STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-1

Section VI. Specific Operating Conditions

A. Emission Unit #S2.001: UTM: North 4059.35 km, East 711.68 km (Zone 11) 

System 01 Reid Gardner Unit #1 Steam Boiler, 100% Coal Fired with Natural Gas Igniters. 

S2.001 Steam Boiler, Foster Wheeler, Model # 5757, Serial # 36-4109, Manufactured April,1965. 1,215 

million Btu/hr, Maximum Heat Input, Nominal 110.0 MW Output.

1. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Air Pollution Equipment

Emissions from S2.001 shall be ducted to the following emissions control system with 100% capture and a maximum 

volume flow rate of 25,000,000 standard cubic feet per hour (SCFH): 

a. Mechanical fly ash collectors for the control of particulate matter. 

b. Soda ash wet scrubber (Flue Gas Desulfurization – FGD) for the control of sulfur dioxide and particulate matter. 

c. Low NOx coal burners and over-fired air. 

d. Baghouse (complete installation and operation no later than July 1, 2010). 

The volumetric flow rate may be determined by utilizing Method 2 – Determination of Stack Gas Velocity and 

Volumetric Flow Rate as referenced in 40 CFR Part 60, Appendix A. 

2. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Emission Limits

a. On and after the date of startup of S2.001, the Permittee will not discharge or cause the discharge into the 

atmosphere from the exhaust stack of S2.001, the following pollutants in excess of the following specified limits: 

(1) NAC 445B.2203 State-Only Requirement - The discharge of PM10 (particulate matter less than 10 microns in 

diameter) to the atmosphere will not exceed 0.20 pound per million Btu. 

(2) SIP 445.731 Federally Enforceable SIP - The discharge of PM (particulate matter) to the atmosphere will not 

exceed 0.20 pound per million Btu. 

(3) Article 8.2.1.2 Federally Enforceable SIP - The discharge of sulfur to the atmosphere will not exceed 729.0 

pounds per hour. 

(4) NAC 445B.22047 State-Only Requirement - The discharge of sulfur to the atmosphere will not exceed 729.0 

pounds per hour. 

(5) NAC 445B.22057 State-Only Requirement - The allowable emission of sulfur from fossil-fired power 

generating Unit Number One of the Nevada Power Company’s Reid Gardner Station, located in air Quality 

Control Region 13, Basin 218, California Wash, must not be greater than 0.275 pound per million Btu. 

(6) NAC 445B.305 Federally Enforceable PSD Permit Requirement (PSD Permit Issued 1/3/80) - The discharge 

of SO2 to the atmosphere will not exceed 0.55 pound per million Btu (based on a 3-hour rolling average 

period). 

(6A) NAC 445B.305 (Consent Decree Requirements) - The discharge of SO2 to the atmosphere will not exceed

0.40 pound per million Btu (based on a 10-day rolling average period). 

(7) SIP 445.721 Federally Enforceable SIP - The opacity from S2.001 will not equal or exceed 20% for a period 

or periods aggregating more than 3 minutes in any one hour. 

(8) NAC 445B.22017 State-Only Requirement - The opacity from S2.001 will not equal or exceed 20%. The 

opacity must be determined as set forth in 445B.22017.1(a) or (b). 

(9) NAC 445B.2202.6 State-Only Requirement - The opacity from S2.001 may exceed the level set in A.2.a.(8) 

of this section for the purposes of boiler lancing or soot blowing, not to exceed 180 minutes in any 

consecutive 24 hour period. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-2

Section VI. Specific Operating Conditions (continued)

A. Emission Unit #S2.001 (continued) 

2. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Emission Limits (continued) 

b. Specific Acid Rain Requirements Parts 72 - 78 Acid Rain Program

(1) The Permittee will not exceed the SO2 and NOx emission levels (acid rain allowances) for the indicated 

years as shown in the following table without holding the required acid rain allowances in accordance with 

Section IV.B.2 of the Acid Rain provisions and pursuant to 40 CFR 72.9: 

Calendar Year 2001 2002 2003 2004 2005 

S2.001 SO2 Phase II Allowance 2,172 2,172 2,172 2,172 2,172 

S2.001 NOx Emission Limit (lb/MMBtu) 0.46 0.46 0.46 0.46 0.46 

(2) The Permittee will comply with the “Standard Requirements” provisions of the SO2 acid rain permit 

application dated January 26, 1995 entitled “Phase II Permit Application” and all references contained 

therein, which is hereby incorporated by reference into this operating document (Attachment 1). [NAC 

445B.305]. 

3. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Operating Parameters

a. S2.001 will combust sub-bituminous and/or bituminous coal; and/or natural gas for purposes of startup, shutdown 

and/or flame stabilization only. 

b. S2.001 may operate a total of 8,760 hours per calendar year. 

c. The maximum operating heat input rate for S2.001 while combusting sub-bituminous and/or bituminous coal and 

natural gas will not exceed 1,215 million Btu per any one-hour period. 

4. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Compliance, Monitoring, Recordkeeping and Reporting

a. Compliance/Performance Testing

Within 180 days of the date of issuance of this operating permit, and once annually thereafter, The Permittee

will: 

(1) Conduct and record a Method 5 performance test for PM on the exhaust stack of S2.001 consisting of three 

valid runs. The Method 5 emissions test must be conducted in accordance with 40 CFR Part 60, Appendix 

A, Method 5, and include the back-half catch. 

(2) Conduct and record a Method 201A and 202 performance test for PM10 on the exhaust stack of S2.001 

consisting of three valid runs. The Method 201A and 202 emissions tests must be conducted in accordance 

with 40 CFR Part 51, Appendix M, Method 201A and 202. The Method 201A and 202 emissions tests may 

be replaced by a Method 5 performance test, including the back-half catch. All particulate captured in the 

Method 5 test will be considered PM10 for compliance demonstration purposes. 

(3) Conduct and record a Method 6 or 6C performance test for SO2 on the exhaust stack of S2.001 consisting of 

three valid runs. The Method 6 or 6C emissions test must be conducted in accordance with 40 CFR Part 60, 

Appendix A, Method 6 (PSD permit requirement VIII.B.2. issued January 3, 1980). 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-3

Section VI. Specific Operating Conditions (continued)

A. Emission Unit #S2.001 (continued) 

4. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Compliance, Monitoring, Recordkeeping and Reporting (continued) 

a. Compliance/Performance Testing (continued) 

(4) The performance tests will be conducted at the maximum operating heat input rate limit established in A.3.c 

of this section for each pollutant required to be tested, unless otherwise approved pursuant to NAC 

445B.252.3 & 4. The Permittee shall make available to the director such records as may be necessary to 

determine the conditions of the test of performance. Operations during periods of startup, shutdown and 

malfunction must not constitute representative conditions of a test of performance unless otherwise specified 

in the applicable standard (NAC 445B.252.3). Should any anticipated major boiler overhaul(s) be scheduled 

to be performed, which coincide with the performance tests, the performance testing will be performed prior 

to the overhaul(s). If the performance testing can not be performed prior to a major boiler overhaul, the 

testing will be performed as soon as practicable following the overhaul(s), but not earlier than 60 days 

following the overhaul. 

(5) The Permittee shall give notice to the director 30 days before the test of performance to allow the director to 

have an observer present. A written testing procedure for the test of performance must be submitted to the 

director at least 30 days before the test of performance to allow the director to review the proposed testing 

procedures (NAC 445B.252.4). 

(6) During each performance test required in A.4.a.(1) through (3) of this section, record the quantity (in tons) of 

coal combusted during each test run, the heat content value of the coal combusted during each test run (in 

Btu/ton) and include these data in the test results submitted. The emissions results of the Method 6 or 6C 

performance test for SO2 must be converted to emissions of sulfur (both lb/hr and lb/MMBtu). The emissions 

results of the Method 5 performance test for PM and method 5 or Method 201A and 202 performance test for 

PM10 must be reported in lb/MMBtu. 

(7) As a result of the most recent performance test performed in A.4.a.(1) through (3) of this section, derive 

emission factors for each of the following: 

(i). Pounds of PM per ton of coal (lbs-PM/tons-coal). 

(ii). Pounds of PM10 per ton of coal (lbs-PM10/tons-coal). 

These emissions factors will be based on the average of the 3 test runs. 

(8) Within 60 days after completing the performance tests contained in A.4.a. of this section, the Permittee shall 

furnish the director a written report of the results of the performance tests and the resultant emissions 

factors. All information and analytical results of testing and sampling must be certified as to the truth and 

accuracy and as to their compliance with NAC 445B.001 to 445B.3485 (NAC 445B.252.8). 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-4

Section VI. Specific Operating Conditions (continued)

A. Emission Unit #S2.001 (continued) 

4. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Compliance, Monitoring, Recordkeeping and Reporting (continued) 

b. Monitoring

The Permittee, upon issuance of this operating permit will: 

(1) Install, calibrate, operate and maintain a coal mass measurement device to continuously measure the 

amount of sub-bituminous and/or bituminous coal (in tons) combusted in S2.001. The coal mass 

measurement device will be installed at an appropriate location in the fuel delivery system to accurately and 

continuously measure the fuel combusted in S2.001. 

(2) Install, calibrate, operate and maintain a fuel flow meter to continuously record the volume (in standard cubic 

feet) of natural gas combusted in S2.001. The fuel flow meter will be installed at an appropriate location in 

the fuel delivery system to accurately and continuously measure the fuel combusted in S2.001 in accordance 

with the requirements prescribed in 40 CFR Part 75. 

(3) Install, calibrate, operate and maintain a Continuous Data Collection System (CDCS) to continuously record 

the quantity (in tons) of sub-bituminous and/or bituminous coal as measured by the coal mass measurement 

device and the quantity of natural gas (in standard cubic feet) as measured by the fuel flow meter as required 

in A.4.b.(1) and (2) of this section. The CDCS will be installed, calibrated, operated and maintained in 

accordance with the manufacturer’s specifications. 

(4) Perform coal sampling of the coal prior to it entering the boiler. Sampling shall be conducted for moisture, 

ash, sulfur content, and gross calorific value. A coal analysis shall be performed weekly and the results of 

these analyses shall be retained for at least two years following the date of the measurement. All sample 

collection, sample preparation, and analyses performed or caused to be performed shall be conducted 

according to the most current ASTM methods (PSD permit requirement VIII.E. issued January 3, 1980). 

(5) Perform coal sampling of the sub-bituminous and/or bituminous coal weekly according to section 12.5.3.2.2 

in Method 19 in appendix A to Part 60 and use ASTM Method D2234-89, “Standard Test Methods for 

Collection of a Gross Sample of Coal.” Determine the gross calorific value of the sub-bituminous and/or 

bituminous coal combusted by sampling at least once weekly, using ASTM D2013-86, “Standard Method of 

Preparing Coal Samples for Analysis”, ASTM D2015-91, “Standard Test Method for Gross Calorific Value of 

Coal and Coke by the Adiabatic Bomb Calorimeter”, ASTM 1989-92, “Standard test Method for Gross 

Calorific Value of Coal and Coke by Microprocessor Controlled Isoperibol Calorimeters”, or ASTM 3286-91a, 

“Standard Test Method for Gross Calorific Value of Coal and Coke by the Isoperibol Bomb Calorimeter.” 

(6) Maintain on site, monthly analysis of calorific value of natural gas provided by natural gas supplier. 

(7) Substitute any missing fuel flow meter data in accordance with the requirements prescribed in 40 CFR Part 

75, Appendix D, Section 2.4.2. 

(8) Install, calibrate, operate and maintain a SO2 continuous emissions monitor system (CEMS) (consisting of a 

SO2 pollutant concentration monitor and a flow monitoring system) to continuously measure the 

concentration of SO2 (in ppm), volumetric gas flow (in scfh), and SO2 mass emissions (in lb/hr and lb/MMBtu) 

from S2.001. The CEMS will be installed at an appropriate location in the exhaust stack of S2.001 to 

accurately and continuously measure the SO2 concentration in S2.001 in accordance with the requirements 

prescribed in 40 CFR Part 60.13 and 40 CFR Part 60, Appendix B, Performance Specification 2 (PSD permit 

requirement VIII.D.2.a. issued January 3, 1980), 40 CFR Part 75, Part 75.11 and Appendix F. 

(9) Install, calibrate, operate and maintain a Continuous Data Collection System (CDCS) to continuously record 

the SO2 concentration (in ppm), volumetric gas flow (in scfh), and SO2 mass emissions (in lb/hr and 

lb/MMBtu) on 1-hour average period and SO2 mass emissions (in lb/MMBtu) on 3-hour rolling average period 

and 1-day average period, as measured by the CEMS required in A.4.b.(8) of this section. The CDCS will be 

installed, calibrated, operated and maintained in accordance with the manufacturer’s specifications and the 

requirements prescribed in 40 CFR Part 60.13 and 40 CFR Part 60, Appendix B, Performance Specification 

2 (PSD permit requirement VIII.D.2.a. issued January 3, 1980), 40 CFR Part 75, Part 75.11 and Appendix F. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-5

Section VI. Specific Operating Conditions (continued)

A. Emission Unit #S2.001 (continued) 

4. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Compliance, Monitoring, Recordkeeping and Reporting (continued) 

b. Monitoring (continued)

(10) Install, calibrate, operate and maintain a continuous opacity monitoring system to continuously measure 

and record the opacity from S2.001. The continuous opacity monitoring system will be installed at an 

appropriate location in the discharge stack of S2.001 to accurately and continuously measure the opacity of 

S2.001 in accordance with the requirements prescribed in NAC 445B.256 to NAC 445B.267 and 40 CFR 

Part 75.10. 

(11) Install, calibrate, operate and maintain a Continuous Data Collection System (CDCS) to continuously 

record the opacity (in percent opacity) as measured by the continuous opacity monitoring system required in 

A.4.b.(10) of this section. The CDCS will be installed, calibrated, operated and maintained in accordance 

with the manufacturer’s specifications and the requirements prescribed in NAC 445B.256 to NAC 445B.267, 

40 CFR Part 75.10 and 40 CFR Part 75.14. 

c. Recordkeeping

The Permittee will maintain a contemporaneous log containing at a minimum, the following recordkeeping for 

each day, or part of a day that S2.001 is operating: 

(1) The total hourly quantity of sub-bituminous and/or bituminous coal (in tons) and the volume of natural gas (in 

scf) combusted, for each hour of operation based on the data recorded by the CDCS as required in A.4.b.(3) 

of this section. 

(2) The total daily hours of operation for the corresponding date. 

(3) The heat contents of each fuel combusted for the corresponding date, in Btu/ton (coal) and Btu/scf (natural 

gas). The heat contents of each fuel will be based on the gross calorific value determined in A.4.b.(5) & (6) 

of this section. 

(4) The hourly heat inputs of the sub-bituminous and/or bituminous coal and/or natural gas combusted, in 

MMBtu per hour. The hourly heat inputs will be calculated from the hourly fuel usage rates recorded in 

A.4.c.(1) of this section, and the heat contents of the fuel as recorded in A.4.c.(3) of this section. 

Sample Calculation: 

(tons-coal/hr)(Btu/ton-coal) = Btu/hr or MMBtu/hr 

(scf/hr)(Btu/scf) = Btu/hr or MMBtu/hr – natural gas 

Sum: 

MMBtu/hr - Coal + MMBtu/hr – natural gas = Hourly Heat Input in MMBtu/hr 

(5) The hourly emission rate of PM and PM10 each, in pounds per MMBtu (lbs/MMBtu). The hourly emission 

rates will be calculated from the hourly quantity of sub-bituminous and/or bituminous coal and/or natural gas 

determined in A.4.b.(1) and (2) of this section, and the emission factor derived in A.4.a.(7) of this section for 

coal combustion and emission factor (7.6 lb/106

 scf) as listed in AP-42, Table 1.4-2. for natural gas 

combustion. 

Sample Calculation: 

(tons-coal/Btu)(lbs-PM/tons-coal) = lbs-PM/Btu or lbs-PM/MMBtu 

(scf natural gas/Btu)(7.6 lb/106

 scf) = lbs-PM/Btu or lbs-PM/MMBtu – natural gas 

Sum: 

lbs-PM/MMBtu - Coal + lbs-PM/MMBtu – natural gas = Hourly Emission Rate in lbs-PM/MMBtu 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-6

Section VI. Specific Operating Conditions (continued)

A. Emission Unit #S2.001 (continued) 

4. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Compliance, Monitoring, Recordkeeping and Reporting (continued) 

c. Recordkeeping (continued)

(6) The emission rates of sulfur and SO2 each, in pounds per hour (lbs/hr) and pounds per million Btu 

(lbs/MMbtu) measured by the CEMS required in A.4.b.(8) of this section, for each averaging period described 

below: 

(i). The sulfur emissions in pounds per hour (lbs/hr) for each 1-hour period. Sulfur emissions will be one-half 

of the SO2 emissions measured. 

(ii). The sulfur and SO2 emissions in pounds per million Btu (lbs/MMBtu) for each 1-hour period. The 

conversion procedures established in 40 CFR Part 60.45(e) & (f) will be used to convert the continuous 

monitoring data into units of the applicable standard (lb/MMBtu, 3-hour rolling average period and 1-day 

average period). Sulfur emissions will be one-half of the SO2 emissions measured. 

(iii). The total SO2 emissions for a 10-day rolling average period (based on preceding last 10 days) in 

lbs/MMBtu. The SO2 emissions in lbs/MMBtu for each 1-day average period recorded in Section 

VI.A.4.c.(6)(ii) will be used to calculate a 10-day rolling average period. 

(7) The measured opacity (in percent opacity) from the continuous opacity monitoring system required in 

A.4.b.(10) of this section. The opacity will be determined from reducing all data from the successive 10-

second readings and recorded for the following: 

(i). Each 6-minute average as required in NAC 445B.22017.1(b) and as set forth in 40 CFR Part 60.13(h). 

d. Reporting

The Permittee will: 

(1) Report all excess emissions as required in Sections III.B and III.C of this operating permit. 

(2) Report all deviations as required in Section V.C of the operating permit. 

(3) Submit semi-annual monitoring reports as required in Section V.C of this operating permit. 

(4) Certify compliance with all applicable requirements as required in Section V.E of this operating permit. 

(5) Report the results of the performance tests required in A.4.a.(8) of this section. 

(6) Federally Enforceable PSD Permit Requirement (PSD Permit Issued 1/3/80) - Submit a written report of 

excess emissions to the Administrator and the Director every calendar quarter. The report shall include: 

(i). The magnitude of excess emissions computed in accordance with 40 CFR 60.13(h), any conversion 

factor(s) used, and the date and time of commencement and completion of each time period of excess 

emissions. 

(ii). Specific identification of each period of excess emissions that occurs during start-ups, shutdowns, and 

malfunctions. The nature and cause of any malfunction (if known) and the corrective action taken or 

preventative measures adopted shall also be reported. 

(iii). The date and time identifying each period during which the continuous monitoring system was 

inoperative except for zero and span checks and the nature of the system repairs or adjustments. 

(iv). When no excess emissions have occurred or the continuous monitoring system has not been 

inoperative, repaired, or adjusted, such information shall be stated in the report. 

(v). Excess emissions shall be defined as any 3-hour rolling average period during which the average 

emissions of sulfur dioxide, as measured by the continuous monitoring system, exceeds the sulfur 

dioxide maximum limit in A.2.a.(6) of this section. 

(vi). The Permittee shall maintain a file of all measurements, including continuous monitoring system, 

monitoring device, and performance testing measurements; all continuous monitoring system 

performance evaluations; all continuous monitoring system or monitoring device calibration checks; 

adjustments and maintenance performed on these systems or devices; and all other information required 

by 40 CFR part 60 recorded in a permanent form suitable for inspection. The file shall be retained for at 

least two years following the date of such measurements, maintenance, reports, and records. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-7

Section VI. Specific Operating Conditions (continued)

A. Emission Unit #S2.001 (continued) 

4. NAC 445B.3405 (NAC 445B.316) Part 70 Program

d. Reporting (continued) 

(7) Consent Decree Requirements

The SO2 excess emissions (lb/MMBtu) shall also be defined as any 10-day rolling average period during which 

the average emissions of sulfur dioxide, as measured by the continuous monitoring system, exceeds the 

sulfur dioxide maximum limit in A.2.a.(6A) of this section. 

(8) Federally Enforceable PSD Permit Requirement (PSD Permit Issued 1/3/80) – The following reporting 

requirements apply only to Section VIII of the PSD Permit issued 1/3/80: 

The Regional Administrator (USEPA) shall be notified by telephone (by The Permitee) within 48 hours 

following any failure of air pollution control equipment, process equipment, or of a process to operate in 

a normal manner which results an increase in emissions above any allowable emissions limit stated in 

Section VIII of the USEPA-issued PSD permit dated January 3, 1980 of these conditions. In addition 

the Regional Administrator shall be notified in writing within fifteen (15) days of any such failure. This 

notification shall include a description of the malfunctioning equipment or abnormal operation, the date 

of the initial failure, the period of time over which emissions were increased due to failure, the cause of 

the failure, the estimated resultant emissions in excess of those allowed under Section VIII of these 

conditions, and the methods utilized to restore normal operations. Compliance with this malfunction 

notification provision shall not excuse or otherwise constitute a defense to any violations of this permit 

or of any law or regulations, which such malfunction, may cause. 

5. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Shielded Requirements

No specific shield requested.
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-8

Section VI. Specific Operating Conditions (continued) 

B. Emission Unit #S2.001 - Alternative Operating Scenario: Co-Firing Coal and No. 2 Distillate Fuel Oil.

System 01B is completely DELETED (dated March 14, 2008). 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-9

Section VI. Specific Operating Conditions (continued)

C. Emission Unit #S2.002. Primary Operating Scenario: 100% Coal Fired. UTM: North 4059.32 km, East 711.68 km 

(Zone 11) 

System 02A Reid Gardner Unit No. 2 Steam Boiler, Coal Fired. 

S2.002 Steam Boiler, Foster Wheeler, Model # 2-79-2106, Serial # 08-6374, Manufactured July 1968. 1,215 

million Btu/hr, Maximum Heat Input, Nominal 110.0 MW Output.

1. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Air Pollution Equipment

Emissions from S2.002 shall be ducted to the following emissions control system with 100% capture and a maximum 

volume flow rate of 25,000,000 standard cubic feet per hour (SCFH): 

a. Mechanical fly ash collectors for the control of particulate matter. 

b. Soda ash wet scrubber (Flue Gas Desulfurization – FGD) for the control of sulfur dioxide and particulate matter. 

c. Low NOx coal burners and over-fired air. 

The volumetric flow rate may be determined by utilizing Method 2 – Determination of Stack Gas Velocity and 

Volumetric Flow Rate as referenced in 40 CFR Part 60, Appendix A. 

2. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Emission Limits

a. On and after the date of startup of S2.002, the Permittee will not discharge or cause the discharge into the 

atmosphere from the exhaust stack of S2.002, the following pollutants in excess of the following specified limits: 

(1) NAC 445B.2203 State-Only Requirement - The discharge of PM10 (particulate matter less than 10 microns in 

diameter) to the atmosphere will not exceed 0.20 pound per million Btu. 

(2) SIP 445.731 Federally Enforceable SIP - The discharge of PM (particulate matter) to the atmosphere will not 

exceed 0.20 pound per million Btu. 

(3) Article 8.2.1.2 Federally Enforceable SIP - The discharge of sulfur to the atmosphere will not exceed 729.0 

pounds per hour. 

(4) NAC 445B.22047 State-Only Requirement - The discharge of sulfur to the atmosphere will not exceed 729.0 

pounds per hour. 

(5) NAC 445B.22057 State-Only Requirement - The allowable emission of sulfur from fossil-fired power 

generating unit Number Two of the Nevada Power Company’s Reid Gardner Station, located in air Quality 

Control Region 13, Basin 218, California Wash, must not be greater than 0.275 pound per million Btu. 

(6) NAC 445B.305 Federally Enforceable PSD Permit Requirement (PSD Permit Issued 1/3/80) - The discharge 

of SO2 to the atmosphere will not exceed 0.55 pound per million Btu (based on a 3-hour rolling average 

period). 

(7) SIP 445.721 Federally Enforceable SIP - The opacity from S2.002 will not equal or exceed 20% for a period 

or periods aggregating more than 3 minutes in any one hour. 

(8) NAC 445B.22017 State-Only Requirement - The opacity from S2.002 will not equal or exceed 20%. The 

opacity must be determined as set forth in 445B.22017.1(a) or (b). 

(9) NAC 445B.2202.6 State-Only Requirement - The opacity from S2.002 may exceed the level set in C.2.a.(8) 

of this section for the purposes of boiler lancing or soot blowing, not to exceed 180 minutes in any 

consecutive 24 hour period. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-10

Section VI. Specific Operating Conditions (continued)

C. Emission Unit #S2.002 - Primary Operating Scenario: Coal Fired (continued) 

2. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Emission Limits (continued) 

b. Specific Acid Rain Requirements Parts 72 - 78 Acid Rain Program

(1) The Permittee will not exceed the SO2 and NOx emission levels (acid rain allowances) for the indicated 

years as shown in the following table without holding the required acid rain allowances in accordance with 

Section IV.B.2 of the Acid Rain provisions and pursuant to 40 CFR 72.9: 

Calendar Year 2001 2002 2003 2004 2005 

S2.002 SO2 Phase II Allowance 2,201 2,201 2,201 2,201 2,201 

S2.002 NOx Emission Limit (lb/MMBtu) 0.46 0.46 0.46 0.46 0.46 

(2) The Permittee will comply with the “Standard Requirements” provisions of the SO2 acid rain permit 

application dated January 26, 1995 entitled “Phase II Permit Application” and all references contained 

therein, which is hereby incorporated by reference into this operating document (Attachment 1). [NAC 

445B.305]. 

3. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Operating Parameters

a. S2.002 will combust sub-bituminous and/or bituminous coal only when operating under this operating scenario. 

b. S2.002 may operate a total of 8,760 hours per calendar year. 

c. The maximum operating heat input rate for S2.002 while combusting sub-bituminous and/or bituminous coal will 

not exceed 1,215 million Btu per any one-hour period. 

4. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Compliance, Monitoring, Recordkeeping and Reporting

a. Compliance/Performance Testing

Within 180 days of the date of issuance of this operating permit, and once annually thereafter, The Permittee

will: 

(1) Conduct and record a Method 5 performance test for PM on the exhaust stack of S2.002 consisting of three 

valid runs. The Method 5 emissions test must be conducted in accordance with 40 CFR Part 60, Appendix 

A, Method 5, and include the back-half catch. 

(2) Conduct and record a Method 201A and 202 performance test for PM10 on the exhaust stack of S2.002 

consisting of three valid runs. The Method 201A and 202 emissions tests must be conducted in accordance 

with 40 CFR Part 51, Appendix M, Method 201A and 202. The Method 201A and 202 emissions tests may 

be replaced by a Method 5 performance test, including the back-half catch. All particulate captured in the 

Method 5 test will be considered PM10 for compliance demonstration purposes. 

(3) Conduct and record a Method 6 or 6C performance test for SO2 on the exhaust stack of S2.002 consisting of 

three valid runs. The Method 6 or 6C emissions test must be conducted in accordance with 40 CFR Part 60, 

Appendix A, Method 6 (PSD permit requirement VIII.B.2. issued January 3, 1980). 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-11

Section VI. Specific Operating Conditions (continued)

C. Emission Unit #S2.002 - Primary Operating Scenario: 100% Coal Fired (continued) 

4. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Compliance, Monitoring, Recordkeeping and Reporting (continued) 

a. Compliance/Performance Testing (continued)

(4) The performance tests will be conducted at the maximum operating heat input rate limit established in C.3.c 

of this section for each pollutant required to be tested, unless otherwise approved pursuant to NAC 

445B.252.3 & 4. The Permittee shall make available to the director such records as may be necessary to 

determine the conditions of the test of performance. Operations during periods of startup, shutdown and 

malfunction must not constitute representative conditions of a test of performance unless otherwise specified 

in the applicable standard (NAC 445B.252.3). Should any anticipated major boiler overhaul(s) be scheduled 

to be performed, which coincide with the performance tests, the performance testing will be performed prior 

to the overhaul(s). If the performance testing can not be performed prior to a major boiler overhaul, the 

testing will be performed as soon as practicable following the overhaul(s), but not earlier than 60 days 

following the overhaul. 

(5) The Permittee shall give notice to the director 30 days before the test of performance to allow the director to 

have an observer present. A written testing procedure for the test of performance must be submitted to the 

director at least 30 days before the test of performance to allow the director to review the proposed testing 

procedures (NAC 445B.252.4). 

(6) During each performance test required in C.4.a.(1) through (3) of this section, record the quantity (in tons) of 

coal combusted during each test run, the heat content value of the coal combusted during each test run (in 

Btu/ton) and include these data in the test results submitted. The emissions results of the Method 6 or 6C 

performance test for SO2 must be converted to emissions of sulfur (both lb/hr and lb/MMBtu). The emissions 

results of the Method 5 performance test for PM and Method 5 or Method 201A and 202 performance test for 

PM10 must be reported in lb/MMBtu. 

(7) As a result of the most recent performance test performed in C.4.a.(1) through (3) of this section, derive 

emission factors for each of the following: 

(i). Pounds of PM per ton of coal (lbs-PM/tons-coal). 

(ii). Pounds of PM10 per ton of coal (lbs-PM10/tons-coal). 

These emissions factors will be based on the average of the 3 test runs. 

(8) Within 60 days after completing the performance tests contained in C.4.a. of this section, the Permittee shall 

furnish the director a written report of the results of the performance tests and the resultant emissions 

factors. All information and analytical results of testing and sampling must be certified as to the truth and 

accuracy and as to their compliance with NAC 445B.001 to 445B.3485 (NAC 445B.252.8). 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-12

Section VI. Specific Operating Conditions (continued) 

C. Emission Unit #S2.002 - Primary Operating Scenario: 100% Coal Fired (continued) 

4. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Compliance, Monitoring, Recordkeeping and Reporting (continued) 

b. Monitoring

The Permittee, upon issuance of this operating permit will: 

(1) Install, calibrate, operate and maintain a coal mass measurement device to continuously measure the 

amount of sub-bituminous and/or bituminous coal (in tons) combusted in S2.002. The coal mass 

measurement device will be installed at an appropriate location in the fuel delivery system to accurately and 

continuously measure the fuel combusted in S2.002. 

(2) Install, calibrate, operate and maintain a Continuous Data Collection System (CDCS) to continuously record 

the quantity (in tons) of sub-bituminous and/or bituminous coal as measured by the coal mass measurement 

device required in C.4.b.(1) of this section. The CDCS will be installed, calibrated, operated and maintained 

in accordance with the manufacturer’s specifications. 

(3) Perform coal sampling of the coal prior to it entering the boiler. Sampling shall be conducted for moisture, 

ash, sulfur content, and gross calorific value. A coal analysis shall be performed weekly and the results of 

these analyses shall be retained for at least two years following the date of the measurement. All sample 

collection, sample preparation, and analyses performed or caused to be performed shall be conducted 

according to the most current ASTM methods (PSD permit requirement VIII.E. issued January 3, 1980). 

(4) Perform coal sampling of the sub-bituminous and/or bituminous coal weekly according to section 12.5.3.2.2 

in Method 19 in appendix A to Part 60 and use ASTM Method D2234-89, “Standard Test Methods for 

Collection of a Gross Sample of Coal.” Determine the gross calorific value of the sub-bituminous and/or 

bituminous coal combusted by sampling at least once weekly, using ASTM D2013-86, “Standard Method of 

Preparing Coal Samples for Analysis”, ASTM D2015-91, “Standard Test Method for Gross Calorific Value of 

Coal and Coke by the Adiabatic Bomb Calorimeter”, ASTM 1989-92, “Standard test Method for Gross 

Calorific Value of Coal and Coke by Microprocessor Controlled Isoperibol Calorimeters”, or ASTM 3286-91a, 

“Standard Test Method for Gross Calorific Value of Coal and Coke by the Isoperibol Bomb Calorimeter.” 

(5) Install, calibrate, operate and maintain a SO2 continuous emissions monitor system (CEMS) (consisting of a 

SO2 pollutant concentration monitor and a flow monitoring system) to continuously measure the 

concentration of SO2 (in ppm), volumetric gas flow (in scfh), and SO2 mass emissions (in lb/hr and lb/MMBtu) 

from S2.002. The CEMS will be installed at an appropriate location in the exhaust stack of S2.002 to 

accurately and continuously measure the SO2 concentration in S2.002 in accordance with the requirements 

prescribed in 40 CFR Part 60.13 and 40 CFR Part 60, Appendix B, Performance Specification 2 (PSD permit 

requirement VIII.D.2.a. issued January 3, 1980), 40 CFR Part 75, Part 75.11 and Appendix F. 

(6) Install, calibrate, operate and maintain a Continuous Data Collection System (CDCS) to continuously record 

the SO2 concentration (in ppm), volumetric gas flow (in scfh), and SO2 mass emissions (in lb/hr and 

lb/MMBtu), as measured by the CEMS required in C.4.b.(5) of this section. The CDCS will be installed, 

calibrated, operated and maintained in accordance with the manufacturer’s specifications and the 

requirements prescribed in 40 CFR Part 60.13 and 40 CFR Part 60, Appendix B, Performance Specification 

2 (PSD permit requirement VIII.D.2.a. issued January 3, 1980), 40 CFR Part 75, Part 75.11 and Appendix F. 

(7) Install, calibrate, operate and maintain a continuous opacity monitoring system to continuously measure and 

record the opacity from S2.002. The continuous opacity monitoring system will be installed at an appropriate 

location in the discharge stack of S2.002 to accurately and continuously measure the opacity of S2.002 in 

accordance with the requirements prescribed in NAC 445B.256 to NAC 445B.267 and 40 CFR Part 75.10. 

(8) Install, calibrate, operate and maintain a Continuous Data Collection System (CDCS) to continuously record 

the opacity (in percent opacity) as measured by the continuous opacity monitoring system required in 

C.4.b.(7) of this section. The CDCS will be installed, calibrated, operated and maintained in accordance with 

the manufacturer’s specifications and the requirements prescribed in NAC 445B.256 to NAC 445B.267, 40 

CFR Part 75.10 and 40 CFR Part 75.14. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-13

Section VI. Specific Operating Conditions (continued)

C. Emission Unit #S2.002 - Primary Operating Scenario: 100% Coal Fired (continued)

4. NAC 445B.3405 (NAC 445B.316) Part 70 Program

c. Recordkeeping

The Permittee will maintain a contemporaneous log containing at a minimum, the following recordkeeping for 

each day, or part of a day that S2.002 is operating under this operating scenario: 

(1) The total hourly quantity of sub-bituminous and/or bituminous coal (in tons) combusted, for each hour of 

operation based on the data recorded by the CDCS as required in C.4.b.(2) of this section. 

(2) The total daily hours of operation for the corresponding date. 

(3) The heat content of the sub-bituminous and/or bituminous coal combusted for the corresponding date, in Btu 

per ton (Btu/ton). The heat content of the sub-bituminous and/or bituminous coal will be based on the gross 

calorific value determined in C.4.b.(4) of this section. 

(4) The hourly heat input of the sub-bituminous and/or bituminous coal combusted, in MMBtu per hour. The 

hourly heat inputs will be calculated from the hourly fuel usage rates recorded in C.4.c.(1) of this section, and 

the heat content of the fuel as recorded in C.4.c.(3) of this section. 

Sample Calculation: 

(tons-coal/hr)(Btu/ton-coal) = Btu/hr or MMBtu/hr 

(5) The hourly emission rate of PM and PM10 each, in pounds per MMBtu (lbs/MMBtu). The hourly emission 

rates will be calculated from the heat content of the fuel determined in C.4.b.(4) of this section, and the 

emission factor derived in C.4.a.(7) of this section. 

Sample Calculation: 

(tons-coal/Btu)(lbs-PM/tons-coal) = lbs-PM/Btu or lbs-PM/MMBtu 

(6) The emission rates of sulfur and SO2 each, in pounds per hour (lbs/hr) and pounds per million Btu 

(lbs/MMbtu) measured by the CEMS required in C.4.b.(6) of this section, for each averaging period 

described below: 

(i). The sulfur emissions in pounds per hour (lbs/hr) for each 1-hour period. Sulfur emissions will be one-half 

of the SO2 emissions measured. 

(ii). The sulfur and SO2 emissions in pounds per million Btu (lbs/MMBtu) for each 1-hour period. The 

conversion procedures established in 40 CFR Part 60.45(e) & (f) will be used to convert the continuous 

monitoring data into units of the applicable standard (lb/MMBtu, 3-hour average period). Sulfur 

emissions will be one-half of the SO2 emissions measured. 

(7) The measured opacity (in percent opacity) from the continuous opacity monitoring system required in 

C.4.b.(8) of this section. The opacity will be determined from reducing all data from the successive 10-

second readings and recorded for the following: 

(i). Each 6-minute average as required in NAC 445B.22017.1(b) and as set forth in 40 CFR Part 60.13(h). 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-14

Section VI. Specific Operating Conditions (continued)

C. Emission Unit #S2.002 - Primary Operating Scenario: 100% Coal Fired (continued)

4. NAC 445B.3405 (NAC 445B.316) Part 70 Program

d. Reporting

The Permittee will: 

(1) Report all excess emissions as required in Sections III.B and III.C of this operating permit. 

(2) Report all deviations as required in Section V.C of the operating permit. 

(3) Submit semi-annual monitoring reports as required in Section V.C of this operating permit. 

(4) Certify compliance with all applicable requirements as required in Section V.E of this operating permit. 

(5) Report the results of the performance tests and opacity observations required in C.4.a.(8) of this section. 

(6) Federally Enforceable PSD Permit Requirement (PSD Permit Issued 1/3/80) - Submit a written report of 

excess emissions to the Administrator and the Director every calendar quarter. The report shall include: 

(i). The magnitude of excess emissions computed in accordance with 40 CFR 60.13(h), any conversion 

factor(s) used, and the date and time of commencement and completion of each time period of excess 

emissions. 

(ii). Specific identification of each period of excess emissions that occurs during start-ups, shutdowns, and 

malfunctions. The nature and cause of any malfunction (if known) and the corrective action taken or 

preventative measures adopted shall also be reported. 

(iii). The date and time identifying each period during which the continuous monitoring system was 

inoperative except for zero and span checks and the nature of the system repairs or adjustments. 

(iv). When no excess emissions have occurred or the continuous monitoring system has not been 

inoperative, repaired, or adjusted, such information shall be stated in the report. 

(v). Excess emissions shall be defined as any three-hour period during which the average emissions of sulfur 

dioxide, as measured by the continuous monitoring system, exceeds the sulfur dioxide maximum limit in 

C.2.a.(6) of this section. 

(vi). The Permittee shall maintain a file of all measurements, including continuous monitoring system, 

monitoring device, and performance testing measurements; all continuous monitoring system 

performance evaluations; all continuous monitoring system or monitoring device calibration checks; 

adjustments and maintenance performed on these systems or devices; and all other information required 

by 40 CFR part 60 recorded in a permanent form suitable for inspection. The file shall be retained for at 

least two years following the date of such measurements, maintenance, reports, and records. 

(7) Federally Enforceable PSD Permit Requirement (PSD Permit Issued 1/3/80) – The following reporting 

requirements apply only to Section VIII of the PSD Permit issued 1/3/80: 

The Regional Administrator (USEPA) shall be notified by telephone (by The Permitee) within 48 hours 

following any failure of air pollution control equipment, process equipment, or of a process to operate in a 

normal manner which results an increase in emissions above any allowable emissions limit stated in Section 

VIII of the USEPA-issued PSD permit dated January 3, 1980 of these conditions. In addition the Regional 

Administrator shall be notified in writing within fifteen (15) days of any such failure. This notification shall 

include a description of the malfunctioning equipment or abnormal operation, the date of the initial failure, the 

period of time over which emissions were increased due to failure, the cause of the failure, the estimated 

resultant emissions in excess of those allowed under Section VIII of these conditions, and the methods 

utilized to restore normal operations. Compliance with this malfunction notification provision shall not excuse 

or otherwise constitute a defense to any violations of this permit or of any law or regulations, which such 

malfunction, may cause. 

5. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Shielded Requirements

No specific shield requested.
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-15

Section VI. Specific Operating Conditions (continued)

C1. Emission Unit #S2.002: UTM: North 4059.32 km, East 711.68 km (Zone 11) 

System 02 Reid Gardner Unit No. 2 Steam Boiler, 100% Coal Fired with Natural Gas Igniters. 

S2.002 Steam Boiler, Foster Wheeler, Model # 2-79-2106, Serial # 08-6374, Manufactured July 1968. 1,215 

million Btu/hr, Maximum Heat Input, Nominal 110.0 MW Output.

1. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Air Pollution Equipment

Emissions from S2.002 shall be ducted to the following emissions control system with 100% capture and a maximum 

volume flow rate of 25,000,000 standard cubic feet per hour (SCFH): 

a. Mechanical fly ash collectors for the control of particulate matter. 

b. Soda ash wet scrubber (Flue Gas Desulfurization – FGD) for the control of sulfur dioxide and particulate matter. 

c. Low NOx coal burners and over-fired air. 

d. Natural gas igniters (complete installation and operation no later than July 1, 2009. 

e. Baghouse (complete installation and operation no later than July 1, 2010). 

The volumetric flow rate may be determined by utilizing Method 2 – Determination of Stack Gas Velocity and 

Volumetric Flow Rate as referenced in 40 CFR Part 60, Appendix A. 

2. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Emission Limits

a. On and after the date of startup of S2.002, the Permittee will not discharge or cause the discharge into the 

atmosphere from the exhaust stack of S2.002, the following pollutants in excess of the following specified limits: 

(1) NAC 445B.2203 State-Only Requirement - The discharge of PM10 (particulate matter less than 10 microns in 

diameter) to the atmosphere will not exceed 0.20 pound per million Btu. 

(2) SIP 445.731 Federally Enforceable SIP - The discharge of PM (particulate matter) to the atmosphere will not 

exceed 0.20 pound per million Btu. 

(3) Article 8.2.1.2 Federally Enforceable SIP - The discharge of sulfur to the atmosphere will not exceed 729.0 

pounds per hour. 

(4) NAC 445B.22047 State-Only Requirement - The discharge of sulfur to the atmosphere will not exceed 729.0 

pounds per hour. 

(5) NAC 445B.22057 State-Only Requirement - The allowable emission of sulfur from fossil-fired power 

generating unit Number Two of the Nevada Power Company’s Reid Gardner Station, located in air Quality 

Control Region 13, Basin 218, California Wash, must not be greater than 0.275 pound per million Btu. 

(6) NAC 445B.305 Federally Enforceable PSD Permit Requirement (PSD Permit Issued 1/3/80) - The discharge 

of SO2 to the atmosphere will not exceed 0.55 pound per million Btu (based on a 3-hour rolling average 

period). 

(6A) NAC 445B.305 (Consent Decree Requirements) - The discharge of SO2 to the atmosphere will not exceed

0.40 pound per million Btu (based on a 10-day rolling average period). 

(7) SIP 445.721 Federally Enforceable SIP - The opacity from S2.002 will not equal or exceed 20% for a period 

or periods aggregating more than 3 minutes in any one hour. 

(8) NAC 445B.22017 State-Only Requirement - The opacity from S2.002 will not equal or exceed 20%. The 

opacity must be determined as set forth in 445B.22017.1(a) or (b). 

(9) NAC 445B.2202.6 State-Only Requirement - The opacity from S2.002 may exceed the level set in C1.2.a.(8) 

of this section for the purposes of boiler lancing or soot blowing, not to exceed 180 minutes in any 

consecutive 24 hour period. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-16

Section VI. Specific Operating Conditions (continued)

C1. Emission Unit #S2.002 (continued) 

2. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Emission Limits (continued) 

b. Specific Acid Rain Requirements Parts 72 - 78 Acid Rain Program

(1) The Permittee will not exceed the SO2 and NOx emission levels (acid rain allowances) for the indicated 

years as shown in the following table without holding the required acid rain allowances in accordance with 

Section IV.B.2 of the Acid Rain provisions and pursuant to 40 CFR 72.9: 

Calendar Year 2001 2002 2003 2004 2005 

S2.002 SO2 Phase II Allowance 2,201 2,201 2,201 2,201 2,201 

S2.002 NOx Emission Limit (lb/MMBtu) 0.46 0.46 0.46 0.46 0.46 

(2) The Permittee will comply with the “Standard Requirements” provisions of the SO2 acid rain permit 

application dated January 26, 1995 entitled “Phase II Permit Application” and all references contained 

therein, which is hereby incorporated by reference into this operating document (Attachment 1). [NAC 

445B.305]. 

3. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Operating Parameters

a. S2.002 will combust sub-bituminous and/or bituminous coal; and/or natural gas for purposes of startup, shutdown 

and/or flame stabilization only. 

b. S2.002 may operate a total of 8,760 hours per calendar year. 

c. The maximum operating heat input rate for S2.002 while combusting sub-bituminous and/or bituminous coal and 

natural gas will not exceed 1,215 million Btu per any one-hour period. 

4. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Compliance, Monitoring, Recordkeeping and Reporting

a. Compliance/Performance Testing

Within 180 days of the date of issuance of this operating permit, and once annually thereafter, The Permittee

will: 

(1) Conduct and record a Method 5 performance test for PM on the exhaust stack of S2.002 consisting of three 

valid runs. The Method 5 emissions test must be conducted in accordance with 40 CFR Part 60, Appendix 

A, Method 5, and include the back-half catch. 

(2) Conduct and record a Method 201A and 202 performance test for PM10 on the exhaust stack of S2.002 

consisting of three valid runs. The Method 201A and 202 emissions tests must be conducted in accordance 

with 40 CFR Part 51, Appendix M, Method 201A and 202. The Method 201A and 202 emissions tests may 

be replaced by a Method 5 performance test, including the back-half catch. All particulate captured in the 

Method 5 test will be considered PM10 for compliance demonstration purposes. 

(3) Conduct and record a Method 6 or 6C performance test for SO2 on the exhaust stack of S2.002 consisting of 

three valid runs. The Method 6 or 6C emissions test must be conducted in accordance with 40 CFR Part 60, 

Appendix A, Method 6 (PSD permit requirement VIII.B.2. issued January 3, 1980). 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-17

Section VI. Specific Operating Conditions (continued)

C1. Emission Unit #S2.002 (continued) 

4. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Compliance, Monitoring, Recordkeeping and Reporting (continued) 

a. Compliance/Performance Testing (continued)

(4) The performance tests will be conducted at the maximum operating heat input rate limit established in C1.3.c 

of this section for each pollutant required to be tested, unless otherwise approved pursuant to NAC 

445B.252.3 & 4. The Permittee shall make available to the director such records as may be necessary to 

determine the conditions of the test of performance. Operations during periods of startup, shutdown and 

malfunction must not constitute representative conditions of a test of performance unless otherwise specified 

in the applicable standard (NAC 445B.252.3). Should any anticipated major boiler overhaul(s) be scheduled 

to be performed, which coincide with the performance tests, the performance testing will be performed prior 

to the overhaul(s). If the performance testing can not be performed prior to a major boiler overhaul, the 

testing will be performed as soon as practicable following the overhaul(s), but not earlier than 60 days 

following the overhaul. 

(5) The Permittee shall give notice to the director 30 days before the test of performance to allow the director to 

have an observer present. A written testing procedure for the test of performance must be submitted to the 

director at least 30 days before the test of performance to allow the director to review the proposed testing 

procedures (NAC 445B.252.4). 

(6) During each performance test required in C1.4.a.(1) through (3) of this section, record the quantity (in tons) 

of coal combusted during each test run, the heat content value of the coal combusted during each test run (in 

Btu/ton) and include these data in the test results submitted. The emissions results of the Method 6 or 6C 

performance test for SO2 must be converted to emissions of sulfur (both lb/hr and lb/MMBtu). The emissions 

results of the Method 5 performance test for PM and Method 5 or Method 201A and 202 performance test for 

PM10 must be reported in lb/MMBtu. 

(7) As a result of the most recent performance test performed in C1.4.a.(1) through (3) of this section, derive 

emission factors for each of the following: 

(i). Pounds of PM per ton of coal (lbs-PM/tons-coal). 

(ii). Pounds of PM10 per ton of coal (lbs-PM10/tons-coal). 

These emissions factors will be based on the average of the 3 test runs. 

(8) Within 60 days after completing the performance tests contained in C1.4.a. of this section, the Permittee

shall furnish the director a written report of the results of the performance tests and the resultant emissions 

factors. All information and analytical results of testing and sampling must be certified as to the truth and 

accuracy and as to their compliance with NAC 445B.001 to 445B.3485 (NAC 445B.252.8). 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-18

Section VI. Specific Operating Conditions (continued) 

C1. Emission Unit #S2.002 (continued) 

4. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Compliance, Monitoring, Recordkeeping and Reporting (continued) 

b. Monitoring

The Permittee, upon issuance of this operating permit will: 

(1) Install, calibrate, operate and maintain a coal mass measurement device to continuously measure the 

amount of sub-bituminous and/or bituminous coal (in tons) combusted in S2.002. The coal mass 

measurement device will be installed at an appropriate location in the fuel delivery system to accurately and 

continuously measure the fuel combusted in S2.002. 

(2) Install, calibrate, operate and maintain a fuel flow meter to continuously record the volume (in standard cubic 

feet) of natural gas combusted in S2.002. The fuel flow meter will be installed at an appropriate location in 

the fuel delivery system to accurately and continuously measure the fuel combusted in S2.002 in accordance 

with the requirements prescribed in 40 CFR Part 75. 

(3) Install, calibrate, operate and maintain a Continuous Data Collection System (CDCS) to continuously record 

the quantity (in tons) of sub-bituminous and/or bituminous coal as measured by the coal mass measurement 

device and the quantity of natural gas (in standard cubic feet) as measured by the fuel flow meter as required 

in C1.4.b.(1) and (2) of this section. The CDCS will be installed, calibrated, operated and maintained in 

accordance with the manufacturer’s specifications. 

(4) Perform coal sampling of the coal prior to it entering the boiler. Sampling shall be conducted for moisture, 

ash, sulfur content, and gross calorific value. A coal analysis shall be performed weekly and the results of 

these analyses shall be retained for at least two years following the date of the measurement. All sample 

collection, sample preparation, and analyses performed or caused to be performed shall be conducted 

according to the most current ASTM methods (PSD permit requirement VIII.E. issued January 3, 1980). 

(5) Perform coal sampling of the sub-bituminous and/or bituminous coal weekly according to section 12.5.3.2.2 

in Method 19 in appendix A to Part 60 and use ASTM Method D2234-89, “Standard Test Methods for 

Collection of a Gross Sample of Coal.” Determine the gross calorific value of the sub-bituminous and/or 

bituminous coal combusted by sampling at least once weekly, using ASTM D2013-86, “Standard Method of 

Preparing Coal Samples for Analysis”, ASTM D2015-91, “Standard Test Method for Gross Calorific Value of 

Coal and Coke by the Adiabatic Bomb Calorimeter”, ASTM 1989-92, “Standard test Method for Gross 

Calorific Value of Coal and Coke by Microprocessor Controlled Isoperibol Calorimeters”, or ASTM 3286-91a, 

“Standard Test Method for Gross Calorific Value of Coal and Coke by the Isoperibol Bomb Calorimeter.” 

(6) Maintain on site, monthly analysis of calorific value of natural gas provided by natural gas supplier. 

(7) Substitute any missing fuel flow meter data in accordance with the requirements prescribed in 40 CFR Part 

75, Appendix D, Section 2.4.2. 

(8) Install, calibrate, operate and maintain a SO2 continuous emissions monitor system (CEMS) (consisting of a 

SO2 pollutant concentration monitor and a flow monitoring system) to continuously measure the 

concentration of SO2 (in ppm), volumetric gas flow (in scfh), and SO2 mass emissions (in lb/hr and lb/MMBtu) 

from S2.002. The CEMS will be installed at an appropriate location in the exhaust stack of S2.002 to 

accurately and continuously measure the SO2 concentration in S2.002 in accordance with the requirements 

prescribed in 40 CFR Part 60.13 and 40 CFR Part 60, Appendix B, Performance Specification 2 (PSD permit 

requirement VIII.D.2.a. issued January 3, 1980), 40 CFR Part 75, Part 75.11 and Appendix F. 

(9) Install, calibrate, operate and maintain a Continuous Data Collection System (CDCS) to continuously record 

the SO2 concentration (in ppm), volumetric gas flow (in scfh), and SO2 mass emissions (in lb/hr and 

lb/MMBtu) on 1-hour average period and SO2 mass emissions (in lb/MMBtu) on 3-hour rolling average period 

and 1-day average period, as measured by the CEMS required in C1.4.b.(8) of this section. The CDCS will 

be installed, calibrated, operated and maintained in accordance with the manufacturer’s specifications and 

the requirements prescribed in 40 CFR Part 60.13 and 40 CFR Part 60, Appendix B, Performance 

Specification 2 (PSD permit requirement VIII.D.2.a. issued January 3, 1980), 40 CFR Part 75, Part 75.11 and 

Appendix F. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-19

Section VI. Specific Operating Conditions (continued)

C1. Emission Unit #S2.002 (continued) 

4. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Compliance, Monitoring, Recordkeeping and Reporting (continued) 

b. Monitoring (continued)

(10) Install, calibrate, operate and maintain a continuous opacity monitoring system to continuously measure and 

record the opacity from S2.002. The continuous opacity monitoring system will be installed at an appropriate 

location in the discharge stack of S2.002 to accurately and continuously measure the opacity of S2.002 in 

accordance with the requirements prescribed in NAC 445B.256 to NAC 445B.267 and 40 CFR Part 75.10. 

(11) Install, calibrate, operate and maintain a Continuous Data Collection System (CDCS) to continuously record 

the opacity (in percent opacity) as measured by the continuous opacity monitoring system required in 

C1.4.b.(10) of this section. The CDCS will be installed, calibrated, operated and maintained in accordance 

with the manufacturer’s specifications and the requirements prescribed in NAC 445B.256 to NAC 445B.267, 

40 CFR Part 75.10 and 40 CFR Part 75.14. 

c. Recordkeeping

The Permittee will maintain a contemporaneous log containing at a minimum, the following recordkeeping for 

each day, or part of a day that S2.002 is operating under this operating scenario: 

(1) The total hourly quantity of sub-bituminous and/or bituminous coal (in tons) and the volume of natural gas (in 

scf) combusted, for each hour of operation based on the data recorded by the CDCS as required in 

C1.4.b.(3) of this section. 

(2) The total daily hours of operation for the corresponding date. 

(3) The heat contents of each fuel combusted for the corresponding date, in Btu/ton (coal) and Btu/scf (natural 

gas). The heat contents of each fuel will be based on the gross calorific value determined in C1.4.b.(5) & (6) 

of this section. 

(4) The hourly heat inputs of the sub-bituminous and/or bituminous coal and/or natural gas combusted, in 

MMBtu per hour. The hourly heat inputs will be calculated from the hourly fuel usage rates recorded in 

C1.4.c.(1) of this section, and the heat contents of the fuel as recorded in C1.4.c.(3) of this section. 

Sample Calculation: 

(tons-coal/hr)(Btu/ton-coal) = Btu/hr or MMBtu/hr 

(scf/hr)(Btu/scf) = Btu/hr or MMBtu/hr – natural gas 

Sum: 

MMBtu/hr - Coal + MMBtu/hr – natural gas = Hourly Heat Input in MMBtu/hr 

(5) The hourly emission rate of PM and PM10 each, in pounds per MMBtu (lbs/MMBtu). The hourly emission 

rates will be calculated from the hourly quantity of sub-bituminous and/or bituminous coal and/or natural gas 

determined in C1.4.b.(1) and (2) of this section, and the emission factor derived in C1.4.a.(7) of this section 

for coal combustion and emission factor (7.6 lb/106

 scf) as listed in AP-42, Table 1.4-2. for natural gas 

combustion. 

Sample Calculation: 

(tons-coal/Btu)(lbs-PM/tons-coal) = lbs-PM/Btu or lbs-PM/MMBtu 

(scf natural gas/Btu)(7.6 lb/106

 scf) = lbs-PM/Btu or lbs-PM/MMBtu – natural gas 

Sum: 

lbs-PM/MMBtu - Coal + lbs-PM/MMBtu – natural gas = Hourly Emission Rate in lbs-PM/MMBtu 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-20

Section VI. Specific Operating Conditions (continued)

C1. Emission Unit #S2.002 (continued) 

4. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Compliance, Monitoring, Recordkeeping and Reporting (continued) 

c. Recordkeeping (continued)

(6) The emission rates of sulfur and SO2 each, in pounds per hour (lbs/hr) and pounds per million Btu 

(lbs/MMbtu) measured by the CEMS required in C1.4.b.(8) of this section, for each averaging period 

described below: 

(i). The sulfur emissions in pounds per hour (lbs/hr) for each 1-hour period. Sulfur emissions will be one-half 

of the SO2 emissions measured. 

(ii). The sulfur and SO2 emissions in pounds per million Btu (lbs/MMBtu) for each 1-hour period. The 

conversion procedures established in 40 CFR Part 60.45(e) & (f) will be used to convert the continuous 

monitoring data into units of the applicable standard (lb/MMBtu, 3-hour rolling average period and 1-day 

average period). Sulfur emissions will be one-half of the SO2 emissions measured. 

(iii). The total SO2 emissions for a 10-day rolling average period (based on preceding last 10 days) in 

lbs/MMBtu. The SO2 emissions in lbs/MMBtu for each 1-day average period recorded in Section 

VI.C1.4.c.(6)(ii) will be used to calculate a 10-day rolling average period. 

(7) The measured opacity (in percent opacity) from the continuous opacity monitoring system required in 

C1.4.b.(10) of this section. The opacity will be determined from reducing all data from the successive 10-

second readings and recorded for the following: 

(i). Each 6-minute average as required in NAC 445B.22017.1(b) and as set forth in 40 CFR Part 60.13(h). 

d. Reporting

The Permittee will: 

(1) Report all excess emissions as required in Sections III.B and III.C of this operating permit. 

(2) Report all deviations as required in Section V.C of the operating permit. 

(3) Submit semi-annual monitoring reports as required in Section V.C of this operating permit. 

(4) Certify compliance with all applicable requirements as required in Section V.E of this operating permit. 

(5) Report the results of the performance tests and opacity observations required in C1.4.a.(8) of this section. 

(6) Federally Enforceable PSD Permit Requirement (PSD Permit Issued 1/3/80) - Submit a written report of 

excess emissions to the Administrator and the Director every calendar quarter. The report shall include: 

(i). The magnitude of excess emissions computed in accordance with 40 CFR 60.13(h), any conversion 

factor(s) used, and the date and time of commencement and completion of each time period of excess 

emissions. 

(ii). Specific identification of each period of excess emissions that occurs during start-ups, shutdowns, and 

malfunctions. The nature and cause of any malfunction (if known) and the corrective action taken or 

preventative measures adopted shall also be reported. 

(iii). The date and time identifying each period during which the continuous monitoring system was 

inoperative except for zero and span checks and the nature of the system repairs or adjustments. 

(iv). When no excess emissions have occurred or the continuous monitoring system has not been 

inoperative, repaired, or adjusted, such information shall be stated in the report. 

(v). Excess emissions shall be defined as any 3-hour rolling average period during which the average 

emissions of sulfur dioxide, as measured by the continuous monitoring system, exceeds the sulfur 

dioxide maximum limit in C1.2.a.(6) of this section. 

(vi). The Permittee shall maintain a file of all measurements, including continuous monitoring system, 

monitoring device, and performance testing measurements; all continuous monitoring system 

performance evaluations; all continuous monitoring system or monitoring device calibration checks; 

adjustments and maintenance performed on these systems or devices; and all other information required 

by 40 CFR part 60 recorded in a permanent form suitable for inspection. The file shall be retained for at 

least two years following the date of such measurements, maintenance, reports, and records. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-21

Section VI. Specific Operating Conditions (continued)

C1. Emission Unit #S2.002 (continued) 

4. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Compliance, Monitoring, Recordkeeping and Reporting (continued) 

d. Reporting (continued) 

(7) Consent Decree Requirements

The SO2 (lb/MMBtu) excess emissions shall also be defined as any 10-day rolling average period during which 

the average emissions of sulfur dioxide, as measured by the continuous monitoring system, exceeds the 

sulfur dioxide maximum limit in Section VI.C1.2.a.(6A). 

(8) Federally Enforceable PSD Permit Requirement (PSD Permit Issued 1/3/80) – The following reporting 

requirements apply only to Section VIII of the PSD Permit issued 1/3/80: 

The Regional Administrator (USEPA) shall be notified by telephone (by The Permitee) within 48 hours following 

any failure of air pollution control equipment, process equipment, or of a process to operate in a normal 

manner which results an increase in emissions above any allowable emissions limit stated in Section VIII of 

the USEPA-issued PSD permit dated January 3, 1980 of these conditions. In addition the Regional 

Administrator shall be notified in writing within fifteen (15) days of any such failure. This notification shall 

include a description of the malfunctioning equipment or abnormal operation, the date of the initial failure, the 

period of time over which emissions were increased due to failure, the cause of the failure, the estimated 

resultant emissions in excess of those allowed under Section VIII of these conditions, and the methods 

utilized to restore normal operations. Compliance with this malfunction notification provision shall not excuse 

or otherwise constitute a defense to any violations of this permit or of any law or regulations, which such 

malfunction, may cause. 

5. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Shielded Requirements

No specific shield requested.
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-22

Section VI. Specific Operating Conditions (continued)

D. Emission Unit #S2.002 - Alternative Operating Scenario: Co-Firing Coal and No. 2 Distillate Fuel Oil. 

UTM: North 4059.35 km, East 711.68 km (Zone 11)

System 02B Reid Gardner Unit No. 2 Steam Boiler, Coal Firing and No. 2 Distillate Fuel Oil. 

S2.002 Steam Boiler, Foster Wheeler, Model # 2-79-2106, Serial # 08-6374, Manufactured July 1968. 

1,215 million Btu/hr, Maximum Heat Input, Nominal 110.0 MW Output.

1. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Air Pollution Equipment

Emissions from S2.002 shall be ducted to the following emissions control system with 100% capture and a maximum 

volume flow rate of 25,000,000 standard cubic feet per hour (SCFH): 

a. Mechanical fly ash collectors for the control of particulate matter. 

b. Soda ash wet scrubber (Flue Gas Desulfurization – FGD) for the control of sulfur dioxide and particulate matter. 

c. Low NOx coal burners and over-fired air. 

The volumetric flow rate may be determined by utilizing Method 2 – Determination of Stack Gas Velocity and 

Volumetric Flow Rate as referenced in 40 CFR Part 60, Appendix A. 

2. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Emission Limits

a. On and after the date of startup of S2.002, the Permittee will not discharge or cause the discharge into the 

atmosphere from the exhaust stack of S2.002, the following pollutants in excess of the following specified limits 

while operating under this alternative operating scenario: 

(1) NAC 445B.2203 State-Only Requirement - The discharge of PM10 (particulate matter less than 10 microns in 

diameter) to the atmosphere will not exceed 0.20 pound per million Btu. 

(2) SIP 445.731 Federally Enforceable SIP - The discharge of PM (particulate matter) to the atmosphere will not 

exceed 0.20 pound per million Btu. 

(3) Article 8.2.1.2 Federally Enforceable SIP - The discharge of sulfur to the atmosphere will not exceed 724.14 

pounds per hour. 

(4) NAC 445B.22047 State-Only Requirement - The discharge of sulfur to the atmosphere will not exceed 

724.14 pounds per hour. 

(5) NAC 445B.22057 State-Only Requirement - The allowable emission of sulfur from fossil-fired power 

generating Unit Number Two of the Nevada Power Company’s Reid Gardner Station, located in air Quality 

Control Region 13, Basin 218, California Wash, must not be greater than 0.275 pound per million Btu. 

(6) NAC 445B.305 Federally Enforceable PSD Permit Requirement (PSD Permit Issued 1/3/80) - The discharge 

of SO2 to the atmosphere will not exceed 0.55 pound per million Btu (based on a 3-hour rolling average 

period). 

(7) SIP 445.721 Federally Enforceable SIP - The opacity from S2.002 will not equal or exceed 20% for a period 

or periods aggregating more than 3 minutes in any one hour. 

(8) NAC 445B.22017 State-Only Requirement - The opacity from S2.002 will not equal or exceed 20%. The 

opacity must be determined as set forth in 445B.22017.1(a) or (b). 

(9) NAC 445B.2202.6 State-Only Requirement - The opacity from S2.002 may exceed the level set in D.2.a.(8) 

of this section for the purposes of boiler lancing or soot blowing, not to exceed 180 minutes in any 

consecutive 24 hour period. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-23

Section VI. Specific Operating Conditions (continued)

D. Emission Unit #S2.002 - Alternative Operating Scenario: Co-Firing Coal and No. 2 Distillate Fuel Oil (continued) 

2. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Emission Limits (continued) 

b. Specific Acid Rain Requirements Parts 72 - 78 Acid Rain Program

(1) The Permittee will not exceed the SO2 and NOx emission levels (acid rain allowances) for the indicated 

years as shown in the following table without holding the required acid rain allowances in accordance with 

Section IV.B.2 of the Acid Rain provisions and pursuant to 40 CFR 72.9: 

Calendar Year 2001 2002 2003 2004 2005 

S2.002 SO2 Phase II Allowance 2,201 2,201 2,201 2,201 2,201 

S2.002 NOx Emission Limit (lb/MMBtu) 0.46 0.46 0.46 0.46 0.46 

(2) The Permittee will comply with the “Standard Requirements” provisions of the SO2 acid rain permit 

application dated January 26, 1995 entitled “Phase II Permit Application” and all references contained 

therein, which is hereby incorporated by reference into this operating document (Attachment 1). [NAC 

445B.305]. 

3. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Operating Parameters

a. While operating under this alternative operating scenario, S2.002 may co-fire sub-bituminous and/or 

bituminous coal and No. 2 distillate fuel oil for purposes of startup, shutdown and/or flame stabilization only. 

b. S2.002 may operate a total of 8,760 hours per calendar year. 

c. The maximum operating heat input rate for S2.002 while co-firing sub-bituminous and/or bituminous coal and No. 

2 distillate fuel oil will not exceed 1,215 million Btu per any one-hour period. 

4. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Compliance, Monitoring, Recordkeeping and Reporting

a. Compliance/Performance Testing

For each calendar year The Permittee operates S2.002 more than 500 hours under this alternative operating 

scenario, The Permittee will perform the following testing no later than 60 days after reaching the 500 hours of 

operation: 

(1) Conduct and record a Method 5 performance test for PM on the exhaust stack of S2.002 consisting of three 

valid runs. The Method 5 emissions test must be conducted in accordance with 40 CFR Part 60, Appendix 

A, Method 5, and include the back-half catch. 

(2) Conduct and record a Method 201A and 202 performance test for PM10 on the exhaust stack of S2.002 

consisting of three valid runs. The Method 201A and 202 emissions tests must be conducted in accordance 

with 40 CFR Part 51, Appendix M, Method 201A and 202. The Method 201A and 202 emissions tests may 

be replaced by a Method 5 performance test, including the back-half catch. All particulate captured in the 

Method 5 test will be considered PM10 for compliance demonstration purposes. 

(3) Conduct and record a Method 6 or 6C performance test for SO2 on the exhaust stack of S2.002 consisting of 

three valid runs. The Method 6 or 6C emissions test must be conducted in accordance with 40 CFR Part 60, 

Appendix A, Method 6 (PSD permit requirement VIII.B.2. issued January 3, 1980). 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-24

Section VI. Specific Operating Conditions (continued)

D. Emission Unit #S2.002 - Alternative Operating Scenario: Co-Firing Coal and No. 2Distillate Fuel Oil (continued) 

4. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Compliance, Monitoring, Recordkeeping and Reporting (continued) 

a. Compliance/Performance Testing (continued) 

(4) The performance tests will be conducted at the maximum operating heat input rate limit established in D.3.c 

of this section for each pollutant required to be tested, unless otherwise approved pursuant to NAC 

445B.252.3 & 4. The Permittee shall make available to the director such records as may be necessary to 

determine the conditions of the test of performance. Operations during periods of startup, shutdown and 

malfunction must not constitute representative conditions of a test of performance unless otherwise specified 

in the applicable standard (NAC 445B.252.3). Should any anticipated major boiler overhaul(s) be scheduled 

to be performed, which coincide with the performance tests, the performance testing will be performed prior 

to the overhaul(s). If the performance testing can not be performed prior to a major boiler overhaul, the 

testing will be performed as soon as practicable following the overhaul(s), but not earlier than 60 days 

following the overhaul. 

(5) The Permittee shall give notice to the director 30 days before the test of performance to allow the director to 

have an observer present. A written testing procedure for the test of performance must be submitted to the 

director at least 30 days before the test of performance to allow the director to review the proposed testing 

procedures (NAC 445B.252.4). 

(6) During each performance test required in D.4.a.(1) through (3) of this section, record the quantity (in tons) of 

coal combusted, the No. 2 distillate fuel oil (in-pounds-mass), the heat content value of the coal (in Btu per 

ton) and No. 2 distillate fuel oil (in Btu per pound) combusted during each test run (in Btu per ton) and 

include these data in the test results submitted. The oil sampling and analysis procedures contained in 40 

CFR Part 75, Appendix D, Section 2.2.4 will be used to determine the No.2 distillate fuel oil parameters. The 

emissions results of the Method 6 or 6C performance test for SO2 must be converted to emissions of sulfur 

(both lb/hr and lb/MMBtu). The emissions results of the Method 5 performance test for PM and Method 5 or 

Method 201A and 202 performance test for PM10 must be reported in lb/MMBtu. 

(7) As a result of the most recent performance test performed in D.4.a.(1) through (3) of this section, derive 

emission factors for each of the following: 

(i). Pounds of PM per ton of coal (lbs-PM/tons-coal). 

(ii). Pounds of PM10 per ton of coal (lbs-PM10/tons-coal). 

(iii). Pounds of PM per ton of No. 2 distillate fuel oil (lbs-PM/lbm-No. 2 Distillate). 

(iv). Pounds of PM10 per ton of No. 2 distillate fuel oil (lbs-PM10/lbm-No. 2 Distillate). 

These emissions factors will be based on the average of the 3 test runs. 

(8) Within 60 days after completing the performance tests contained in D.4.a. of this section, the Permittee shall 

furnish the director a written report of the results of the performance tests and the resultant emissions 

factors. All information and analytical results of testing and sampling must be certified as to the truth and 

accuracy and as to their compliance with NAC 445B.001 to 445B.3485 (NAC 445B.252.8). 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-25

Section VI. Specific Operating Conditions (continued)

D. Emission Unit #S2.002 - Alternative Operating Scenario: Co-Firing Coal and No. 2 Distillate Fuel Oil (continued) 

4. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Compliance, Monitoring, Recordkeeping and Reporting (continued) 

b. Monitoring

The Permittee, upon issuance of this operating permit will: 

(1) Install, calibrate, operate and maintain a coal mass measurement device to continuously measure the 

amount of sub-bituminous and/or bituminous coal (in tons) combusted in S2.002. The coal mass 

measurement device will be installed at an appropriate location in the fuel delivery system to accurately and 

continuously measure the fuel combusted in S2.002. 

(2) Install, calibrate, operate and maintain a fuel flow meter to continuously record the mass amount (in poundsmass) of No. 2 distillate fuel oil combusted in S2.002. The fuel flow meter will be installed at an appropriate 

location in the fuel delivery system to accurately and continuously measure the fuel combusted in S2.002 in 

accordance with the requirements prescribed in 40 CFR Part 75. 

(3) Install, calibrate, operate and maintain a Continuous Data Collection System (CDCS) to continuously record 

the quantity (in tons) of sub-bituminous and/or bituminous coal as measured by the coal mass measurement 

device and the mass amount (in pounds-mass) of the No. 2 distillate fuel oil as measured by the fuel flow 

meter required in D.4.b.(1) & (2) of this section. The CDCS will be installed, calibrated, operated and 

maintained in accordance with the manufacturer’s specifications and the requirements prescribed in 40 CFR 

Part 75. 

(4) Perform coal sampling of the coal prior to it entering the boiler. Sampling shall be conducted for moisture, 

ash, sulfur content, and gross calorific value. A coal analysis shall be performed weekly and the results of 

these analyses shall be retained for at least two years following the date of the measurement. All sample 

collection, sample preparation, and analyses performed or caused to be performed shall be conducted 

according to the most current ASTM methods (PSD permit requirement VIII.E. issued January 3, 1980). 

(5) Perform coal sampling of the sub-bituminous and/or bituminous coal weekly according to section 12.5.3.2.2 

in Method 19 in appendix A to Part 60 and use ASTM Method D2234-89, “Standard Test Methods for 

Collection of a Gross Sample of Coal.” Determine the gross calorific value of the sub-bituminous and/or 

bituminous coal combusted by sampling at least once weekly, using ASTM D2013-86, “Standard Method of 

Preparing Coal Samples for Analysis”, ASTM D2015-91, “Standard Test Method for Gross Calorific Value of 

Coal and Coke by the Adiabatic Bomb Calorimeter”, ASTM 1989-92, “Standard test Method for Gross 

Calorific Value of Coal and Coke by Microprocessor Controlled Isoperibol Calorimeters”, or ASTM 3286-91a, 

“Standard Test Method for Gross Calorific Value of Coal and Coke by the Isoperibol Bomb Calorimeter.” 

(6) Using either the Flow Proportional or Daily Method described in 40 CFR Part 75, Appendix D 2.2.2, 2.2.3, or 

2.2.4 prepare a daily sample representative of the No. 2 distillate fuel oil combusted in S2.002 for each day 

of operation while combusting that fuel. The sulfur content of the daily fuel oil sample shall be determined in 

accordance with the requirements prescribed in 40 CFR Part 75, Appendix D. The fuel oil gross calorific 

value of this daily sample will be determined in accordance with ASTM D240-87 (Re-approved 1991), 

“Standard Test Method for Heat of Combustion of Liquid Hydrocarbon Fuels by Bomb Calorimeter” or ASTM 

D2382-88, “Standard Test Method for Heat or Combustion of Hydrocarbon Fuels by Bomb Calorimeter (High 

Precision Method) and the requirements prescribed in 40 CFR Part 75, Appendix F, Section 3.3.6.2.” 

Alternatively, an estimated maximum gross calorific value of 20,000 Btu per pound (Btu/lb) @ 7.4 pounds per 

gallon (lb/gal) for No. 2 distillate fuel oil may be used. 

(7) Substitute any missing fuel flow meter data in accordance with the requirements prescribed in 40 CFR Part 

75, Appendix D, Section 2.4.2. Substitute any missing sulfur content data for the No. 2 distillate fuel oil in 

accordance with the requirements prescribed in 40 CFR Part 75, Appendix D, Section 2.4.1. Substitute any 

missing gross calorific value data for the No. 2 distillate fuel oil in accordance with the requirements 

prescribed in 40 CFR Part 75, Appendix D, Section 2.4.1. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-26

Section VI. Specific Operating Conditions (continued)

D. Emission Unit #S2.002 - Alternative Operating Scenario: Co-Firing Coal and No. 2 Distillate Fuel Oil (continued)

4. NAC 445B.3405 (NAC 445B.316) Part 70 Program

b. Monitoring (continued) 

(8) Install, calibrate, operate and maintain a SO2 continuous emissions monitor system (CEMS) (consisting of a 

SO2 pollutant concentration monitor and a flow monitoring system) to continuously measure the 

concentration of SO2 (in ppm), volumetric gas flow (in scfh), and SO2 mass emissions (in lb/hr and lb/MMBtu) 

from S2.002. The CEMS will be installed at an appropriate location in the exhaust stack of S2.002 to 

accurately and continuously measure the SO2 concentration in S2.002 in accordance with the requirements 

prescribed in 40 CFR Part 60.13 and 40 CFR Part 60, Appendix B, Performance Specification 2 (PSD permit 

requirement VIII.D.2.a. issued January 3, 1980), 40 CFR Part 75, Part 75.11 and Appendix F. 

(9) Install, calibrate, operate and maintain a Continuous Data Collection System (CDCS) to continuously record 

the SO2 concentration (in ppm), volumetric gas flow (in scfh), and SO2 mass emissions (in lb/hr and 

lb/MMBtu), as measured by the CEMS required in D.4.b.(8) of this section. The CDCS will be installed, 

calibrated, operated and maintained in accordance with the manufacturer’s specifications and the 

requirements prescribed in 40 CFR Part 60.13 and 40 CFR Part 60, Appendix B, Performance Specification 

2 (PSD permit requirement VIII.D.2.a. issued January 3, 1980), 40 CFR Part 75, Part 75.11 and Appendix F. 

(10) Install, calibrate, operate and maintain a continuous opacity monitoring system to continuously measure and 

record the opacity from S2.002. The continuous opacity monitoring system will be installed at an appropriate 

location in the discharge stack of S2.002 to accurately and continuously measure the opacity of S2.002 in 

accordance with the requirements prescribed in NAC 445B.256 to NAC 445B.267 and 40 CFR Part 75.10. 

(11) Install, calibrate, operate and maintain a Continuous Data Collection System (CDCS) to continuously record 

the opacity (in percent opacity) as measured by the continuous opacity monitoring system required in 

D.4.b.(10) of this section. The CDCS will be installed, calibrated, operated and maintained in accordance 

with the manufacturer’s specifications and the requirements prescribed in NAC 445B.256 to NAC 445B.267, 

40 CFR Part 75.10 and 40 CFR Part 75.14. 

c. Recordkeeping

The Permittee will maintain a contemporaneous log containing at a minimum, the following recordkeeping for 

each day, or part of a day that S2.002 is operating under this alternative operating scenario: 

(1) The name of the operating scenario, the type(s) of fuel(s) combusted and the calendar date of any required 

monitoring, including the date and time of switching from one operating scenario to another. 

(2) The total hourly quantity of co-fired sub-bituminous and/or bituminous coal (in tons) and the mass amount of 

No. 2 distillate fuel oil in pounds-mass (lbm) combusted, for each hour of operation based on the data 

recorded by the CDCS as required in D.4.b.(3) of this section. 

(3) The total daily hours of operation for the corresponding date. 

(4) The heat content of each fuel combusted for the corresponding date, in Btu/ton (coal) and Btu/pound (No. 2 

distillate fuel oil). The heat content for each fuel will be based on the gross calorific value determined in 

D.4.b.(5) & (6) of this section. 

(5) The hourly heat input of the co-fired sub-bituminous and/or bituminous coal and No. 2 distillate fuel oil 

combusted, in MMBtu per hour. The hourly heat inputs will be calculated from the hourly fuel usage rates 

recorded in D.4.c.(2) of this section, and the heat content of the fuel as recorded in D.4.c.(4) of this section. 

Sample Calculation: 

(tons-coal/hr)(Btu/ton-coal) = Btu/hr or MMBtu/hr 

(lbm-No. 2 Distillate/hr)(Btu/lbs) = Btu/hr or MMBtu/hr - No. 2 Distillate 

Sum: 

MMBtu/hr - Coal + MMBtu/hr - No. 2 Distillate = Hourly Heat Input in MMBtu/hr 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-27

Section VI. Specific Operating Conditions (continued)

D. Emission Unit #S2.002 - Alternative Operating Scenario: Co-Firing Coal and No. 2 Distillate Fuel Oil (continued) 

c. Recordkeeping (continued) 

(6) The hourly emission rate of PM and PM10 each, in pounds per MMBtu (lbs/MMBtu). The hourly emission rates 

will be calculated from the hourly quantity of co-fired sub-bituminous and/or bituminous coal and No. 2 distillate 

fuel oil determined in D.4.b.(3) of this section, and the emission factor derived in D.4.a.(7) of this section. 

Sample Calculation: 

(tons-coal/Btu)(lbs-PM/tons-coal) = lbs-PM/Btu or lbs-PM/MMBtu 

(lbm-No. 2 Distillate/Btu)(lbs-PM/lbm-No. 2 Distillate) = lbs-PM/Btu or lbs-PM/MMBtu – No. 2 Distillate 

Sum: 

lbs-PM/MMBtu - Coal + lbs-PM/MMBtu - No. 2 Distillate = Hourly Emission Rate in lbs-PM/MMBtu 

(7) The emission rates of sulfur and SO2 each, in pounds per hour (lbs/hr) and pounds per million Btu (lbs/MMbtu) 

measured by the CEMS required in D.4.b.(8) of this section, for each averaging period described below: 

(i). The sulfur emissions in pounds per hour (lbs/hr) for each 1-hour period. Sulfur emissions will be one-half of 

the SO2 emissions measured. 

(ii). The sulfur and SO2 emissions in pounds per million Btu (lbs/MMBtu) for each 1-hour period. The conversion 

procedures established in 40 CFR Part 60.45(e) & (f) will be used to convert the continuous monitoring data 

into units of the applicable standard (lb/MMBtu, 3-hour average period). Sulfur emissions will be one-half of 

the SO2 emissions measured. 

(8) The measured opacity (in percent opacity) from the continuous opacity monitoring system required in D.4.b.(10) 

of this section. The opacity will be determined from reducing all data from the successive 10-second readings 

and recorded for the following: 

(i). Each 6-minute average as required in NAC 445B.22017.1(b) and as set forth in 40 CFR Part 60.13(h). 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-28

Section VI. Specific Operating Conditions (continued)

D. Emission Unit #S2.002 - Alternative Operating Scenario: Co-Firing Coal and No. 2 Distillate Fuel Oil (continued)

d. Reporting

The Permittee will: 

(1) Report all excess emissions as required in Sections III.B and III.C of this operating permit. 

(2) Report all deviations as required in Section V.C of the operating permit. 

(3) Submit semi-annual monitoring reports as required in Section V.C of this operating permit. 

(4) Certify compliance with all applicable requirements as required in Section V.E of this operating permit. 

(5) Report the results of the performance tests and opacity observations required in D.4.a.(8) of this section. 

(6) Federally Enforceable PSD Permit Requirement (PSD Permit Issued 1/3/80) - Submit a written report of excess 

emissions to the Administrator and the Director every calendar quarter. The report shall include: 

(i). The magnitude of excess emissions computed in accordance with 40 CFR 60.13(h), any conversion factor(s) 

used, and the date and time of commencement and completion of each time period of excess emissions. 

(ii). Specific identification of each period of excess emissions that occurs during start-ups, shutdowns, and 

malfunctions. The nature and cause of any malfunction (if known) and the corrective action taken or 

preventative measures adopted shall also be reported. 

(iii). The date and time identifying each period during which the continuous monitoring system was inoperative 

except for zero and span checks and the nature of the system repairs or adjustments. 

(iv). When no excess emissions have occurred or the continuous monitoring system has not been inoperative, 

repaired, or adjusted, such information shall be stated in the report. 

(v). Excess emissions shall be defined as any three-hour period during which the average emissions of sulfur 

dioxide, as measured by the continuous monitoring system, exceeds the sulfur dioxide maximum limit in 

D.2.a.(6) of this section. 

(vi). The Permittee shall maintain a file of all measurements, including continuous monitoring system, monitoring 

device, and performance testing measurements; all continuous monitoring system performance evaluations; 

all continuous monitoring system or monitoring device calibration checks; adjustments and maintenance 

performed on these systems or devices; and all other information required by 40 CFR part 60 recorded in a 

permanent form suitable for inspection. The file shall be retained for at least two years following the date of 

such measurements, maintenance, reports, and records. 

(7) Federally Enforceable PSD Permit Requirement (PSD Permit Issued 1/3/80) – The following reporting 

requirements apply only to Section VIII of the PSD Permit issued 1/3/80: 

The Regional Administrator (USEPA) shall be notified by telephone (by The Permitee) within 48 hours following 

any failure of air pollution control equipment, process equipment, or of a process to operate in a normal manner 

which results an increase in emissions above any allowable emissions limit stated in Section VIII of the USEPAissued PSD permit dated January 3, 1980 of these conditions. In addition the Regional Administrator shall be 

notified in writing within fifteen (15) days of any such failure. This notification shall include a description of the 

malfunctioning equipment or abnormal operation, the date of the initial failure, the period of time over which 

emissions were increased due to failure, the cause of the failure, the estimated resultant emissions in excess of 

those allowed under Section VIII of these conditions, and the methods utilized to restore normal operations. 

Compliance with this malfunction notification provision shall not excuse or otherwise constitute a defense to any 

violations of this permit or of any law or regulations, which such malfunction, may cause. 

5. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Shielded Requirements

No specific shield requested. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-29

Section VI. Specific Operating Conditions (continued)

E. Emission Unit #S2.003: UTM: North 4059.28 km, East 711.68 km (Zone 11) 

System 03 Reid Gardner Unit #3 Steam Boiler, 100% Coal Fired with Natural Gas Igniters. 

S2.003 Steam Boiler, Foster Wheeler, Model # 279-1554, Serial # 08-1544, Manufactured July 1976. 

1,237 million Btu/hr, Maximum Heat Input, Nominal 110.0 MW Output.

1. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Air Pollution Equipment

Emissions from S2.003 shall be ducted to the following emissions control system with 100% capture and a maximum 

volume flow rate of 28,000,000 standard cubic feet per hour (SCFH): 

a. Mechanical fly ash collectors for the control of particulate matter. 

b. Soda ash wet scrubber (Flue Gas Desulfurization – FGD) for the control of sulfur dioxide and particulate matter. 

c. Low NOx coal burners and over-fired air. 

d. Baghouse (complete installation and operation no later than July 1, 2010). 

The volumetric flow rate may be determined by utilizing Method 2 – Determination of Stack Gas Velocity and 

Volumetric Flow Rate as referenced in 40 CFR Part 60, Appendix A. 

2. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Emission Limits

a. On and after the date of startup of S2.003, the Permittee will not discharge or cause the discharge into the 

atmosphere from the exhaust stack of S2.003, the following pollutants in excess of the following specified limits: 

(1) NAC 445B.2203 State-Only Requirement - The discharge of PM10 (particulate matter less than 10 microns in 

diameter) to the atmosphere will not exceed 0.20 pound per million Btu. 

(2) SIP 445.731 Federally Enforceable SIP - The discharge of PM (particulate matter) to the atmosphere will not 

exceed 0.20 pound per million Btu. 

(3) 40 CFR Part 60.42(a)(1) Federally Enforceable New Source Performance Standard Requirement - On and 

after the date on which the performance test required to be conducted by Sec. 60.8 is completed, no owner 

or operator subject to the provisions of this subpart shall cause to be discharged into the atmosphere from 

any affected facility any gases which contain particulate matter in excess of 43 nanograms per joule heat 

input (0.10 lb per million Btu). 

(4) Article 8.2.1.2 Federally Enforceable SIP - The discharge of sulfur to the atmosphere will not exceed 737.25 

pounds per hour. 

(5) NAC 445B.22047 State-Only Requirement - The discharge of sulfur to the atmosphere will not exceed 

737.25 pounds per hour. 

(6) NAC 445B.22057 State-Only Requirement - The allowable emission of sulfur from fossil-fired power 

generating Unit Number Three of the Nevada Power Company’s Reid Gardner Station, located in air Quality 

Control Region 13, Basin 218, California Wash, must not be greater than 0.275 pound per million Btu. 

(7) NAC 445B.305 Federally Enforceable PSD Permit Requirement (PSD Permit Issued 1/3/80) - The discharge 

of SO2 to the atmosphere will not exceed 0.55 pound per million Btu (based on a 3-hour rolling average 

period). 

(7A)NAC 445B.305 (Consent Decree Requirements) - The discharge of SO2 to the atmosphere will not exceed

0.40 pound per million Btu (based on a 10-day rolling average period). 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-30

Section VI. Specific Operating Conditions (continued)

E. Emission Unit #S2.003 (continued)

2. NAC 445B.3405 (NAC 445B.316) Part 70 Program

a. Emission Limits (continued) 

(8) 40 CFR Part 60.43(a)(2) Federally Enforceable New Source Performance Standard Requirement - On and 

after the date on which the performance test required to be conducted by Sec. 60.8 is completed, no owner 

or operator subject to the provisions of this subpart shall cause to be discharged into the atmosphere from 

any affected facility any gases which contain sulfur dioxide in excess of 520 nonograms per joule heat input 

(1.2 lb per million Btu). 

(9) 40 CFR Part 60.44(a)(3) Federally Enforceable New Source Performance Standard Requirement - On and 

after the date on which the performance test required to be conducted by Sec. 60.8 is completed, no owner 

or operator subject to the provisions of this subpart shall cause to be discharged into the atmosphere from 

any affected facility any gases which contain nitrogen oxides, expressed as NO2 in excess of 300 nanograms 

per joule heat input (0.70 lb per million Btu). 

(10) SIP 445.721 Federally Enforceable SIP - The opacity from S2.003 will not equal or exceed 20% for a period 

or periods aggregating more than 3 minutes in any one hour. 

(11) NAC 445B.22017 State-Only Requirement - The opacity from S2.003 will not equal or exceed 20%. The 

opacity must be determined as set forth in 445B.22017.1(a) or (b). S2.003 is allowed one 6-minute period 

per hour of not more than 27 percent opacity as set forth in 40 CFR part 60.42(a)(2). 

(12) NAC 445B.2202.6 State-Only Requirement - The opacity from S2.003 may exceed the level set in E.2.a.(11) 

of this section for the purposes of boiler lancing or soot blowing, not to exceed 180 minutes in any 

consecutive 24 hour period. 

(13) 40 CFR Part 60.42(a)(2) Federally Enforceable New Source Performance Standard Requirement - On and 

after the date on which the performance test required to be conducted by Sec. 60.8 is completed, no owner 

or operator subject to the provisions of this subpart shall cause to be discharged into the atmosphere from 

any affected facility any gases which exhibit greater than 20 percent opacity except for one six-minute period 

per hour of not more than 27 percent opacity. 

b. Specific Acid Rain Requirements Parts 72 - 78 Acid Rain Program

(1) The Permittee will not exceed the SO2 and NOx emission levels (acid rain allowances) for the indicated 

years as shown in the following table without holding the required acid rain allowances in accordance with 

Section IV.B.2 of the Acid Rain provisions and pursuant to 40 CFR 72.9: 

Calendar Year 2001 2002 2003 2004 2005 

S2.003 SO2 Phase II Allowance 2,124 2,124 2,124 2,124 2,124 

S2.003 NOx Emission Limit (lb/MMBtu) 0.46 0.46 0.46 0.46 0.46 

(2) The Permittee will comply with the “Standard Requirements” provisions of the SO2 acid rain permit 

application dated January 26, 1995 entitled “Phase II Permit Application” and all references contained 

therein, which is hereby incorporated by reference into this operating document (Attachment 1). [NAC 

445B.305]. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-31

Section VI. Specific Operating Conditions (continued)

E. Emission Unit #S2.003 (continued)

3. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Operating Parameters

a. S2.003 will combust sub-bituminous and/or bituminous coal; and/or natural gas for purposes of startup, shutdown 

and/or flame stabilization only. 

b. S2.003 may operate a total of 8,760 hours per calendar year. 

c. The maximum operating heat input rate for S2.003 while combusting sub-bituminous and/or bituminous coal and 

natural gas will not exceed 1,237 million Btu per any one-hour period. 

4. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Compliance, Monitoring, Recordkeeping and Reporting 

a. Compliance/Performance Testing

Within 180 days of the date of issuance of this operating permit, and once annually thereafter, The Permittee

will: 

(1) Conduct and record a Method 5 performance test for PM on the exhaust stack of S2.003 consisting of three 

valid runs. The Method 5 emissions test must be conducted in accordance with 40 CFR Part 60, Appendix 

A, Method 5, and include the back-half catch. The sampling time and sample volume for each run shall be at 

least 60 minutes and 0.85 dscm (30 dscf). The probe and filter holder heating systems in the sampling train 

shall be set to provide an average gas temperature of 160+/- 140C (320+/- 250F). The emission rate 

correction factor, integrated or grab sampling and analysis procedure of Method 3B shall be used to 

determine the O2 concentration (%O2). The O2 sample shall be obtained simultaneously with, and at the 

same traverse points as, the particulate sample. If the grab sampling procedure is used, the O2

concentration for the run shall be the arithmetic mean of the sample O2 concentrations at all traverse points. 

If the particulate run has more than 12 traverse points, the O2 traverse points may be reduced to 12 provided 

that Method 1 is used to locate the 12 O2 traverse points (40 CFR Part 60.46(b)(2)). 

(2) Conduct and record a Method 201A and 202 performance test for PM10 on the exhaust stack of S2.003 

consisting of three valid runs. The Method 201A and 202 emissions tests must be conducted in accordance 

with 40 CFR Part 51, Appendix M, Method 201A and 202. The Method 201A and 202 emissions tests may 

be replaced by the Method 5 performance test required in E.4.a.(1) above. All particulate captured in the 

Method 5 test will be considered PM10 for compliance demonstration purposes. 

(3) Conduct and record a Method 6 performance test for SO2 on the exhaust stack of S2.003 consisting of three 

valid runs. The Method 6 emissions test must be conducted in accordance with 40 CFR Part 60, Appendix 

A, Method 6 (PSD permit requirement VIII.B.2. issued January 3, 1980). The sampling site shall be the 

same as that selected for the particulate sample required in E.4.a.(1). The sampling location in the duct shall 

be at the centroid of the cross section or at a point no closer to the walls than 1 m (3.28 ft). The sampling 

time and sample volume for each sample run shall be at least 20 minutes and 0.020 dscm (0.71 dscf). Two 

samples shall be taken during a 1-hour period, with each sample taken within a 30-minute interval. The 

emission rate correction factor, integrated sampling and analysis procedure of Method 3B shall be used to 

determine the O2 concentration (%O2). The O2 sample shall be taken simultaneously with, and at the same 

point as, the SO2 sample. The SO2 emission rate shall be computed for each pair of SO2 and O2 samples. 

The SO2 emission rate (E) for each run shall be the arithmetic mean of the results of the two pairs of samples 

(40 CFR Part 60.46(b)(4)). 

(4) Conduct and record a Method 7 performance test for NOx on the exhaust stack of S2.003 consisting of three 

valid runs. The Method 7 emissions test must be conducted in accordance with 40 CFR Part 60, Appendix 

A, Method 7. The sampling site and location shall be the same as for the SO2 sample required in E.4.a.(3). 

Each run shall consist of four grab samples, with each sample taken at about 15-minute intervals. For each 

NOx sample, the emission rate correction factor, grab sampling and analysis procedure of Method 3B shall 

be used to determine the O2 concentration (%O2). The O2 sample shall be taken simultaneously with, and at 

the same point as, the NOx sample. The NOx emission rate shall be computed for each pair of NOx and O2

samples. The NOx emission rate (E) for each run shall be the arithmetic mean of the results of the four pairs 

of samples (40 CFR Part 60.46(b)(5)). 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-32

Section VI. Specific Operating Conditions (continued)

E. Emission Unit #S2.003 (continued)

4. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Compliance, Monitoring, Recordkeeping and Reporting (continued) 

a. Compliance/Performance Testing (continued)

(5) During one of the three test runs required in E.4.a.(1) of this section, conduct and record a Method 9 visual 

opacity observation of the discharge from the exhaust stack of S2.003. The Method 9 opacity test must be 

conducted in accordance with the visible emissions evaluation procedures contained in 40 CFR Part 60, 

Appendix A, Method 9. A certified visible emissions reader must conduct the visible emissions evaluations 

for a period of at least 6 minutes. The opacity readings must be averaged such that compliance with both a 

6-minute average and 2, 3-minute averages are determined (40 CFR Part 60.46(b)(3)). 

(6) The performance tests will be conducted at the maximum operating heat input rate limit established in E.3.c 

of this section for each pollutant required to be tested, unless otherwise approved pursuant to NAC 

445B.252.3 & 4. The Permittee shall make available to the director such records as may be necessary to 

determine the conditions of the test of performance. Operations during periods of startup, shutdown and 

malfunction must not constitute representative conditions of a test of performance unless otherwise specified 

in the applicable standard (NAC 445B.252.3). Should any anticipated major boiler overhaul(s) be scheduled 

to be performed, which coincide with the performance tests, the performance testing will be performed prior 

to the overhaul(s). If the performance testing can not be performed prior to a major boiler overhaul, the 

testing will be performed as soon as practicable following the overhaul(s), but not earlier than 60 days 

following the overhaul. 

(7) The Permittee shall give notice to the director 30 days before the test of performance to allow the director to 

have an observer present. A written testing procedure for the test of performance must be submitted to the 

director at least 30 days before the test of performance to allow the director to review the proposed testing 

procedures (NAC 445B.252.4). The alternatives to the reference methods and procedures provided in 40 

CFR Part 60.46(d) may be utilized to the extent that they are applicable to S2.003, and must be identified in 

the testing procedures as alternative methods. 

(8) During each performance test required in E.4.a.(1) through (4) of this section, record the quantity (in tons) of 

coal combusted during each test run, the heat content value of the coal combusted during each test run (in 

Btu/ton) and include these data in the test results submitted. The emissions results of the Method 6 and 

Method 7 performance tests for SO2 and NOx must be converted to emissions of sulfur (both lb/hr and 

lb/MMBtu) and emissions of nitrogen oxides (lb/MMbtu). The emissions results of the Method 5 performance 

test for PM and Method 5 or Method 201A and 202 performance tests for PM10 must be reported in 

lb/MMBtu. The emission rate (E) of particulate matter, SO2, and NOx shall be computed for each run using 

the following formula (40 CFR Part 60.46(b)(1): 

E = C Fd (20.9)/(20.9-% O2) 

E = emission rate of pollutant , ng/J (lb/million Btu) 

C = concentration of pollutant, ng/dscm (lb/dscf) 

% O2 = oxygen concentration, percent dry basis 

Fd = factor as determined from Method 19. 

(9) As a result of the most recent performance test performed in E.4.a.(1) through (4) of this section, derive 

emission factors for each of the following: 

(i). Pounds of PM per ton of coal (lbs-PM/tons-coal). 

(ii). Pounds of PM10 per ton of coal (lbs-PM10/tons-coal). 

These emissions factors will be based on the average of the 3 test runs. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-33

Section VI. Specific Operating Conditions (continued)

E. Emission Unit #S2.003 (continued)

4. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Compliance, Monitoring, Recordkeeping and Reporting (continued) 

a. Compliance/Performance Testing (continued)

(10) Within 60 days after completing the performance tests and opacity observations contained in E.4.a. of this 

section, the Permittee shall furnish the director a written report of the results of the performance tests, the 

opacity observations and the resultant emissions factors. All information and analytical results of testing and 

sampling must be certified as to the truth and accuracy and as to their compliance with NAC 445B.001 to 

445B.3485 (NAC 445B.252.8). 

b. Monitoring

The Permittee, upon issuance of this operating permit will: 

(1) Install, calibrate, operate and maintain a coal mass measurement device to continuously measure the 

amount of sub-bituminous and/or bituminous coal (in tons) combusted in S2.003. The coal mass 

measurement device will be installed at an appropriate location in the fuel delivery system to accurately and 

continuously measure the fuel combusted in S2.003. 

(2) Install, calibrate, operate and maintain a fuel flow meter to continuously record the volume (in standard cubic 

feet) of natural gas combusted in S2.003. The fuel flow meter will be installed at an appropriate location in 

the fuel delivery system to accurately and continuously measure the fuel combusted in S2.003 in accordance 

with the requirements prescribed in 40 CFR Part 75. 

(3) Install, calibrate, operate and maintain a Continuous Data Collection System (CDCS) to continuously record 

the quantity (in tons) of sub-bituminous and/or bituminous coal as measured by the coal mass measurement 

device and the quantity of natural gas (in standard cubic feet) as measured by the fuel flow meter as required 

in E.4.b.(1) and (2) of this section. The CDCS will be installed, calibrated, operated and maintained in 

accordance with the manufacturer’s specifications. 

(4) Perform coal sampling of the coal prior to it entering the boiler. Sampling shall be conducted for moisture, 

ash, sulfur content, and gross calorific value. A coal analysis shall be performed weekly and the results of 

these analyses shall be retained for at least two years following the date of the measurement. All sample 

collection, sample preparation, and analyses performed or caused to be performed shall be conducted 

according to the most current ASTM methods (PSD permit requirement VIII.E. issued January 3, 1980). 

(5) Perform coal sampling of the sub-bituminous and/or bituminous coal weekly according to section 12.5.3.2.2 

in Method 19 in appendix A to Part 60 and use ASTM Method D2234-89, “Standard Test Methods for 

Collection of a Gross Sample of Coal.” Determine the gross calorific value of the sub-bituminous and/or 

bituminous coal combusted by sampling at least once weekly, using ASTM D2013-86, “Standard Method of 

Preparing Coal Samples for Analysis”, ASTM D2015-91, “Standard Test Method for Gross Calorific Value of 

Coal and Coke by the Adiabatic Bomb Calorimeter”, ASTM 1989-92, “Standard test Method for Gross 

Calorific Value of Coal and Coke by Microprocessor Controlled Isoperibol Calorimeters”, or ASTM 3286-91a, 

“Standard Test Method for Gross Calorific Value of Coal and Coke by the Isoperibol Bomb Calorimeter.” 

(6) Maintain on site, monthly analysis of calorific value of natural gas provided by natural gas supplier. 

(7) Substitute any missing fuel flow meter data in accordance with the requirements prescribed in 40 CFR Part 

75, Appendix D, Section 2.4.2. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-34

Section VI. Specific Operating Conditions (continued)

E. Emission Unit #S2.003 (continued)

4. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Compliance, Monitoring, Recordkeeping and Reporting (continued) 

b. Monitoring (continued)

(8) Install, calibrate, operate and maintain a SO2 continuous emissions monitor system (CEMS) (consisting of a 

SO2 pollutant concentration monitor and a flow monitoring device) to continuously measure the concentration 

of SO2 (in ppm), volumetric gas flow (in scfh), and SO2 mass emissions (in lb/hr and lb/MMBtu) from S2.003. 

The CEMS will be installed at an appropriate location in the exhaust stack of S2.003 to accurately and 

continuously measure the SO2 concentration in S2.003 in accordance with the requirements prescribed in 40 

CFR Part 60.13 and 40 CFR Part 60, Appendix B, Performance Specification 2, 40 CFR Part 60.45(a), 40 

CFR Part 60, Appendix B, Performance Specification 2, 40 CFR Part 75, Part 75.11 and Appendix F. For 

performance evaluations under 40 CFR Part 60.13(c) and calibration checks under 60.13(d), Method 6 and 

3B shall be used for the performance evaluations of sulfur dioxide (40 CFR Part 60.45(c)(1)). Sulfur dioxide 

shall be used for preparing calibration gas mixtures under Performance Specification 2 of Appendix B of 40 

CFR Part 60 (40 CFR Part 60.45(c)(2)). The span value for the CEMS shall be determined in accordance 

with the provisions contained in 40 CFR Part 60.45(c)(3) & (4). 

(9) Install, calibrate, operate and maintain a Continuous Data Collection System (CDCS) to continuously record 

the SO2 concentration (in ppm), volumetric gas flow (in scfh), and SO2 mass emissions (in lb/hr and 

lb/MMBtu) on 1-hour average period and SO2 mass emissions (in lb/MMBtu) on 3-hour rolling average period 

and 1-day average period, as measured by the CEMS required in E.4.b.(8) of this section. The CDCS will be 

installed, calibrated, operated and maintained in accordance with the manufacturer’s specifications and the 

requirements prescribed in 40 CFR Part 60.13 and 40 CFR Part 60, Appendix B, Performance Specification 

2, 40 CFR Part 60.45(a), 40 CFR Part 60, Appendix B, Performance Specifications, 40 CFR Part 75, Part 

75.11 and Appendix F. 

(10) Install, calibrate, operate and maintain a NOx continuous emissions monitor system (CEMS) (consisting of a 

NOx pollutant concentration monitor and a flow monitoring device) to continuously measure the concentration 

of NOx (in ppm), volumetric gas flow (in scfh), and NOx mass emissions (in lb/MMBtu) from S2.003. The 

CEMS will be installed at an appropriate location in the exhaust stack of S2.003 to accurately and 

continuously measure the NOx concentration in S2.003 in accordance with the requirements prescribed in 40 

CFR Part 60.45(a), 40 CFR Part 60, Appendix B, Performance Specification 2, 40 CFR Part 75, Part 75.11 

and Appendix F. For performance evaluations under 40 CFR Part 60.13(c) and calibration checks under 

60.13(d), Method 7 and 3B shall be used for the performance evaluations of nitrogen oxides (40 CFR Part 

60.45(c)(1)). Nitric oxide shall be used for preparing calibration gas mixtures under Performance 

Specification 2 of Appendix B of 40 CFR Part 60 (40 CFR Part 60.45(c)(2)). The span value for the CEMS 

shall be determined in accordance with the provisions contained in 40 CFR Part 60.45(c)(3) & (4). 

(11) Install, calibrate, operate and maintain a Continuous Data Collection System (CDCS) to continuously record 

the NOx concentration (in ppm), volumetric gas flow (in scfh), and NOx mass emissions (in lb/MMBtu), as 

measured by the CEMS required in E.4.b.(10) of this section. The CDCS will be installed, calibrated, 

operated and maintained in accordance with the manufacturer’s specifications and the requirements 

prescribed in 40 CFR Part 60.45(a), 40 CFR Part 60, Appendix B, Performance Specification 2, 40 CFR Part 

75, Part 75.11 and Appendix F. 

(12) Install, calibrate, operate and maintain a continuous opacity monitoring system to continuously measure and 

record the opacity from S2.003. The continuous opacity monitoring system will be installed at an appropriate 

location in the discharge stack of S2.003 to accurately and continuously measure the opacity of S2.003 in 

accordance with the requirements prescribed in NAC 445B.256 to NAC 445B.267, 40 CFR Part 60.45(a), 40 

CFR Part 60, Appendix B, Performance Specification 1, and 40 CFR Part 75.10. For performance 

evaluations under 40 CFR Part 60.13(c) and calibration checks under 60.13(d), the span value for the 

continuous opacity monitoring system shall be 80, 90, or 100 percent (40 CFR Part 60.45(c) and 

60.45(c)(3)). 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-35

Section VI. Specific Operating Conditions (continued)

E. Emission Unit #S2.003 (continued)

4. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Compliance, Monitoring, Recordkeeping and Reporting (continued) 

b. Monitoring (continued)

(13) Install, calibrate, operate and maintain a Continuous Data Collection System (CDCS) to continuously record 

the opacity (in percent opacity) as measured by the continuous opacity monitoring system required in 

E.4.b.(12) of this section. The CDCS will be installed, calibrated, operated and maintained in accordance 

with the manufacturer’s specifications and the requirements prescribed in NAC 445B.256 to NAC 445B.267, 

40 CFR Part 60.45(a), 40 CFR Part 60, Appendix B, Performance Specification 1, 40 CFR Part 75.10 and 40 

CFR Part 75.14. 

c. Recordkeeping

The Permittee will maintain a contemporaneous log containing at a minimum, the following recordkeeping for 

each day, or part of a day that S2.003 is operating under this operating scenario: 

(1) The total hourly quantity of sub-bituminous and/or bituminous coal (in tons) and the volume of natural gas (in 

scf) combusted, for each hour of operation based on the data recorded by the CDCS as required in E.4.b.(3) 

of this section. 

(2) The total daily hours of operation for the corresponding date. 

(3) The heat contents of each fuel combusted for the corresponding date, in Btu/ton (coal) and Btu/scf (natural 

gas). The heat contents of each fuel will be based on the gross calorific value determined in E.4.b.(5) & (6) 

of this section. 

(4) The hourly heat inputs of the sub-bituminous and/or bituminous coal and/or natural gas combusted, in 

MMBtu per hour. The hourly heat inputs will be calculated from the hourly fuel usage rates recorded in 

E.4.c.(1) of this section, and the heat contents of the fuel as recorded in E.4.c.(3) of this section. 

Sample Calculation: 

(tons-coal/hr)(Btu/ton-coal) = Btu/hr or MMBtu/hr 

(scf/hr)(Btu/scf) = Btu/hr or MMBtu/hr – natural gas 

Sum: 

MMBtu/hr - Coal + MMBtu/hr – natural gas = Hourly Heat Input in MMBtu/hr 

(5) The hourly emission rate of PM and PM10 each, in pounds per MMBtu (lbs/MMBtu). The hourly emission 

rates will be calculated from the hourly quantity of sub-bituminous and/or bituminous coal and/or natural gas 

determined in E.4.b.(1) and (2) of this section, and the emission factor derived in E.4.a.(9) of this section for 

coal combustion and emission factor (7.6 lb/106

 scf) as listed in AP-42, Table 1.4-2. for natural gas 

combustion. 

Sample Calculation: 

(tons-coal/Btu)(lbs-PM/tons-coal) = lbs-PM/Btu or lbs-PM/MMBtu 

(scf natural gas/Btu)(7.6 lb/106

 scf) = lbs-PM/Btu or lbs-PM/MMBtu – natural gas 

Sum: 

lbs-PM/MMBtu - Coal + lbs-PM/MMBtu – natural gas = Hourly Emission Rate in lbs-PM/MMBtu 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-36

Section VI. Specific Operating Conditions (continued)

E. Emission Unit #S2.003 (continued)

4. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Compliance, Monitoring, Recordkeeping and Reporting (continued) 

c. Recordkeeping (continued) 

(6) The emission rates of sulfur and SO2 each, in pounds per hour (lbs/hr) and pounds per million Btu 

(lbs/MMbtu) measured by the CEMS required in E.4.b.(8) of this section, for each averaging period described 

below: 

(i). The sulfur emissions in pounds per hour (lbs/hr) for each 1-hour period. Sulfur emissions will be one-half 

of the SO2 emissions measured. 

(ii). The sulfur and SO2 emissions in pounds per million Btu (lbs/MMBtu) for each 1-hour period. The 

conversion procedures established in 40 CFR Part 60.45(e) & (f) will be used to convert the continuous 

monitoring data into units of the applicable standard (lb/MMBtu, 3-hour rolling average period and 1-day 

average period). Sulfur emissions will be one-half of the SO2 emissions measured. 

(iii). The total SO2 emissions for a 10-day rolling average period (based on preceding last 10 days) in 

lbs/MMBtu. The SO2 emissions in lbs/MMBtu for each 1-day average period recorded in Section 

VI.E.4.c.(6)(ii) will be used to calculate a 10-day rolling average period. 

(7) The hourly emissions rate of NOx in pounds per million Btu (lbs/MMBtu) for each 1-hour period measured by 

the CEMS required in E.4.b.(10) of this section. The conversion procedures established in 40 CFR Part 

60.45(e) & (f) will be used to convert the continuous monitoring data into units of the applicable standard 

(lb/MMBtu, 3-hour rolling average). 

(8) The measured opacity (in percent opacity) from the continuous opacity monitoring system required in 

E.4.b.(12) of this section. The opacity will be determined from reducing all data from the successive 10-

second readings and recorded for the following: 

(i). Each 6-minute average, except for one 6-minute period per hour of up to 27 percent opacity as 

established in NAC 445B.22017.1(b) and as set forth in 40 CFR Part 60.13(h). 

(ii). Each 6-minute average, except for one 6-minute period per hour of up to 27 percent opacity as 

established in 40 CFR Part 60.42(a)(2). 

d. Reporting

The Permittee will: 

(1) Report all excess emissions as required in Sections III.B and III.C of this operating permit. 

(2) Report all deviations as required in Section V.C of the operating permit. 

(3) Submit semi-annual monitoring reports as required in Section V.C of this operating permit. 

(4) Certify compliance with all applicable requirements as required in Section V.E of this operating permit. 

(5) Report the results of the performance tests and opacity observations required in E.4.a.(10) of this section. 

(6) Federally Enforceable PSD Permit Requirement (PSD Permit Issued 1/3/80) - Submit a written report of 

excess emissions to the Administrator and the Director every calendar quarter. The report shall include: 

(i). The magnitude of excess emissions computed in accordance with 40 CFR 60.13(h), any conversion 

factor(s) used, and the date and time of commencement and completion of each time period of excess 

emissions. 

(ii). Specific identification of each period of excess emissions that occurs during start-ups, shutdowns, and 

malfunctions. The nature and cause of any malfunction (if known) and the corrective action taken or 

preventative measures adopted shall also be reported. 

(iii). The date and time identifying each period during which the continuous monitoring system was 

inoperative except for zero and span checks and the nature of the system repairs or adjustments. 

(iv). When no excess emissions have occurred or the continuous monitoring system has not been 

inoperative, repaired, or adjusted, such information shall be stated in the report. 

(v). Excess emissions shall be defined as any 3-hour rolling average period during which the average 

emissions of sulfur dioxide, as measured by the continuous monitoring system, exceeds the sulfur 

dioxide maximum limit in E.2.a.(7) of this section. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-37

Section VI. Specific Operating Conditions (continued)

E. Emission Unit #S2.003 (continued)

4. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Compliance, Monitoring, Recordkeeping and Reporting (continued) 

d. Reporting (continued) 

(6) Federally Enforceable PSD Permit Requirement (PSD Permit Issued 1/3/80) 

(vi). The Permittee shall maintain a file of all measurements, including continuous monitoring system, 

monitoring device, and performance testing measurements; all continuous monitoring system 

performance evaluations; all continuous monitoring system or monitoring device calibration checks; 

adjustments and maintenance performed on these systems or devices; and all other information required 

by 40 CFR part 60 recorded in a permanent form suitable for inspection. The file shall be retained for at 

least two years following the date of such measurements, maintenance, reports, and records. 

(7) Consent Decree Requirements

The SO2 (lb/MMBtu) excess emissions shall also be defined as any 10-day rolling average period during which 

the average emissions of sulfur dioxide, as measured by the continuous monitoring system, exceeds the 

sulfur dioxide maximum limit in Section VI.E.2.a.(7A). 

(8) Federally Enforceable PSD Permit Requirement (PSD Permit Issued 1/3/80) – The following reporting 

requirements apply only to Section VIII of the PSD Permit issued 1/3/80: 

The Regional Administrator (USEPA) shall be notified by telephone (by The Permitee) within 48 hours 

following any failure of air pollution control equipment, process equipment, or of a process to operate in 

a normal manner which results an increase in emissions above any allowable emissions limit stated in 

Section VIII of the USEPA-issued PSD permit dated January 3, 1980 of these conditions. In addition 

the Regional Administrator shall be notified in writing within fifteen (15) days of any such failure. This 

notification shall include a description of the malfunctioning equipment or abnormal operation, the date 

of the initial failure, the period of time over which emissions were increased due to failure, the cause of 

the failure, the estimated resultant emissions in excess of those allowed under Section VIII of these 

conditions, and the methods utilized to restore normal operations. Compliance with this malfunction 

notification provision shall not excuse or otherwise constitute a defense to any violations of this permit 

or of any law or regulations, which such malfunction, may cause. 

5. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Shielded Requirements

No specific shield requested.
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-38

Section VI. Specific Operating Conditions (continued)

F. Emission Unit #S2.003 - Alternative Operating Scenario: Co-Firing Coal and No. 2 Distillate Fuel Oil.

System 03B is completely DELETED (dated March 14, 2008). 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-39

Section VI. Specific Operating Conditions (continued)

G. Emission Unit #S2.004: UTM: North 4059.28 km, East 711.68 km (Zone 11) 

System 04 Reid Gardner Unit #4 Steam Boiler, 100% Coal Fired with Natural Gas Igniters.

S2.004 Steam Boiler, Foster Wheeler, Model # Custom Built, Serial # 12A6361-1, Unit Manufactured 

July 1983. 2,956 million Btu/hr, Maximum Heat Input, Nominal 295.0 MW Output.

1. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Air Pollution Equipment

Emissions from S2.004 shall be ducted to the following emissions control system with 100% capture and a maximum 

volume flow rate of 60,000,000 standard cubic feet per hour (SCFH): 

a. Twin parallel baghouse filtration systems for the control of particulate matter Federally Enforceable PSD Permit 

Requirement (PSD Permit Issued 1/3/80). 

b. Sodium carbonate wet spray scrubbing system for the control of sulfur dioxide Federally Enforceable PSD Permit 

Requirement (PSD Permit Issued 1/3/80). 

c. Low NOx coal burners and over-fired air. 

d. Rotating Opposed Fired Air (ROFA) combustion system for the control of NOx emissions. ROFA system will be 

maintained and operated in accordance with standard facility work practices. 

The volumetric flow rate may be determined by utilizing Method 2 – Determination of Stack Gas Velocity and 

Volumetric Flow Rate as referenced in 40 CFR Part 60, Appendix A. 

2. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Emission Limits

a. On and after the date of startup of S2.004, the Permittee will not discharge or cause the discharge into the 

atmosphere from the exhaust stack of S2.004, the following pollutants in excess of the following specified limits: 

(1) NAC 445B.2203 State-Only Requirement - The discharge of PM10 (particulate matter less than 10 microns in 

diameter) to the atmosphere will not exceed 0.16 pound per million Btu. 

(2) SIP 445.731 Federally Enforceable SIP - The discharge of PM (particulate matter) to the atmosphere will not 

exceed 0.16 pound per million Btu. 

(3) NAC 445B.305 Federally Enforceable PSD Permit Requirement (PSD Permit Issued 1/3/80) - The discharge 

of PM (particulate matter) to the atmosphere will not exceed 0.03 pound per million Btu. 

(4) 40 CFR Part 60.42a(a) Federally Enforceable New Source Performance Standard Requirement - On and 

after the date on which the performance test required to be conducted by Sec. 60.8 is completed, no owner 

or operator subject to the provisions of this subpart shall cause to be discharged into the atmosphere from 

any affected facility any gases which contain particulate matter in excess of 13 nanograms per joule (0.03 lb 

per million Btu) heat input derived from the combustion of solid fuel and 1 percent of the potential combustion 

concentration (99 percent reduction) when combusting solid fuel. 

(5) NAC 445B.22047 State-Only Requirement - The discharge of sulfur to the atmosphere will not exceed 

1,773.6 pounds per hour. 

(6) Article 8.2.1.2 Federally Enforceable SIP - The discharge of sulfur to the atmosphere will not exceed 1,773.6 

pounds per hour. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-40

Section VI. Specific Operating Conditions (continued)

G. Emission Unit #S2.004 (continued) 

2. NAC 445B.3405 (NAC 445B.316) Part 70 Program (continued)

a. Emission Limits (continued)

(7) NAC 445B.2206 State-Only Requirement - The allowable emission of sulfur from fossil-fired power 

generating Unit Number Four of Nevada Power Company’s Reid Gardner Station, located in air Quality 

Control Region 13, Basin 218, California Wash, must not be greater than 0.145 pound per million Btu. The 

efficiency of the capture of sulfur must be maintained at a minimum of 85 percent, based on a 30-day rolling 

average. 

(8) NAC 445B.305 Federally Enforceable PSD Permit Requirement (PSD Permit Issued 1/3/80) - The discharge 

of SO2 to the atmosphere will not exceed 0.29 pound per million Btu (based on a 30-day rolling average 

period). 

(9) 40 CFR Part 60.43a(a) Federally Enforceable New Source Performance Standard Requirement - On and 

after the date on which the initial performance test required to be conducted under Sec. 60.8 is completed, 

no owner or operator subject to the provisions of this subpart shall cause to be discharged into the 

atmosphere from any affected facility which combusts solid fuel, any gases which contain sulfur dioxide in 

excess of 520 nonograms per joule (1.20 lb per million Btu) heat input and 10 percent of the potential 

combustion concentration (90 percent reduction), or 30 percent of the potential combustion concentration (70 

percent reduction), when emissions are less that 260 nonograms per joule (0.60 lb per million Btu) heat 

input. Compliance with the emission limitation and percent reduction requirements under this section are 

both determined on a 30-day rolling average basis (40 CFR Part 60.43a(g)). 

(10) NAC 445B.305 Federally Enforceable PSD Permit Requirement (PSD Permit Issued 1/3/80) - The discharge 

of NO2 to the atmosphere will not exceed 0.5 pound per million Btu while firing sub-bituminous coal. 

(11) NAC 445B.305 Federally Enforceable PSD Permit Requirement (PSD Permit Issued 1/3/80) - The discharge 

of NO2 to the atmosphere will not exceed 0.6 pound per million Btu while firing bituminous coal. 

(12) 40 CFR Part 60.44a(a) Federally Enforceable New Source Performance Standard Requirement - On and 

after the date on which the initial performance test required to be conducted by Sec. 60.8 is completed, no 

owner or operator subject to the provisions of this subpart shall cause to be discharged into the atmosphere 

from any affected facility any gases which contain nitrogen oxides (expressed as NO2) in excess of the 

following emission limits, based on a 30-day rolling average: 

(i). Solid fuels: 

Sub-bituminous Coal 210 ng/J (0.50 lb/million Btu) 

Bituminous Coal 260 ng/J (0.60 lb/million Btu) 

(ii). NOx reduction requirement 

Solid fuels 65 percent reduction of potential combustion concentration 

(13) SIP 445.721 Federally Enforceable SIP - The opacity from S2.004 will not equal or exceed 20% for a period 

or periods aggregating more than 3 minutes in any one hour. 

(14) NAC 445B.22017 State-Only Requirement - The opacity from S2.004 will not equal or exceed 20%. The 

opacity must be determined as set forth in 445B.22017.1(a) or (b). S2.004 is allowed one 6-minute period 

per hour of not more than 27 percent opacity as set forth in 40 CFR part 60.42a(2). 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-41

Section VI. Specific Operating Conditions (continued)

G. Emission Unit #S2.004 (continued) 

2. NAC 445B.3405 (NAC 445B.316) Part 70 Program (continued)

a. Emission Limits (continued)

(15) NAC 445B.2202.6 State-Only Requirement - The opacity from S2.004 may exceed the level set in G.2.a.(14) 

of this section for the purposes of boiler lancing or soot blowing, not to exceed 180 minutes in any 

consecutive 24 hour period. 

(16) 40 CFR Part 60.42a(b) Federally Enforceable New Source Performance Standard Requirement - On and 

after the date the particulate matter performance test required to be conducted by Sec. 60.8 is completed, no 

owner or operator subject to the provisions of this subpart shall cause to be discharged into the atmosphere 

from any affected facility any gases which exhibit greater than 20 percent opacity (6-minute average), except 

for one 6-minute period per hour of not more than 27 percent opacity. 

b. Specific Acid Rain Requirements Parts 72 - 78 Acid Rain Program

(1) The Permittee will not exceed the SO2 emission levels (acid rain allowances) for the indicated years as 

shown in the following table without holding the required acid rain allowances in accordance with Section 

IV.B.2 of the Acid Rain provisions and pursuant to 40 CFR 72.9: 

Calendar Year 2005 2006 2007 2008 2009

S2.004 SO2 Phase II Allowance 2,813 2,813 2,813 2,813 2,813 

S2.004 NOx Emission Limit (lb/MMBtu) 0.50 0.50 0.50 0.46 0.46 

(2) The Permittee will comply with the “Standard Requirements” provisions of the SO2 acid rain permit 

application dated January 26, 1995 entitled “Phase II Permit Application” and all references contained 

therein, which is hereby incorporated by reference into this operating document (Attachment 1). [NAC 

445B.305]. 

3. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Operating Parameters

a. S2.004 will combust sub-bituminous and/or bituminous coal; and/or natural gas for purposes of startup, shutdown 

and/or flame stabilization only. 

b. S2.004 may operate a total of 8,760 hours per calendar year. 

c. The maximum operating heat input rate for S2.004 while combusting sub-bituminous and/or bituminous coal and 

natural gas will not exceed 2,956 million Btu per any one-hour period. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-42

Section VI. Specific Operating Conditions (continued)

G. Emission Unit #S2.004 (continued)

4. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Compliance, Monitoring, Recordkeeping and Reporting

a. Compliance/Performance Testing

Within 180 days of the date of issuance of this operating permit, and once annually thereafter, The Permittee

will: 

(1) Conduct and record a Method 5 performance test for PM on the exhaust stack of S2.004 consisting of three 

valid runs. The Method 5 emissions test must be conducted in accordance with 40 CFR Part 60, Appendix 

A, Method 5, and include the back-half catch. Compliance with the particulate matter standards contained in 

G.2.a.(2) through (4) shall be determined by using the dry basis F factor (O2) procedures in Method 19 to 

compute the emissions rate. Method 5B shall be used to determine the particulate matter concentration. 

The sampling time and sample volume for each run shall be at least 120 minutes and 1.70 dscm (60 dscf). 

The probe and filter holder heating system in the sampling train may be set to provide an average gas 

temperature of 160+/- 140

C (320+/- 250F). For each particulate run, the emission rate correction factor, 

integrated or grab sampling and analysis procedures of Method 3B shall be used to determine the O2

concentration. The O2 sample shall be obtained simultaneously with, and at the same traverse points as, the 

particulate run. If the particulate run has more than 12 traverse points, the O2 traverse points may be 

reduced to 12 provided that Method 1 is used to locate the 12 O2 traverse points (40 CFR Part 60.48a(b)). 

(2) Conduct and record a Method 201A and 202 performance test for PM10 on the exhaust stack of S2.004 

consisting of three valid runs. The Method 201A and 202 emissions tests must be conducted in accordance 

with 40 CFR Part 51, Appendix M, Method 201A and 202. The Method 201A and 202 emissions tests may 

be replaced by the Method 5 performance test required in G.4.a.(1) above. All particulate captured in the 

Method 5 test will be considered PM10 for compliance demonstration purposes. 

(3) Conduct and record a Method 6 performance test for SO2 on the exhaust stack of S2.004 consisting of three 

valid runs. The Method 6 emissions test must be conducted in accordance with 40 CFR Part 60, Appendix 

A, Method 6. 

(4) Conduct and record a Method 7 performance test for NOx on the exhaust stack of S2.004 consisting of three 

valid runs. The Method 7 emissions test must be conducted in accordance with 40 CFR Part 60, Appendix 

A, Method 7. 

(5) During one of the three test runs required in G.4.a.(1) of this section, conduct and record a Method 9 visual 

opacity observation of the discharge from the exhaust stack of S2.004. The Method 9 opacity test must be 

conducted in accordance with the visible emissions evaluation procedures contained in 40 CFR Part 60, 

Appendix A, Method 9. A certified visible emissions reader must conduct the visible emissions evaluations 

for a period of at least 6 minutes. The opacity readings must be averaged such that compliance with both a 

6-minute average and 2, 3-minute averages are determined (40 CFR Part 60.48a(b)(3)). 

(6) The performance tests will be conducted at the maximum operating heat input rate limit established in G.3.c 

of this section for each pollutant required to be tested, unless otherwise approved pursuant to NAC 

445B.252.3 & 4. The Permittee shall make available to the director such records as may be necessary to 

determine the conditions of the test of performance. Operations during periods of startup, shutdown and 

malfunction must not constitute representative conditions of a test of performance unless otherwise specified 

in the applicable standard (NAC 445B.252.3). Should any anticipated major boiler overhaul(s) be scheduled 

to be performed, which coincide with the performance tests, the performance testing will be performed prior 

to the overhaul(s). If the performance testing can not be performed prior to a major boiler overhaul, the 

testing will be performed as soon as practicable following the overhaul(s), but not earlier than 60 days 

following the overhaul. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-43

Section VI. Specific Operating Conditions (continued)

G. Emission Unit #S2.004 (continued)

4. NAC 445B.3405 (NAC 445B.316) Part 70 Program (continued)

Compliance, Monitoring, Recordkeeping and Reporting (continued) 

a. Compliance/Performance Testing (continued)

(7) The Permittee shall give notice to the director 30 days before the test of performance to allow the director to 

have an observer present. A written testing procedure for the test of performance must be submitted to the 

director at least 30 days before the test of performance to allow the director to review the proposed testing 

procedures (NAC 445B.252.4). The alternative to the reference methods and procedures provided in 40 

CFR Part 60.48a(e) may be utilized to the extent that they are applicable to S2.004, and must be identified in 

the testing procedures as alternative methods. 

(8) During each performance test required in G.4.a.(1) through (4) of this section, record the quantity (in tons) of 

coal combusted during each test run, the heat content value of the coal combusted during each test run (in 

Btu/ton) and include these data in the test results submitted. The emissions results of the Method 6 and 

Method 7 performance tests for SO2 and NOx must be converted to emissions of sulfur (both lb/hr and 

lb/MMBtu) and emissions of nitrogen oxides (lb/MMbtu). The emissions results of the Method 5 or Method 

201A and 202 performance test for PM10 must be reported in lb/MMBtu. 

(9) As a result of the most recent performance test performed in G.4.a.(1) through (2) of this section, derive 

emission factors for each of the following: 

(i). Pounds of PM per ton of coal (lbs-PM/tons-coal). 

(ii). Pounds of PM10 per ton of coal (lbs-PM10/tons-coal). 

These emissions factors will be based on the average of the 3 test runs. 

(10) Within 60 days after completing the performance tests and opacity observations contained in G.4.a. of this 

section, the Permittee shall furnish the director a written report of the results of the performance tests, the 

opacity observations and the resultant emissions factors. All information and analytical results of testing and 

sampling must be certified as to the truth and accuracy and as to their compliance with NAC 445B.001 to 

445B.3485 (NAC 445B.252.8). 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-44

Section VI. Specific Operating Conditions (continued)

G. Emission Unit #S2.004 (continued) 

4. NAC 445B.3405 (NAC 445B.316) Part 70 Program (continued)

Compliance, Monitoring, Recordkeeping and Reporting (continued) 

b. Monitoring

The Permittee, upon issuance of this operating permit will: 

(1) Install, calibrate, operate and maintain a coal mass measurement device to continuously measure the 

amount of sub-bituminous and/or bituminous coal (in tons) combusted in S2.004. The coal mass 

measurement device will be installed at an appropriate location in the fuel delivery system to accurately and 

continuously measure the fuel combusted in S2.004. 

(2) Install, calibrate, operate and maintain a fuel flow meter to continuously record the volume (in standard cubic 

feet) of natural gas combusted in S2.004. The fuel flow meter will be installed at an appropriate location in 

the fuel delivery system to accurately and continuously measure the fuel combusted in S2.004 in accordance 

with the requirements prescribed in 40 CFR Part 75. 

(3) Install, calibrate, operate and maintain a Continuous Data Collection System (CDCS) to continuously record 

the quantity (in tons) of sub-bituminous and/or bituminous coal as measured by the coal mass measurement 

device and the quantity of natural gas (in standard cubic feet) as measured by the fuel flow meter as required 

in G.4.b.(1) and (2) of this section. The CDCS will be installed, calibrated, operated and maintained in 

accordance with the manufacturer’s specifications. 

(4) Perform coal sampling of the coal prior to it entering the boiler. Sampling shall be conducted for moisture, 

ash, sulfur content, and gross calorific value. A coal analysis shall be performed weekly and the results of 

these analyses shall be retained for at least two years following the date of the measurement. All sample 

collection, sample preparation, and analyses performed or caused to be performed shall be conducted 

according to the most current ASTM methods (PSD permit requirement VIII.E. issued January 3, 1980). 

(5) Perform coal sampling of the sub-bituminous and/or bituminous coal weekly according to section 12.5.3.2.2 

in Method 19 in appendix A to Part 60 and use ASTM Method D2234-89, “Standard Test Methods for 

Collection of a Gross Sample of Coal.” Determine the gross calorific value of the sub-bituminous and/or 

bituminous coal combusted by sampling at least once weekly, using ASTM D2013-86, “Standard Method of 

Preparing Coal Samples for Analysis”, ASTM D2015-91, “Standard Test Method for Gross Calorific Value of 

Coal and Coke by the Adiabatic Bomb Calorimeter”, ASTM 1989-92, “Standard test Method for Gross 

Calorific Value of Coal and Coke by Microprocessor Controlled Isoperibol Calorimeters”, or ASTM 3286-91a, 

“Standard Test Method for Gross Calorific Value of Coal and Coke by the Isoperibol Bomb Calorimeter.” 

(6) Maintain on site, monthly analysis of calorific value of natural gas provided by natural gas supplier. 

(7) Substitute any missing fuel flow meter data in accordance with the requirements prescribed in 40 CFR Part 

75, Appendix D, Section 2.4.2. 

(8) Install, calibrate, operate and maintain a SO2 continuous emissions monitor system (CEMS) (consisting of a 

SO2 pollutant concentration monitor and a flow monitoring device) to continuously measure the concentration 

and percent reduction of SO2 (in ppm), percent reduction, volumetric gas flow (in scfh), and SO2 mass 

emissions (in lb/hr and lb/MMBtu) from S2.004. The CEMS will be installed at an appropriate location in the 

exhaust stack of S2.004 to accurately and continuously measure the SO2 concentration in S2.004 in 

accordance with the requirements prescribed in 40 CFR Part 60.47a(b), 40 CFR Part 60, Appendix B, 

Performance Specification 2, 40 CFR Part 75, Part 75.11 and Appendix F. SO2 emissions are monitored at 

both the inlet and outlet of the sulfur dioxide control device. The procedures established in 40 CFR Part 

60.47a(i) shall be used to conduct monitoring system performance evaluations. 

(9) Install, calibrate, operate and maintain a Continuous Data Collection System (CDCS) to continuously record 

the SO2 concentration (in ppm), SO2 percent reduction, volumetric gas flow (in scfh), and SO2 mass 

emissions (in lb/hr and lb/MMBtu), as measured by the CEMS required in G.4.b.(8) of this section. The 

CDCS will be installed, calibrated, operated and maintained in accordance with the manufacturer’s 

specifications and the requirements prescribed in 40 CFR Part 60.47a, 40 CFR Part 60, Appendix B, 

Performance Specifications, 40 CFR Part 75, Part 75.11 and Appendix F. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-45

Section VI. Specific Operating Conditions (continued)

G. Emission Unit #S2.004 (continued) 

4. NAC 445B.3405 (NAC 445B.316) Part 70 Program (continued)

Compliance, Monitoring, Recordkeeping and Reporting (continued) 

b. Monitoring (continued)

(10) Install, calibrate, operate and maintain a NOx continuous emissions monitor system (CEMS) (consisting of a 

NOx pollutant concentration monitor and a flow monitoring device) to continuously measure the concentration 

of NOx (in ppm), volumetric gas flow (in scfh), and NOx emissions rate (in lb/MMBtu) from S2.004. The 

CEMS will be installed at an appropriate location in the exhaust stack of S2.004 to accurately and 

continuously measure the NOx concentration in S2.004 in accordance with the requirements prescribed in 40 

CFR Part 60.47a(c), 40 CFR Part 60, Appendix B, Performance Specification 2, 40 CFR Part 75, Part 75.11 

and Appendix F. The NOx CEMS installed to meet the requirements of 40 CFR Part 75 may be used to 

meet the requirements of 40 CFR Part 60.47(c). The requirements established in 60.49a continue to apply, 

except that the permittee shall also meet the requirements of 40 CFR Part 60.49a shall not include data 

substituted using the missing data procedures in subpart D of 40 CFR Part 75, nor shall the data have been 

bias adjusted according to the procedures of 40 CFR Part 75. The procedures established in 40 CFR Part 

60.47a(i) shall be used to conduct monitoring system performance evaluations. 

(11) Install, calibrate, operate and maintain a Continuous Data Collection System (CDCS) to continuously record 

the NOx concentration (in ppm), volumetric gas flow (in scfh), and NOx emissions rate (in lb/MMBtu), as 

measured by the CEMS required in G.4.b.(10) of this section. The CDCS will be installed, calibrated, 

operated and maintained in accordance with the manufacturer’s specifications and the requirements 

prescribed in 40 CFR Part 60, Appendix B, Performance Specification 2, 40 CFR Part 75, Part 75.11 and 

Appendix F. 

(12) Install, calibrate, operate and maintain a Continuous Data Collection System (CDCS) to continuously record 

the oxygen or carbon dioxide content of the flue gases at each location where sulfur dioxide or nitrogen 

oxides emissions are monitored (40 CFR Part 60.47a(d)). 

(13) Install, calibrate, operate and maintain a continuous opacity monitoring system to continuously measure and 

record the opacity from S2.004. The continuous opacity monitoring system will be installed at an appropriate 

location in the discharge stack of S2.004 to accurately and continuously measure the opacity of S2.004 in 

accordance with the requirements prescribed in NAC 445B.256 to NAC 445B.267, 40 CFR Part 60.47a(a), 

40 CFR Part 60, Appendix B, Performance Specification 1, and 40 CFR Part 75.10. If opacity interference 

due to water droplets exists in the stack, the opacity is monitored upstream of the interference. 

(14) Install, calibrate, operate and maintain a Continuous Data Collection System (CDCS) to continuously record 

the opacity (in percent opacity) as measured by the continuous opacity monitoring system required in 

G.4.b.(13) of this section. The CDCS will be installed, calibrated, operated and maintained in accordance 

with the manufacturer’s specifications and the requirements prescribed in NAC 445B.256 to NAC 445B.267, 

40 CFR Part 60.47a(a), 40 CFR Part 60, Appendix B, Performance Specification 1, 40 CFR Part 75.10 and 

40 CFR Part 75.14. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-46

Section VI. Specific Operating Conditions (continued)

G. Emission Unit #S2.004 (continued)

4. NAC 445B.3405 (NAC 445B.316) Part 70 Program (continued) 

c. Recordkeeping

The Permittee will maintain a contemporaneous log containing at a minimum, the following recordkeeping for 

each day, or part of a day that S2.004 is operating under this operating scenario: 

(1) The total hourly quantity of sub-bituminous and/or bituminous coal (in tons) and the volume of natural gas (in 

scf) combusted, for each hour of operation based on the data recorded by the CDCS as required in G.4.b.(3) 

of this section. 

(2) The total daily hours of operation for the corresponding date. 

(3) The heat contents of each fuel combusted for the corresponding date, in Btu/ton (coal) and Btu/scf (natural 

gas). The heat contents for each fuel will be based on the gross calorific value determined in G.4.b.(5) & (6) 

of this section. 

(4) The hourly heat inputs of the sub-bituminous and/or bituminous coal and/or natural gas combusted, in 

MMBtu per hour. The hourly heat inputs will be calculated from the hourly fuel usage rates recorded in 

G.4.c.(1) of this section, and the heat contents of the fuel as recorded in G.4.c.(3) of this section. 

Sample Calculation: 

(tons-coal/hr)(Btu/ton-coal) = Btu/hr or MMBtu/hr 

(scf/hr)(Btu/scf) = Btu/hr or MMBtu/hr – natural gas 

Sum: 

MMBtu/hr - Coal + MMBtu/hr – natural gas = Hourly Heat Input in MMBtu/hr 

(5) The hourly emission rate of PM and PM10 each, in pounds per MMBtu (lbs/MMBtu). The hourly emission 

rates will be calculated from the hourly quantity of sub-bituminous and/or bituminous coal and/or natural gas 

determined in G.4.b.(1) & (2) of this section, and the emission factor derived in G.4.a.(9) of this section for 

coal combustion and emission factor (7.6 lb/106

 scf) listed in AP-42, Table 1.4-2. for natural gas combustion. 

Sample Calculation: 

(tons-coal/Btu)(lb/tons-coal) = lbs-PM/Btu or lbs-PM/MMBtu 

(scf natural gas/Btu)(7.6 lb/106

 scf) = lbs-PM/Btu or lbs-PM/MMBtu – natural gas 

Sum: 

lbs-PM/MMBtu - Coal + lbs-PM/MMBtu – natural gas = Hourly Emission Rate in lbs-PM/MMBtu 

(6) The emission rates of sulfur and SO2 each, in pounds per hour (lbs/hr) and pounds per million Btu 

(lbs/MMbtu) measured by the CEMS required in G.4.b.(8) of this section, for each averaging period 

described below: 

(i). The sulfur emissions in pounds per hour (lbs/hr) for each 1-hour period. Sulfur emissions will be one-half 

of the SO2 emissions measured. 

(ii). The Sulfur and SO2 emissions in pounds per million Btu (lbs/MMBtu) and the percent reduction levels for 

each 30-day rolling average period. The compliance determination procedures established in 40 CFR 

Part 60.48a(c) will be used to convert the continuous monitoring data into units of the applicable 

standards (lb/MMBtu, 30-day rolling average period and percent reduction). 

(7) The hourly emissions rate of NOx in pounds per million Btu (lbs/MMBtu) and the percent reduction levels for 

each 30-day rolling average period measured by the CEMS required in G.4.b.(10) of this section. The 

compliance determination procedures established in 40 CFR Part 60.48a(d) will be used to convert the 

continuous monitoring data into units of the applicable standard (lb/MMBtu, 30-day rolling average period 

and percent reduction). 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-47

Section VI. Specific Operating Conditions (continued)

G. Emission Unit #S2.004 (continued)

4. NAC 445B.3405 (NAC 445B.316) Part 70 Program (continued) 

c. Recordkeeping (continued)

(8) The measured opacity (in percent opacity) from the continuous opacity monitoring system required in 

G.4.b.(13) of this section. The opacity will be determined from reducing all data from the successive 10-

second readings and recorded for the following: 

(i). Each 6-minute average, except for one 6-minute period per hour of up to 27 percent opacity as 

established in NAC 445B.22017.1(b) and as set forth in 40 CFR Part 60.13(h). 

(ii). Each 6-minute average, except for one 6-minute period per hour of up to 27 percent opacity as 

established in 40 CFR Part 60.42a(b). 

d. Reporting

The Permittee will: 

(1) Report all excess emissions as required in Sections III.B and III.C of this operating permit. 

(2) Report all deviations as required in Section V.C of the operating permit. 

(3) Submit semi-annual monitoring reports as required in Section V.C of this operating permit. 

(4) Certify compliance with all applicable requirements as required in Section V.E of this operating permit. 

(5) Report the results of the performance tests and opacity observations required in G.4.a.(10) of this section. 

(6) Federally Enforceable PSD Permit Requirement (PSD Permit Issued 1/3/80) - Submit a written report of 

excess emissions to the Administrator and the Director every calendar quarter. The report shall include: 

(i). The magnitude of excess emissions computed in accordance with 40 CFR 60.13(h), any conversion 

factor(s) used, and the date and time of commencement and completion of each time period of excess 

emissions. 

(ii). Specific identification of each period of excess emissions that occurs during start-ups, shutdowns, and 

malfunctions. The nature and cause of any malfunction (if known) and the corrective action taken or 

preventative measures adopted shall also be reported. 

(iii). The date and time identifying each period during which the continuous monitoring system was 

inoperative except for zero and span checks and the nature of the system repairs or adjustments. 

(iv). When no excess emissions have occurred or the continuous monitoring system has not been 

inoperative, repaired, or adjusted, such information shall be stated in the report. 

(v). Reid Gardner Unit #4 is subject to the federal regulations entitled “Standards of Performance for New 

Stationary Sources” (40 CFR Part 60). Nevada Power Company shall comply with all requirements of 

Subpart Da of this regulation. 

(vi). The Permittee shall maintain a file of all measurements, including continuous monitoring system, 

monitoring device, and performance testing measurements; all continuous monitoring system 

performance evaluations; all continuous monitoring system or monitoring device calibration checks; 

adjustments and maintenance performed on these systems or devices; and all other information required 

by 40 CFR part 60 recorded in a permanent form suitable for inspection. The file shall be retained for at 

least two years following the date of such measurements, maintenance, reports, and records. 

(7) Federally Enforceable New Source Performance Standard Requirement - Submit reports in accordance with 

the provisions established in 40 CFR Part 60.49a. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-48

Section VI. Specific Operating Conditions (continued)

G. Emission Unit #S2.004 (continued)

4. NAC 445B.3405 (NAC 445B.316) Part 70 Program (continued) 

d. Reporting (continued)

(8) Federally Enforceable PSD Permit Requirement (PSD Permit Issued 1/3/80) – The following reporting 

requirements apply only to Section VIII of the PSD Permit issued 1/3/80: 

The Regional Administrator (USEPA) shall be notified by telephone (by The Permitee) within 48 hours 

following any failure of air pollution control equipment, process equipment, or of a process to operate in a 

normal manner which results an increase in emissions above any allowable emissions limit stated in Section 

VIII of the USEPA-issued PSD permit dated January 3, 1980 of these conditions. In addition the Regional 

Administrator shall be notified in writing within fifteen (15) days of any such failure. This notification shall 

include a description of the malfunctioning equipment or abnormal operation, the date of the initial failure, the 

period of time over which emissions were increased due to failure, the cause of the failure, the estimated 

resultant emissions in excess of those allowed under Section VIII of these conditions, and the methods 

utilized to restore normal operations. Compliance with this malfunction notification provision shall not excuse 

or otherwise constitute a defense to any violations of this permit or of any law or regulations, which such 

malfunction, may cause. 

5. NAC 445B.3405 (NAC 445B.316) Part 70 Program

Shielded Requirements

No specific shield requested. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-49

Section VI. Specific Operating Conditions (continued)

H. Emission Unit #S2.004. Alternative Operating Scenario: Co-Firing Coal and No. 2 Distillate Fuel Oil. 

System 04B is completely DELETED (dated March 14, 2008).
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-50

Section VI. Specific Operating Conditions (continued)

I. Emission Units #S2.005 through S2.008 UTM: North 4059.35 km, East 711.68 km (Zone 11) 

System 05 Cooling Towers - Units #1 through #4 

S2.005 Reid Gardner Unit #1 Cooling Tower (CT-01), Positive Draft Type, Marley Model and 

Serial# unknown, In Service 1965, 63,800 gallon/min Circulating Water Flow Rate 

S2.006 Reid Gardner Unit #2 Cooling Tower (CT-02), Positive Draft Type, Marley Model and 

Serial# unknown, In Service 1968, 63,800 gallon/min Circulating Water Flow Rate 

S2.007 Reid Gardner Unit #3 Cooling Tower (CT-03), Positive Draft Type, Marley Model and 

Serial# unknown, In Service 1976, 63,800 gallon/min Circulating Water Flow Rate 

S2.008 Reid Gardner Unit #4 Cooling Tower (CT-04), Positive Draft Type, Marley Model and 

Serial# unknown, In Service 1983, 131,000 gallon/min Circulating Water Flow Rate 

1. NAC 445B.3405 (NAC 445B.316) 

Air Pollution Equipment (Part 70 Program)

Emissions from S2.005 through S2.008 each will be controlled by drift eliminators. 

2. NAC 445B.3405 (NAC 445B.316) (Part 70 Program)

Emission Limits

a. On and after the date of startup of S2.005 through S2.008, The Permittee will not discharge or cause the 

discharge into the atmosphere from the cooling tower stack of S2.005 through S2.008 each, the following 

pollutants in excess of the following specified limits: 

(1) (i). NAC 445B.305 Part 70 Program - The discharge of PM10 (particulate matter less that 10 microns in 

diameter) to the atmosphere from S2.005 through S2.007 each, will not exceed 51.5 pounds per hour. 

(ii). NAC 445B.305 Part 70 Program - The discharge of PM10 (particulate matter less that 10 microns in 

diameter) to the atmosphere from S2.008 will not exceed 105.8 pounds per hour. 

(2) (i). NAC 445B.22033 State-Only Requirement - The discharge of PM10 (particulate matter less that 10 

microns in diameter) to the atmosphere from S2.005 and S2.006 each, will not exceed 119.24 pounds 

per hour. 

(ii). NAC 445B.22033 State-Only Requirement - The discharge of PM10 (particulate matter less that 10 

microns in diameter) to the atmosphere from S2.007, will not exceed 119.93 pounds per hour. 

(iii). NAC 445B.22033 State-Only Requirement - The discharge of PM10 (particulate matter less that 10 

microns in diameter) to the atmosphere from S2.008 will not exceed 132.72 pounds per hour. 

(3) (i). SIP 445.732 Federally Enforceable SIP - The discharge of PM (particulate matter) to the atmosphere 

from S2.005 and S2.006 each, will not exceed 119.24 pounds per hour. 

(ii). SIP 445.732 Federally Enforceable SIP - The discharge of PM (particulate matter) to the atmosphere 

from S2.007 will not exceed 119.93 pounds per hour. 

(iii). SIP 445.732 Federally Enforceable SIP - The discharge of PM (particulate matter) to the atmosphere 

from S2.008 will not exceed 132.72 pounds per hour. 

(4) NAC 445B.22017 State-Only Requirement - The opacity from of S2.005 through S2.008 each, will not equal 

or exceed 20%. The opacity must be determined as set forth in 445B.22017.1(a) or (b). 

(5) SIP 445.721 Federally Enforceable SIP - The opacity from S2.005 through S2.008 each, will not equal or 

exceed 20% for a period or periods aggregating more than 3 minutes in any one hour. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-51

Section VI. Specific Operating Conditions (continued)

I. Emission Units #S2.005 through S2.008 (continued)

3. NAC 445B.3405 (NAC 445B.316) (Federally Enforceable Part 70 Program)

Operating Parameters

a. (1) The maximum circulating water flow rate for S2.005 through S2.007 each, will not exceed 63,800 gallons per 

minute. 

(2) The maximum circulating water flow rate for S2.008 will not exceed 131,000 gallons per minute. 

b. (1) The maximum Total Dissolved Solids (TDS) content for S2.005 through S2.008 each, will not exceed 8,500 

milligrams per liter (8,500 ppm). 

c. The use of chromium-based water treatment chemicals is prohibited. 

d. S2.005 through S2.008 each may operate 8,760 hours per calendar year. 

4. NAC 445B.3405 (NAC 445B.316) (Federally Enforceable Part 70 Program)

Monitoring, Record keeping and Compliance

The Permittee will maintain a contemporaneous log containing at a minimum, the following recordkeeping for each 

day, or part of a day that S2.005 through S2.008 are operated: 

a. Monitoring

The Permittee, upon the issuance date of this operating permit will: 

(1) Sample the cooling tower water from S2.005 through S2.008 each, on a calendar quarterly basis for the TDS 

concentration in parts per million (ppm). The TDS will be determined using EPA Method 160.1 DNS. 

b. Recordkeeping

The Permittee will maintain a contemporaneous log containing at a minimum, the following recordkeeping for 

each day, or part of a day that S2.005 through S2.008 each are operating under this operating scenario: 

(1) The TDS value of the circulating water of S2.005 through S2.008 each on a calendar quarterly basis. The 

TDS value will be based on the sampling required in I.4.a. of this section. 

(2) The volume flow rate of the circulating water of S2.005 through S2.008 each, on an hourly basis. 

(3) The total hourly quantities of water circulated for each hour of each day S2.005 through S2.008 operates. 

(4) The total daily hours of operation of S2.005 through S2.008 for the corresponding date. 

(5) Inspect and record in a contemporaneous log the maintenance and operation of the drift eliminators of 

S2.005 through S2.008 each in accordance with the manufacturer’s guidelines on an annual basis. Annual 

inspection records must show that observations were made and include records of any corrective actions 

taken. 

c. Reporting

The Permittee will: 

(1) Report all excess emissions as required in Sections III.B and III.C of this operating permit. 

(2) Report all deviations as required in Section V.C of the operating permit. 

(3) Submit semi-annual monitoring reports as required in Section V.C of this operating permit. 

(4) Certify compliance with all applicable requirements as required in Section V.E of this operating permit. 

5. NAC 445B.3405 (NAC 445B.316) Federally Enforceable Part 70 Program

Shielded Requirements

No specific shield requested. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-52

Section VI. Specific Operating Conditions (continued)

J. Emission Unit # S2.009 UTM: North 3995.5 km, East 675.5 km 

System 06 No. 2 Distillate Fuel Storage Tank System 

S2.009 Storage Tank with No. 2 Distillate Fuel Oil, Manufacturer, Model# and Serial# Unknown. 

Installed 1964. 860,000-gallon capacity. 

1. NAC 445B.316 Part 70 Program

Air Pollution Equipment

Control system consisting of submerged fill. 

2. NAC 445B.316 Part 70 Program

Emission Limits

On and after the date of startup of S2.009, the Permittee will not discharge or cause the discharge into the 

atmosphere from exhaust vent of S2.009, the following pollutants in excess of the following specified limits: 

a. NAC 445B.305 (Federally Enforceable Part 70 Program) - The discharge of VOC to the atmosphere from S2.009 

will not exceed 1.4 tons per calendar year. 

b. SIP 445.721 (Federally Enforceable SIP Requirement) - The opacity from S2.009 will not equal or exceed 20%

for a period or periods aggregating more than 3 minutes in any one-hour period. 

c. NAC 445B.22017 State-Only Requirement - The opacity from S2.009 will not equal or exceed 20%. The opacity 

must be determined as set forth in 445B.22017.1(a) or (b). 

3. NAC 445B.316 (Federally Enforceable Part 70 Program)

Operating Parameters

a. S2.009 

(1) May store No. 2 distillate fuel oil only. 

(2) Maximum throughput will not exceed 420,000,000 gallons per calendar year. 

(3) May operate 8,760 hours per year. 

4. NAC 445B.316 Part 70 Program

Monitoring, Record keeping and Compliance

Upon issuance of this permit, the Permittee will: 

a. Monitor and record in a contemporaneous log, the total fuel oil throughput for S2.009 on a monthly basis for the 

calendar year. 

5. NAC 445B.316 Part 70 Program

Shielded Requirements

No specific shield requested. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-53

Section VI. Specific Operating Conditions (continued) 

K. Emission Unit #PF1.001. UTM: North 4,059.35 km, East 711.68 (Zone 11). 

System 07 – Coal Unloading Station & Coal Conveying Equipment 

PF1.001 Coal Train car Unloading Station (C-05) manufactured by McNalley-Pittsburgh. 

Includes: 

-Rail car unloading hoppers A1 #1-3 and A2 #1-7; 

-Conveyor belts B, C, F, N, G, H, J, D, E, M and K; 

-Flop gates F/C, G/N, and K/M; 

-Feeders D, E, H-1 and H-2; 

-“As-received” coal sampler and sample collector; 

-“As-fired” coal sampler and sample collector; 

-Unit #1-3 Coal storage pile(s); and 

-Associated transfer points 

1. NAC 445B.3405 (445B.316) Part 70 Program

Air Pollution Equipment

a. Control system for PF1.001 consisting of water sprays applying water with added surfactant at transfer points 

and coal storage piles. 

b. Fully-enclosed covers over conveyors. 

2. NAC 445B.3405 (445B.316) Part 70 Program

Emission Limits

On and after the date of startup of PF1.001, Nevada Power Company - Reid Gardner Station will not discharge or 

cause the discharge into the atmosphere the following pollutants in excess of the following specified limits: 

a. SIP 445.732 Federally Enforceable SIP Requirement - The discharge of PM (particulate matter) to the 

atmosphere from PF1.001 will not exceed 90.06 pounds per hour. 

b. NAC 445B.22033 State-Only Requirement - The discharge of PM10 (particulate matter less than 10 microns in 

diameter) to the atmosphere from PF1.001 will not exceed 90.06 pounds per hour. 

c. NAC 445B.305 Part 70 Program - The discharge of PM (particulate matter) and PM10 (particulate matter less 

than 10 microns in diameter) to the atmosphere from PF1.001 will not exceed 37.1 pounds per hour nor more 

than 50.6 tons per year. 

d. SIP 445.721 Federally Enforceable SIP Requirement - The opacity from PF1.001 will not equal or exceed 20%

for a period or periods aggregating more than 3 minutes in any one hour. 

e. NAC 445B.22017 & NAC 445B.355 State Only Requirements - The opacity from PF1.001 will not equal or 

exceed 20% for a period or periods aggregating more than 3 minutes in any one hour. 

f. 40 CFR 60.252(c) NSPS Regulation - On and after the date on which the performance test required to be 

conducted by Section 60.8 is completed, an owner or operator subject to the provisions of NSPS Subpart Y (Coal 

Preparation Plants) shall not cause to be discharged into the atmosphere from any coal processing and 

conveying equipment, coal storage system, or coal transfer and loading system processing coal, gases which 

exhibit 20 percent opacity or greater. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-54

Section VI. Specific Operating Conditions (continued) 

K. Emission Unit #PF1.001. (continued) 

3. NAC 445B.3405 (445B.316) Part 70 Program

Operating Parameters

a. Maximum allowable throughput of coal in PF1.001 will not exceed 2,500 tons per hour. 

b. Hours

1. PF1.001 may operate 8,760 hours per calendar year. 

4. NAC 445B.3405 (445B.316) Part 70 Program

Monitoring, Record keeping, Compliance and Reporting

a. Monitoring, Recordkeeping and Compliance 

The Permittee, upon issuance of this operating permit will: 

i. Monitor and record the throughput of coal for PF1.001 on a daily basis. 

ii. Monitor and record the hours of operation for PF1.001 on a daily basis. 

iii. Within 30 days of the issuance of this operating permit, the Permittee shall submit a visual observation plan 

to be approved by the director. The observation plan shall identify multiple observation points from where 

the visible emission sources, excluding emissions sources located and operated inside a building shall be 

monitored. The visual observations shall be conducted once every two-calendar weeks. All of the visible 

emission sources associated with each observation point shall be specifically identified in within the 

observation plan. 

iv. A certified Method 9 observer shall conduct and record a visible emission survey of visible emissions from 

the emission sources, in accordance with the submitted observation plan, once every two-calendar weeks, 

under normal representative operating conditions. Record the time and date of the survey and whether any 

visible emissions were observed. If the visible emission survey detects any visible emissions, the Permittee 

will conduct a Method 9 visible emissions reading conducted by a certified visible emissions reader within 4 

hours of the initial visible observation survey, including all documents required under 40 CFR Part 60, 

Appendix A. 

v. The required monitoring established in (i.) through (iv.) above, will be maintained in a contemporaneous log 

containing at a minimum, the following record keeping for each day, or part of a day that PF1.001 is 

operating: 

(a) The calendar date of any required monitoring. 

(b) The total daily throughput rate of coal, in tons, for the corresponding date. 

(c) The total daily hours of operation for the corresponding date. 

(d) The corresponding average hourly throughput rate of coal, in tons per hour. The average hourly 

throughput rate will be determined from the daily throughput rate and the total daily hours of operation 

recorded in (b) and (c) above. 

(e) Results and verification of the visible emissions survey, and documentation of any Method 9 visible 

emission tests that were undertaken, including all documents required under 40 CFR Part 60, Appendix 

A. 

vi. As a means of showing initial compliance with the NSPS Subpart Y opacity limit prescribed in k.2.f. of this 

section, within 180 days from the date of issuance of this operating permit, conduct and record a Method 9 

Initial Opacity Compliance Demonstration (IOCD) for all emission Units that support boiler Unit #3 using the 

procedures in Section 60.11 to determine the opacity from the discharge of PF1.002 to the atmosphere. The 

Method 9 IOCD shall be performed and recorded by a certified opacity reader. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-55

Section VI. Specific Operating Conditions (continued) 

K. Emission Unit #PF1.001. (continued) 

4. NAC 445B.3405 (445B.316) Part 70 Program

Monitoring, Record keeping, Compliance and Reporting (continued) 

b. Reporting 

i. Federally Enforceable PSD Permit Requirement (PSD Permit Issued 1/3/80) – The following reporting 

requirement applies only to Section VIII of the PSD Permit issued 1/3/80: 

The Regional Administrator (USEPA) shall be notified by telephone (by The Permitee) within 48 hours 

following any failure of air pollution control equipment, process equipment, or of a process to operate in a 

normal manner which results an increase in emissions above any allowable emissions limit stated in Section 

VIII of the USEPA-issued PSD permit dated January 3, 1980 of these conditions. In addition the Regional 

Administrator shall be notified in writing within fifteen (15) days of any such failure. This notification shall 

include a description of the malfunctioning equipment or abnormal operation, the date of the initial failure, the 

period of time over which emissions were increased due to failure, the cause of the failure, the estimated 

resultant emissions in excess of those allowed under Section VIII of these conditions, and the methods 

utilized to restore normal operations. Compliance with this malfunction notification provision shall not excuse 

or otherwise constitute a defense to any violations of this permit or of any law or regulations, which such 

malfunction, may cause. 

5. NAC 445B.3405 (445B.316) Part 70 Program

Shielded Requirements

No shielded provisions are established for these emission units. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-56

Section VI. Specific Operating Conditions (continued) 

L. Emission Unit #PF1.002. UTM: North 4,059.35 km, East 711.68 km (Zone 11). 

System 08 – Coal Unloading Station & Coal Conveying Equipment 

PF1.002 Loading of Unit #4 Coal Conveying (C-06a) manufactured by McNalley-Pittsburgh. 

Includes: 

-Unit #4 coal storage pile(s) 

-Feeders 0-1A, 0-1B, 0-2B and 0-2A; 

-Conveyors 0-1, 0-2, P-1 and P-2; and 

-Associated transfer points. 

1. NAC 445B.3405 (445B.316) Part 70 Program

Air Pollution Equipment

a. Control system for PF1.002 consisting of water sprays applying water with added surfactant at transfer points 

and coal storage piles. 

b. Fully-enclosed covers over coal conveyors. 

2. NAC 445B.3405 (445B.316) Part 70 Program

Emission Limits

On and after the date of startup of PF1.002, Nevada Power Company - Reid Gardner Station will not discharge or 

cause the discharge into the atmosphere the following pollutants in excess of the following specified limits: 

a. SIP 445.732 Federally Enforceable SIP Requirement - The discharge of PM (particulate matter) to the 

atmosphere from PF1.002 will not exceed 82.02 pounds per hour. 

b. NAC 445B.22033 State-Only Requirement - The discharge of PM10 to the atmosphere from PF1.002 will not 

exceed 82.02 pounds per hour. 

c. NAC 445B.305 Part 70 Program - The discharge of PM (particulate matter) and PM10 (particulate matter less 

than 10 microns in diameter) to the atmosphere from PF1.002 will not exceed 0.2 pound per hour nor more than 

0.02 ton per year. 

d. SIP 445.721 Federally Enforceable SIP Requirement - The opacity from PF1.002 discharge will not equal or 

exceed 20% for a period or periods aggregating more than 3 minutes in any one hour. 

e. NAC 445B.22017, & NAC445B.355 State Only Requirements - The opacity from PF1.002 discharges will not 

equal or exceed 20% for a period or periods aggregating more than 3 minutes in any one hour. 

f. 40 CFR 60.252(c) NSPS Regulation - On and after the date on which the performance test required to be 

conducted by Section 60.8 is completed, an owner or operator subject to the provisions of NSPS Subpart Y (Coal 

Preparation Plants) shall not cause to be discharged into the atmosphere from any coal processing and 

conveying equipment, coal storage system, or coal transfer and loading system processing coal, gases which 

exhibit 20 percent opacity or greater. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-57

Section VI Specific Operating Conditions (continued) 

L. Emission Unit #PF1.002 (continued) 

3. NAC 445B.3405 (445B.316) Part 70 Program

Operating Parameters

a. Maximum allowable throughput of coal in PF1.002 will not exceed 1,400 tons per hour. 

b. Hours

1. PF1.002 may operate 8,760 hours per calendar year. 

4. NAC 445B.3405 (445B.316) Part 70 Program

Monitoring, Recordkeeping, Compliance and Reporting

a. Monitoring, Record keeping and Compliance 

The Permittee, upon issuance of this operating permit will: 

i. Monitor and record the throughput of coal for PF1.002 on a daily basis. 

ii. Monitor and record the hours of operation for PF1.002 on a daily basis. 

iii. Within 30 days of the issuance of this operating permit, the Permittee shall submit a visual observation plan 

to be approved by the director. The observation plan shall identify multiple observation points from where 

the visible emission sources, excluding emissions sources located and operated inside a building shall be 

monitored. The visual observations shall be conducted once every two-calendar weeks. All of the visible 

emission sources associated with each observation point shall be specifically identified in within the 

observation plan. 

iv. A certified Method 9 observer shall conduct and record a visible emission survey of visible emissions from 

the emission sources, in accordance with the submitted observation plan, once every two-calendar weeks, 

under normal representative operating conditions. Record the time and date of the survey and whether any 

visible emissions were observed. If the visible emission survey detects any visible emissions, the Permittee 

will conduct a Method 9 visible emissions reading conducted by a certified visible emissions reader within 4 

hours of the initial visible observation survey, including all documents required under 40 CFR Part 60, 

Appendix A. 

v. The required monitoring established in (i.) through (iv.) above, will be maintained in a contemporaneous log 

containing at a minimum, the following record keeping for each day, or part of a day that PF1.002 is 

operating: 

(a) The calendar date of any required monitoring. 

(b) The total daily throughput rate of coal, in tons, for the corresponding date. 

(c) The total daily hours of operation for the corresponding date. 

(d) The corresponding average hourly throughput rate of coal, in tons per hour. The average hourly 

throughput rate will be determined from the daily throughput rate and the total daily hours of operation 

recorded in (b) and (c) above. 

(e) Results and verification of the visible emissions survey, and documentation of any Method 9 visible 

emission tests that were undertaken, including all documents required under 40 CFR Part 60, Appendix 

A.

vi. As a means of showing initial compliance with the NSPS Subpart Y opacity limit prescribed in L.2.f. of this 

section, within 180 days from the date of issuance of this operating permit, conduct and record a Method 9 

Initial Opacity Compliance Demonstration (IOCD) using the procedures in Section 60.11 to determine the 

opacity from the discharge of PF1.002 to the atmosphere. The Method 9 IOCD shall be performed and 

recorded by a certified opacity reader. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-58

Section VI Specific Operating Conditions (continued) 

L. Emission Unit #PF1.002 (continued) 

4. NAC 445B.3405 (445B.316) Part 70 Program

Monitoring, Recordkeeping, Compliance and Reporting (continued)

b. Reporting 

i. Federally Enforceable PSD Permit Requirement (PSD Permit Issued 1/3/80) – The following reporting 

requirement applies only to Section VIII of the PSD Permit issued 1/3/80: 

The Regional Administrator (USEPA) shall be notified by telephone (by The Permitee) within 48 hours 

following any failure of air pollution control equipment, process equipment, or of a process to operate in a 

normal manner which results an increase in emissions above any allowable emissions limit stated in Section 

VIII of the USEPA-issued PSD permit dated January 3, 1980 of these conditions. In addition the Regional 

Administrator shall be notified in writing within fifteen (15) days of any such failure. This notification shall 

include a description of the malfunctioning equipment or abnormal operation, the date of the initial failure, the 

period of time over which emissions were increased due to failure, the cause of the failure, the estimated 

resultant emissions in excess of those allowed under Section VIII of these conditions, and the methods 

utilized to restore normal operations. Compliance with this malfunction notification provision shall not excuse 

or otherwise constitute a defense to any violations of this permit or of any law or regulations, which such 

malfunction, may cause. 

5. NAC 445B.3405 (445B.316) Part 70 Program

Shielded Requirements

No shielded provisions are established for these emission units. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-59

Section VI. Specific Operating Conditions (continued)

M. Emission Units # S2.010 and PF1.003. UTM: North 4,059.35 km, East 711.68 km (Zone 11).

1. NAC 445B.3405 (445B.316) Part 70 Program

Air Pollution Equipment

a. Emissions from S2.010 shall be ducted to silo vent fabric filters with 100% capture efficiency installed on each 

silo. 

b. Control system for PF1.003 consisting of an enclosure. 

c. S2.010 shall be located in fully-enclosed (tripper-room) building. 

2. NAC 445B.3405 (445B.316) Part 70 Program

Emission Limits

On and after the date of startup of S2.010 and PF1.003, Nevada Power Company - Reid Gardner Station will not

discharge or cause the discharge into the atmosphere the following pollutants in excess of the following specified

limits: 

a. SIP 445.732 Federally Enforceable SIP Requirement - The discharge of PM (particulate matter) to the

atmosphere from S2.010 will not exceed 90.06 pounds per hour. The discharge of PM to the atmosphere from

PF1.003 will not exceed 55.63 pounds per hour. 

b. NAC 445B.22033 State-Only Requirement - The discharge of PM10 (particulate matter less than 10 microns in 

diameter) to the atmosphere from S2.010 will not exceed 90.06 pounds per hour. The discharge of PM10 to the 

atmosphere from PF1.003 will not exceed 55.63 pounds per hour. 

c. NAC 445B.305 Part 70 Program - The discharge of PM (particulate matter) and PM10 (particulate matter less 

than 10 microns in diameter) to the atmosphere from S2.010 and PF1.003 combined will not exceed 0.2 pound 

per hour nor more than 0.1 ton per year. 

d. SIP 445.721 Federally Enforceable SIP Requirement - Unless otherwise provided in SIP 445.721 inclusive, no 

owner or operator may cause or permit the discharge into the atmosphere from any stationary source of any air 

contaminant for a period or periods aggregating more than 3 minutes in any 1 hour which is of an opacity equal 

to or greater than 20 percent. 

e. NAC 445B.22017 (State Only Requirement) - The opacity from the discharges of S2.010, and PF1.003 each, to 

the atmosphere will not equal or exceed 20%. 

f. 40 CFR 60.252(c) NSPS Regulation - On and after the date on which the performance test required to be 

conducted by Section 60.8 is completed, an owner or operator subject to the provisions of NSPS Subpart Y (Coal

Preparation Plants) shall not cause to be discharged into the atmosphere from any coal processing and

conveying equipment, coal storage system, or coal transfer and loading system processing coal, gases which

exhibit 20 percent opacity or greater. 

System 09 - Units #1-3 Coal Storage Silos (C-01) 

S2.010 Loading of (12) Coal Silos for Units #1-3 (C-01a), manufactured by McNalley-Pittsburgh, model #512K-8. 

PF1.003 Unloading of (12) Coal Silos for Units #1-3 (C-01b), manufactured by McNalley-Pittsburgh, model #512K8. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-60

Section VI. Specific Operating Conditions (continued)

M. Emission Units # S2.010 and PF1.003 (continued) 

3. NAC 445B.3405 (445B.316) Part 70 Program

Operating Parameters

a. Maximum allowable throughput of coal in S2.010 will not exceed 1,650 tons per hour. 

b. Maximum allowable throughput of coal in PF1.003 will not exceed 152.8 tons per hour. 

c. Hours

S2.010 and PF1.003 each may operate 8,760 hours per calendar year. 

4. NAC 445B.3405 (445B.316) Part 70 Program

Monitoring, Recordkeeping, Compliance and Reporting

a. Monitoring, Record keeping and Compliance 

The Permittee, upon issuance of this operating permit will: 

i. Monitor and record the throughput of coal for PF1.003 and S2.010 each on a daily basis. 

ii. Monitor and record the hours of operation for PF1.003 and S2.010 each on a daily basis. 

iii. The required monitoring established in (i.) through (ii.) above, will be maintained in a contemporaneous log 

containing at a minimum, the following record keeping for each day, or part of a day that PF1.003 and/or 

S2.010 are operating: 

(a) The calendar date of any required monitoring. 

(b) The total daily throughput rate of coal, in tons, for the corresponding date. 

(c) The total daily hours of operation for the corresponding date. 

(d) The corresponding average hourly throughput rate of coal, in tons per hour. The average hourly 

throughput rate will be determined from the daily throughput rate and the total daily hours of operation 

recorded in (b) and (c) above. 

(e) Results and verification of the visible emissions survey, and documentation of any Method 9 visible 

emission tests that were undertaken, including all documents required under 40 CFR Part 60, Appendix 

A.

iv. As a means of showing initial compliance with the NSPS Subpart Y opacity limit prescribed in M.2.f. of this 

section, within 180 days from the date of issuance of this operating permit, conduct and record a Method 9 

Initial Opacity Compliance Demonstration (IOCD) using the procedures in Section 60.11 to determine the 

opacity from the discharge of S2.010 to the atmosphere. The Method 9 IOCD shall be performed and 

recorded by a certified opacity reader. 

v. On an annual basis for PF1.003, perform and record visible emissions inspections at the point of transfer of 

coal from the coal storage silos to the boiler coal mills, while coal is being discharged from the silos. If these 

visible emissions inspections document any opacity discharged to the atmosphere greater than 0% from the 

enclosed transfer points, provide immediate corrective action in the affected transfer enclosures. Annual 

visible emissions inspection records must show that observations were made and include records of any 

corrective actions taken. 

vi. On an annual basis, perform an inspection of the PF1.003 coal silo discharge enclosures for each of the coal 

storage silos. Annual enclosure inspection records must show that observations were made and include 

records of any corrective actions taken. 

vii. On an annual basis, perform an inspection of the S2.010 coal silo fabric bag filter for each of the coal storage 

silos. Annual bag inspection records must show that observations were made and include records of any 

corrective actions taken. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-61

Section VI. Specific Operating Conditions (continued)

M. Emission Units # S2.010 and PF1.003 (continued) 

4. NAC 445B.3405 (445B.316) Part 70 Program

Monitoring, Record keeping and Compliance (continued) 

b. Reporting 

i. Federally Enforceable PSD Permit Requirement (PSD Permit Issued 1/3/80) – The following reporting 

requirement applies only to Section VIII of the PSD Permit issued 1/3/80: 

The Regional Administrator (USEPA) shall be notified by telephone (by The Permitee) within 48 hours 

following any failure of air pollution control equipment, process equipment, or of a process to operate in a 

normal manner which results an increase in emissions above any allowable emissions limit stated in Section 

VIII of the USEPA-issued PSD permit dated January 3, 1980 of these conditions. In addition the Regional 

Administrator shall be notified in writing within fifteen (15) days of any such failure. This notification shall 

include a description of the malfunctioning equipment or abnormal operation, the date of the initial failure, the 

period of time over which emissions were increased due to failure, the cause of the failure, the estimated 

resultant emissions in excess of those allowed under Section VIII of these conditions, and the methods 

utilized to restore normal operations. Compliance with this malfunction notification provision shall not excuse 

or otherwise constitute a defense to any violations of this permit or of any law or regulations, which such 

malfunction, may cause. 

5. NAC 445B.3405 (445B.316) Part 70 Program

Shielded Requirements

No shielded provisions are established for these emission units. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-62

Section VI. Specific Operating Conditions (continued)

N. Emission Units # S2.011 and PF1.004. UTM: North 4,059.35 km, East 711.68 km (Zone 11).

1. NAC 445B.3405 (445B.316) Part 70 Program

Air Pollution Equipment

a. Emissions from S2.011 shall be ducted to silo vent fabric filters with 100% capture efficiency installed on each 

silo. 

b. Control system for PF1.004 consisting of an enclosure. 

c. S2.011 shall be located in fully enclosed (cascade room) building. 

2. NAC 445B.3405 (445B.316) Part 70 Program

Emission Limits

On and after the date of startup of S2.011 and PF1.004, Nevada Power Company - Reid Gardner Station will not

discharge or cause the discharge into the atmosphere the following pollutants in excess of the following specified

limits: 

a. SIP 445.732 Federally Enforceable SIP Requirement - The discharge of PM to the atmosphere from S2.011 will

not exceed 82.02 pounds per hour. The discharge of PM to the atmosphere from PF1.004 will not exceed 53.40

pounds per hour. 

b. NAC 445B.22033 State-Only Requirement - The discharge of PM10 to the atmosphere from S2.011 will not

exceed 82.02 pounds per hour. The discharge of PM10 to the atmosphere from PF1.004 will not exceed 53.40

pounds per hour. 

c. NAC 445B.305 Part 70 Program - The discharge of PM (particulate matter) and PM10 (particulate matter less 

than 10 microns in diameter) to the atmosphere from S2.011 and PF1.004 combined will not exceed 0.2 pound 

per hour nor more than 0.1 ton per year. 

d. SIP 445.721 Federally Enforceable SIP Requirement - Unless otherwise provided in SIP 445.721 inclusive, no 

owner or operator may cause or permit the discharge into the atmosphere from any stationary source of any air 

contaminant for a period or periods aggregating more than 3 minutes in any 1 hour which is of an opacity equal 

to or greater than 20 percent. 

e. NAC 445B.22017 (State Only Requirement) - The opacity from the discharges of S2.011, and PF1.004 to the 

atmosphere, each, will not equal or exceed 20%. 

f. 40 CFR 60.252(c) NSPS Regulation - On and after the date on which the performance test required to be 

conducted by Section 60.8 is completed, an owner or operator subject to the provisions of NSPS Subpart Y (Coal

Preparation Plants) shall not cause to be discharged into the atmosphere from any coal processing and

conveying equipment, coal storage system, or coal transfer and loading system processing coal, gases which

exhibit 20 percent opacity or greater. 

System 10 - Unit #4 Coal Storage Silos (C-02)

S2.011 Loading of (8) Coal Silos for Unit #4 (C-02a), manufactured by McNalley-Pittsburgh. 

PF1.004 Unloading of (8) Coal Silos for Unit #4 (C-02b), manufactured by McNalley-Pittsburgh. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-63

Section VI. Specific Operating Conditions (continued)

N. Emission Units # S2.011 and PF1.004 (continued) 

3. NAC 445B.3405 (445B.316) Part 70 Program

Operating Parameters

a. Maximum allowable throughput of coal in S2.011 will not exceed 1,800 tons per hour. 

b. Maximum allowable throughput of coal in PF1.004 will not exceed 123.2 tons per hour. 

c. Hours

i. S2.011 and PF1.004 each may operate 8,760 hours per calendar year. 

4. NAC 445B.3405 (445B.316) Part 70 Program

Monitoring, Recordkeeping, Compliance and Reporting

a. Monitoring, Record keeping and Compliance 

The Permittee, upon issuance of this operating permit will: 

i. Monitor and record the throughput of coal for PF1.004 and S2.011 each on a daily basis. 

ii. Monitor and record the hours of operation for PF1.004 and S2.011 each on a daily basis. 

iii. The required monitoring established in (i.) through (ii.) above, will be maintained in a contemporaneous log 

containing at a minimum, the following record keeping for each day, or part of a day that PF1.004 and/or 

S2.001 are operating: 

(a) The calendar date of any required monitoring. 

(b) The total daily throughput rate of coal, in tons, for the corresponding date. 

(c) The total daily hours of operation for the corresponding date. 

(d) The corresponding average hourly throughput rate of coal, in tons per hour. The average hourly 

throughput rate will be determined from the daily throughput rate and the total daily hours of operation 

recorded in (b) and (c) above. 

(e) Results and verification of the visible emissions survey, and documentation of any Method 9 visible 

emission tests that were undertaken, including all documents required under 40 CFR Part 60, Appendix 

A.

iv. As a means of showing initial compliance with the NSPS Subpart Y opacity limit prescribed in M.2.f. of this 

section, within 180 days from the date of issuance of this operating permit, conduct and record a Method 9 

Initial Opacity Compliance Demonstration (IOCD) using the procedures in Section 60.11 to determine the 

opacity from the discharge of S2.011 to the atmosphere. The Method 9 IOCD shall be performed and 

recorded by a certified opacity reader. 

v. On an annual basis for PF1.004, perform and record visible emissions inspections at the point of transfer of 

coal from the coal storage silos to the boiler coal mills, while coal is being discharged from the silos. If these 

visible emissions inspections document any opacity discharged to the atmosphere greater than 0% from the 

enclosed transfer points, provide immediate corrective action in the affected transfer enclosures. Annual 

visible emissions inspection records must show that observations were made and include records of any 

corrective actions taken. 

vi. On an annual basis, perform an inspection of the PF1.003 coal silo discharge enclosures for each of the coal 

storage silos. Annual enclosure inspection records must show that observations were made and include 

records of any corrective actions taken. 

vii. On an annual basis, perform an inspection of the S2.010 coal silo fabric bag filter for each of the coal storage 

silos. Annual bag inspection records must show that observations were made and include records of any 

corrective actions taken. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-64

Section VI. Specific Operating Conditions (continued)

N. Emission Units # S2.011 and PF1.004 (continued) 

4. NAC 445B.3405 (445B.316) Part 70 Program

Monitoring, Record keeping , Compliance and Reporting (continued) 

b. Reporting 

i. Federally Enforceable PSD Permit Requirement (PSD Permit Issued 1/3/80) – The following reporting 

requirement applies only to Section VIII of the PSD Permit issued 1/3/80: 

The Regional Administrator (USEPA) shall be notified by telephone (by The Permitee) within 48 hours 

following any failure of air pollution control equipment, process equipment, or of a process to operate in a 

normal manner which results an increase in emissions above any allowable emissions limit stated in Section 

VIII of the USEPA-issued PSD permit dated January 3, 1980 of these conditions. In addition the Regional 

Administrator shall be notified in writing within fifteen (15) days of any such failure. This notification shall 

include a description of the malfunctioning equipment or abnormal operation, the date of the initial failure, the 

period of time over which emissions were increased due to failure, the cause of the failure, the estimated 

resultant emissions in excess of those allowed under Section VIII of these conditions, and the methods 

utilized to restore normal operations. Compliance with this malfunction notification provision shall not excuse 

or otherwise constitute a defense to any violations of this permit or of any law or regulations, which such 

malfunction, may cause. 

5. NAC 445B.3405 (445B.316) Part 70 Program

Shielded Requirements

No shielded provisions are established for these emission units. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-65

Section VI. Specific Operating Conditions (continued) 

O. Emission Units # PF1.005 through # PF1.008. UTM: North 4,059.35 km, East 711.68 km (Zone 11). 

System 11 - Coal Crushing & Screening Station (C-03) 

PF1.005 Coal Granulation Crusher #1 (C-03a), manufactured by Pennsylvania Co., model #TKKB, serial #4149. 

PF1.006 Coal Granulation Crusher #2 (C-03b), manufactured by Pennsylvania Co., model #TKKB, serial #4150. 

PF1.007 Coal Granulation Crusher #3 (C-03c), manufactured by Pennsylvania Co., model #TK-9-388, serial 

#3101. 

PF1.008 Link Belt Coal Screen (C-03d), manufactured by FMC, model #823513-Z. 

1. NAC 445B.3405 (445B.316) Part 70 Program

Air Pollution Equipment

a. Control systems for PF1.005 through PF1.008 each shall consist of water sprays installed at PF1.005, PF1.006, 

PF1.007 and PF1.008. 

2. NAC 445B.3405 (445B.316) Part 70 Program

Emission Limits

On and after the date of startup of PF1.005 through PF1.008, the Permittee will not discharge or cause the 

discharge into the atmosphere the following pollutants in excess of the following specified limits: 

a. SIP 445.732 Federally Enforceable SIP Requirement - The discharge of PM (particulate matter) to the 

atmosphere from PF1.005 through PF1.007, each, will not exceed 80.51 pounds per hour. The discharge of PM 

to the atmosphere from PF1.008 will not exceed 90.06 pounds per hour. 

b. NAC 445B.22033 State-Only Requirement - The discharge of PM10 (particulate matter less than 10 microns in 

diameter) to the atmosphere from PF1.005 through PF1.007, each, will not exceed 80.51 pounds per hour. The 

discharge of PM10 to the atmosphere from PF1.008 will not exceed 90.06 pounds per hour. 

c. NAC 445B.305 Part 70 Program - The discharge of PM (particulate matter) and PM10 (particulate matter less 

than 10 microns in diameter) to the atmosphere from PF1.005 through PF1.007 each will not exceed 0.7 pound 

per hour, nor more than 0.04 ton per year. The discharge of PM (particulate matter) and PM10 (particulate matter 

less than 10 microns in diameter) to the atmosphere from PF1.008 will not exceed 2.1 pounds per hour, nor more 

than 0.1 ton per year. 

d. SIP 445.721 Federally Enforceable SIP Requirement - Unless otherwise provided in SIP 445.721 inclusive, no 

owner or operator may cause or permit the discharge into the atmosphere from any stationary source of any air 

contaminant for a period or periods aggregating more than 3 minutes in any 1 hour which is of an opacity equal 

to or greater than 20 percent. 

e. NAC 445B.22017 (State Only Requirement) - The opacity from the discharges of PF1.005 through PF1.008 to 

the atmosphere, each, will not equal or exceed 20%. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-66

Section VI. Specific Operating Conditions (continued) 

O. Emission Units # PF1.005 through # PF1.008 (continued) 

3. NAC 445B.3405 (445B.316) Part 70 Program

Operating Parameters

a. Maximum allowable throughput of coal in PF1.005 through PF1.007, each, will not exceed 1,250 tons per hour, 

averaged on a daily basis. 

b. Maximum allowable throughput of coal in PF1.008 will not exceed 2,500 tons per hour, averaged on a daily 

basis. 

c. Hours

i. PF1.005 through PF1.008 each may operate 100 hours per calendar year. 

4. NAC 445B.3405 (445B.316) Part 70 Program

Monitoring, Recordkeeping, Compliance and Reporting

a. Monitoring, Record keeping and Compliance 

The Permittee, upon issuance of this operating permit will: 

i. Monitor and record the throughput of coal for PF1.005 through PF1.007 each on a daily basis. 

ii. Monitor and record the hours of operation for PF1.005 through PF1.007 each on a daily basis. 

iii. The required monitoring established in (i.) through (iv.) above, will be maintained in a contemporaneous log 

containing at a minimum, the following record keeping for each day, or part of a day that PF1.005 through 

PF1.007 are operating: 

(a) The calendar date of any required monitoring. 

(b) The total daily throughput rate of coal, in tons, for the corresponding date. 

(c) The total daily hours of operation for the corresponding date. 

(d) The corresponding average hourly throughput rate of coal, in tons per hour. The average hourly 

throughput rate will be determined from the daily throughput rate and the total daily hours of operation 

recorded in (b) and (c) above. 

b. Reporting 

i. Federally Enforceable PSD Permit Requirement (PSD Permit Issued 1/3/80) – The following reporting 

requirement applies only to Section VIII of the PSD Permit issued 1/3/80: 

The Regional Administrator (USEPA) shall be notified by telephone (by The Permitee) within 48 hours 

following any failure of air pollution control equipment, process equipment, or of a process to operate in a 

normal manner which results an increase in emissions above any allowable emissions limit stated in Section 

VIII of the USEPA-issued PSD permit dated January 3, 1980 of these conditions. In addition the Regional 

Administrator shall be notified in writing within fifteen (15) days of any such failure. This notification shall 

include a description of the malfunctioning equipment or abnormal operation, the date of the initial failure, the 

period of time over which emissions were increased due to failure, the cause of the failure, the estimated 

resultant emissions in excess of those allowed under Section VIII of these conditions, and the methods 

utilized to restore normal operations. Compliance with this malfunction notification provision shall not excuse 

or otherwise constitute a defense to any violations of this permit or of any law or regulations, which such 

malfunction, may cause. 

5. NAC 445B.3405 (445B.316) Part 70 Program

Shielded Requirements

No shielded provisions are established for these emission units. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-67

Section VI. Specific Operating Conditions (continued) 

P. Emission Units #S2.012 and PF1.009. UTM: North 4,059.35 km, East 711.68 km (Zone 11). 

System 12 - Units #1-3 Fly Ash Storage Silos (C-04) 

S2.012 Loading of Fly Ash Silo for Units #1-3 (C-04a), manufactured by United Conveyor Corp. 

PF1.009 Unloading of Fly Ash Silo for Units #1-3 (C-04a), manufactured by United Conveyor Corp. 

1. NAC 445B.3405 (445B.316) Part 70 Program

Air Pollution Equipment

a.Emissions from S2.012 shall be ducted to a pulse-jet fabric filter with 100% capture efficiency installed on the fly 

ash silo. 

b. Control system for PF1.009 consisting of best operational practices to ensure compliance with the emission limits 

stated below. 

2. NAC 445B.3405 (445B.316) Part 70 Program

Emission Limits

On and after the date of startup of S2.012 and PF1.009, each, the Permittee will not discharge or cause the 

discharge into the atmosphere the following pollutants in excess of the following specified limits: 

a. SIP 445.732 Federally Enforceable SIP Requirement - The discharge of PM (particulate matter) to the 

atmosphere from S2.012 and PF1.009 each will not exceed 17.20 pounds per hour. 

b. NAC 445B.22033 State-Only Requirement - The discharge of PM10 (particulate matter less than 10 microns in 

diameter) to the atmosphere from S2.012 and PF1.009 each will not exceed 17.20 pounds per hour. 

c. NAC 445B.305 Part 70 Program - The discharge of PM (particulate matter) and PM10 (particulate matter less 

than 10microns in diameter) to the atmosphere from S2.012 and PF1.009 combined will not exceed 0.6 pound 

per hour nor more than 4.4 ton per year. 

d. SIP 445.721 Federally Enforceable SIP Requirement - Unless otherwise provided in SIP 445.721 inclusive, no 

owner or operator may cause or permit the discharge into the atmosphere from any stationary source of any air 

contaminant for a period or periods aggregating more than 3 minutes in any 1 hour, which is of an opacity equal 

to or greater than 20 percent. 

e. NAC 445B.22017 (State Only Requirement) - The opacity from the discharges S2.012 and PF1.009 each, to the 

atmosphere will not equal or exceed 20%. 

3. NAC 445B.3405 (445B.316) Part 70 Program

Operating Parameters

a. Maximum allowable throughput of fly ash in S2.012 and PF1.009 each will not exceed 8.5 tons per hour. 

b. Hours

i. S2.012 and PF1.009 each may operate 8,760 hours per calendar year.
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-68

Section VI. Specific Operating Conditions (continued) 

P. Emission Units #S2.012 and #PF1.009 (continued) 

4. NAC 445B.3405 (445B.316) Part 70 Program

Monitoring, Recordkeeping, Compliance and Reporting

a. Monitoring, Record keeping and Compliance 

The Permittee, upon issuance of this operating permit will: 

i. Monitor and record the throughput of fly ash for PF1.009 and S2.012 each on a daily basis. 

ii. Monitor and record the hours of operation for PF1.009 and S2.012 each on a daily basis. 

iii. The required monitoring established in (i.) through (ii.) above, will be maintained in a contemporaneous log 

containing at a minimum, the following record keeping for each day, or part of a day that PF1.009 and/or 

S2.012 are operating: 

(a) The calendar date of any required monitoring. 

(b) The total daily throughput rate of fly ash, in tons, for the corresponding date. 

(c) The total daily hours of operation for the corresponding date. 

(d) The corresponding average hourly throughput rate of fly ash, in tons per hour. The average hourly 

throughput rate will be determined from the daily throughput rate and the total daily hours of operation 

recorded in (b) and (c) above. 

(e) Calculate fly ash throughput in tons as follows: [8.5 tons per hour] x [hours of operation] x [baghouse 

control efficiency]. 

The value for baghouse control efficiency shall be from a written manufacturer’s guarantee, or a NDEPBAPC approved performance test of the baghouse under permitted conditions or the NDEP-BAPC 

standard control efficiency rating for a properly maintained baghouse of 0.02 grains/dscf. Record what 

method is used to obtain baghouse control efficiency. 

b. Reporting 

i. Federally Enforceable PSD Permit Requirement (PSD Permit Issued 1/3/80) – The following reporting 

requirement applies only to Section VIII of the PSD Permit issued 1/3/80: 

The Regional Administrator (USEPA) shall be notified by telephone (by The Permitee) within 48 hours 

following any failure of air pollution control equipment, process equipment, or of a process to operate in a 

normal manner which results an increase in emissions above any allowable emissions limit stated in Section 

VIII of the USEPA-issued PSD permit dated January 3, 1980 of these conditions. In addition the Regional 

Administrator shall be notified in writing within fifteen (15) days of any such failure. This notification shall 

include a description of the malfunctioning equipment or abnormal operation, the date of the initial failure, the 

period of time over which emissions were increased due to failure, the cause of the failure, the estimated 

resultant emissions in excess of those allowed under Section VIII of these conditions, and the methods 

utilized to restore normal operations. Compliance with this malfunction notification provision shall not excuse 

or otherwise constitute a defense to any violations of this permit or of any law or regulations, which such 

malfunction, may cause. 

5. NAC 445B.3405 (445B.316) Part 70 Program

Shielded Requirements

No shielded provisions are established for these emission units. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-69

Section VI. Specific Operating Conditions (continued) 

Q. Emission Units #S2.013 and PF1.010. UTM: North 4,059.35 km, East 711.68 km (Zone 11). 

System 13 - Units #1-3 Backup Fly Ash Storage Silos (C-07) 

S2.013 Loading of Backup Fly Ash Silo for Units #1-3 (C-07a), manufactured by Smoot Co. Inc. 

PF1.010 Unloading of Backup Fly Ash Silo for Units #1-3 (C-07a), manufactured by Smoot Co. Inc. 

1. NAC 445B.3405 (445B.316) Part 70 Program

Air Pollution Equipment

a. Emissions from S2.013 shall be ducted to a pulse-jet fabric filter with 100% capture efficiency installed on the fly 

ash silo. 

b. Control system for PF1.010 consisting of best operational practices to ensure compliance with the emission limits 

stated below. 

2. NAC 445B.3405 (445B.316) Part 70 Program

Emission Limits

On and after the date of startup of S2.013 and PF1.010, each, the Permittee will not discharge or cause the 

discharge into the atmosphere the following pollutants in excess of the following specified limits: 

a. SIP 445.732 Federally Enforceable SIP Requirement - The discharge of PM to the atmosphere from S2.013 will 

not exceed 13.62 pounds per hour. The discharge of PM to the atmosphere from PF1.010 will not exceed 44.39

pounds per hour. 

b. NAC 445B.22033 State-Only Requirement - The discharge of PM10 to the atmosphere from S2.013 will not 

exceed 13.62 pounds per hour. The discharge of PM10 to the atmosphere from PF1.010 will not exceed 44.39

pounds per hour. 

c. NAC 445B.305 Part 70 Program - The discharge of PM (particulate matter) and PM10 (particulate matter less 

than 10microns in diameter) to the atmosphere from S2.013 and PF1.010 combined will not exceed 0.5 pound 

per hour nor more than 1.8 tons per year. 

d. SIP 445.721 Federally Enforceable SIP Requirement - Unless otherwise provided in SIP 445.721 inclusive, no 

owner or operator may cause or permit the discharge into the atmosphere from any stationary source of any air 

contaminant for a period or periods aggregating more than 3 minutes in any 1 hour, which is of an opacity equal 

to or greater than 20 percent. 

e. NAC 445B.22017 (State Only Requirement) - The opacity from the discharges S2.013 and PF1.010 each to the 

atmosphere, will not equal or exceed 20%. 

3. NAC 445B.3405 (445B.316) Part 70 Program

Operating Parameters

a. Maximum allowable throughput of fly ash in S2.013 will not exceed 6 tons per hour. 

b. Maximum allowable throughput of fly ash in PF1.010 will not exceed 35 tons per hour. 

c. Hours

1. S2.013 and PF1.010 each may operate 8,760 hours per calendar year.
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-70

Section VI. Specific Operating Conditions (continued) 

Q. Emission Units # S2.013 and PF1.010 (continued) 

4. NAC 445B.3405 (445B.316) Part 70 Program

Monitoring, Recordkeeping, Compliance and Reporting

a. Monitoring, Record keeping and Compliance 

The Permittee, upon issuance of this operating permit will: 

i. Monitor and record the throughput of fly ash for PF1.010 and S2.013 each on a daily basis. 

ii. Monitor and record the hours of operation for PF1.010 and S2.013 each on a daily basis. 

iii. The required monitoring established in (i.) through (ii.) above, will be maintained in a contemporaneous log 

containing at a minimum, the following record keeping for each day, or part of a day that PF1.010 and/or 

S2.013 are operating: 

(a) The calendar date of any required monitoring. 

(b) The total daily throughput rate of fly ash, in tons, for the corresponding date. 

(c) The total daily hours of operation for the corresponding date. 

(d) The corresponding average hourly throughput rate of fly ash, in tons per hour. The average hourly 

throughput rate will be determined from the daily throughput rate and the total daily hours of operation 

recorded in (b) and (c) above. 

(e) Calculate fly ash throughput in tons as follows: [8.5 tons per hour] x [hours of operation] x [baghouse 

control efficiency]. 

The value for baghouse control efficiency shall be from a written manufacturer’s guarantee, or a NDEPBAPC approved performance test of the baghouse under permitted conditions or the NDEP-BAPC 

standard control efficiency rating for a properly maintained baghouse of 0.02 grains/dscf. Record what 

method is used to obtain baghouse control efficiency. 

b. Reporting 

i. Federally Enforceable PSD Permit Requirement (PSD Permit Issued 1/3/80) – The following reporting 

requirement applies only to Section VIII of the PSD Permit issued 1/3/80: 

The Regional Administrator (USEPA) shall be notified by telephone (by The Permitee) within 48 hours 

following any failure of air pollution control equipment, process equipment, or of a process to operate in a 

normal manner which results an increase in emissions above any allowable emissions limit stated in Section 

VIII of the USEPA-issued PSD permit dated January 3, 1980 of these conditions. In addition the Regional 

Administrator shall be notified in writing within fifteen (15) days of any such failure. This notification shall 

include a description of the malfunctioning equipment or abnormal operation, the date of the initial failure, the 

period of time over which emissions were increased due to failure, the cause of the failure, the estimated 

resultant emissions in excess of those allowed under Section VIII of these conditions, and the methods 

utilized to restore normal operations. Compliance with this malfunction notification provision shall not excuse 

or otherwise constitute a defense to any violations of this permit or of any law or regulations, which such 

malfunction, may cause. 

5. NAC 445B.3405 (445B.316) Part 70 Program

Shielded Requirements

No shielded provisions are established for these emission units. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-71

Section VI. Specific Operating Conditions (continued) 

R. Emission Units #S2.014 and PF1.011. UTM: North 4,059.35 km, East 711.68 km (Zone 11). 

System 14 - Unit #4 Fly Ash Storage Silos (C-09) 

S2.014 Loading of Fly Ash Silo for Unit #4 (C-09a), manufactured by United Conveyor Corp. 

PF1.011 Unloading of Fly Ash Silo for Unit #4 (C-09b), manufactured by United Conveyor Corp. 

1. NAC 445B.3405 (445B.316) Part 70 Program

Air Pollution Equipment

a. Emissions from S2.014 shall be ducted to a pulse-jet fabric filter with 100% capture efficiency installed on the fly 

ash silo. 

b. Control system for PF1.011 consisting of best operational practices to ensure compliance with the emission limits 

stated below. 

2. NAC 445B.3405 (445B.316) Part 70 Program

Emission Limits

On and after the date of startup of S2.014 and PF1.011, each, the Permittee will not discharge or cause the 

discharge into the atmosphere the following pollutants in excess of the following specified limits: 

a. SIP 445.732 Federally Enforceable SIP Requirement - The discharge of PM to the atmosphere from S2.014 and 

PF1.011, each, will not exceed 20.44 pounds per hour. 

b. NAC 445B.22033 State-Only Requirement - The discharge of PM10 to the atmosphere from S2.014 and 

PF1.011, each, will not exceed 20.44 pounds per hour. 

c. NAC 445B.305 Part 70 Program - The discharge of PM (particulate matter) and PM10 (particulate matter less 

than 10microns in diameter) to the atmosphere from S2.014 and PF1.011 combined, will not exceed 0.3 pound 

per hour nor more than 1.7 tons per year. 

d. SIP 445.721 Federally Enforceable SIP Requirement - Unless otherwise provided in SIP 445.721 inclusive, no 

owner or operator may cause or permit the discharge into the atmosphere from any stationary source of any air 

contaminant for a period or periods aggregating more than 3 minutes in any 1 hour, which is of an opacity equal 

to or greater than 20 percent. 

e. NAC 445B.22017 (State Only Requirement) - The opacity from the discharges of S2.014 and PF1.020 each to 

the atmosphere will not equal or exceed 20%. 

3. NAC 445B.3405 (445B.316) Part 70 Program

Operating Parameters

a. Maximum allowable throughput of fly ash in S2.014 and PF1.011, each, will not exceed 11 tons per hour. 

b. Hours

1. S2.014 and PF1.011 each may operate 8,760 hours per calendar year.
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-72

Section VI. Specific Operating Conditions (continued) 

R. Emission Units # S2.014 and PF1.011 (continued) 

4. NAC 445B.3405 (445B.316) Part 70 Program

Monitoring, Record keeping, Compliance and Reporting

a. Monitoring, Recordkeeping and Compliance 

The Permittee, upon issuance of this operating permit will: 

i. Monitor and record the throughput of fly ash for PF1.011 and S2.014 each on a daily basis. 

ii. Monitor and record the hours of operation for PF1.011 and S2.014 each on a daily basis. 

iii. The required monitoring established in (i.) through (ii.) above, will be maintained in a contemporaneous log 

containing at a minimum, the following record keeping for each day, or part of a day that PF1.011 and/or 

S2.014 are operating: 

(a) The calendar date of any required monitoring. 

(b) The total daily throughput rate of fly ash, in tons, for the corresponding date. 

(c) The total daily hours of operation for the corresponding date. 

(d) The corresponding average hourly throughput rate of fly ash, in tons per hour. The average hourly 

throughput rate will be determined from the daily throughput rate and the total daily hours of operation 

recorded in (b) and (c) above. 

(e) Calculate fly ash throughput in tons as follows: [11.0 tons per hour] x [hours of operation] x [baghouse 

control efficiency]. 

The value for baghouse control efficiency shall be from a written manufacturer’s guarantee, or a NDEPBAPC approved performance test of the baghouse under permitted conditions or the NDEP-BAPC 

standard control efficiency rating for a properly maintained baghouse of 0.02 grains/dscf. Record what 

method is used to obtain baghouse control efficiency. 

b. Reporting 

i. Federally Enforceable PSD Permit Requirement (PSD Permit Issued 1/3/80) – The following reporting 

requirement applies only to Section VIII of the PSD Permit issued 1/3/80: 

The Regional Administrator (USEPA) shall be notified by telephone (by The Permitee) within 48 hours 

following any failure of air pollution control equipment, process equipment, or of a process to operate in a 

normal manner which results an increase in emissions above any allowable emissions limit stated in Section 

VIII of the USEPA-issued PSD permit dated January 3, 1980 of these conditions. In addition the Regional 

Administrator shall be notified in writing within fifteen (15) days of any such failure. This notification shall 

include a description of the malfunctioning equipment or abnormal operation, the date of the initial failure, the 

period of time over which emissions were increased due to failure, the cause of the failure, the estimated 

resultant emissions in excess of those allowed under Section VIII of these conditions, and the methods 

utilized to restore normal operations. Compliance with this malfunction notification provision shall not excuse 

or otherwise constitute a defense to any violations of this permit or of any law or regulations, which such 

malfunction, may cause. 

5. NAC 445B.3405 (445B.316) Part 70 Program

Shielded Requirements

No shielded provisions are established for these emission units.
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-73

Section VI. Specific Operating Conditions (continued) 

S. Emission Units # S2.015 and #PF1.012. UTM: North 4,059.35 km, East 711.68 km (Zone 11).

System 15 – Units #1-3 Soda Ash Slurry Tank 

S2.015 Loading of Units #1-3 Soda Ash Slurry Tank (W-01), manufactured by Brown-Minneapolis Tank, serial 

#276901. 

PF1.012 Unloading of Units #1-3 Soda Ash Slurry Tank (W-01), manufactured by Brown-Minneapolis Tank, serial 

#276901. 

1. NAC 445B.3405 (445B.316) Part 70 Program

Air Pollution Equipment

a. Emissions from S2.015 shall be ducted to an inverted venturi scrubber with 100% capture efficiency installed on 

S2.015. 

b. Control system for PF1.012 shall consist of a wet (saturated) process. 

2. NAC 445B.3405 (445B.316) Part 70 Program

Emission Limits

On and after the date of startup of S2.015 and PF1.012, the Permittee will not discharge or cause the discharge into 

the atmosphere the following pollutants in excess of the following specified limits: 

a. SIP 445.732 Federally Enforceable SIP Requirement - The discharge of PM (particulate matter) to the 

atmosphere from S2.015 and PF1.012 each will not exceed 7.37 pounds per hour. 

b. NAC 445B.22033 State-Only Requirement - The discharge of PM10 (particulate matter less than 10 microns in 

diameter) to the atmosphere from S2.015 and PF1.012 each will not exceed 7.37 pounds per hour. 

c. NAC 445B.305 Part 70 Program - The discharge of PM (particulate matter) and PM10 (particulate matter less 

than 10 microns in diameter) to the atmosphere from S2.015 and PF1.012 combined will not exceed 0.13 pound 

per hour nor more than 0.54 ton per year. 

d. SIP 445.721 Federally Enforceable SIP Requirement - Unless otherwise provided in SIP 445.721 inclusive, no 

owner or operator may cause or permit the discharge into the atmosphere from any stationary source of any air 

contaminant for a period or periods aggregating more than 3 minutes in any 1 hour which is of an opacity equal 

to or greater than 20 percent. 

e. NAC 445B.22017 (State Only Requirement) - The opacity from the discharges of S2.015 and PF1.012 each to 

the atmosphere will not equal or exceed 20%. 

3. NAC 445B.3405 (445B.316) Part 70 Program

Operating Parameters

a. Maximum allowable throughput of soda ash in S2.015 will not exceed 2.4 tons per hour. 

b. Maximum allowable throughput of soda ash solution for PF1.012 will not exceed 2.4 tons per hour. 

c. Hours

S2.015 and PF1.012 each may operate 8,760 hours per calendar year.
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-74

Section VI. Specific Operating Conditions (continued) 

S. Emission Units # S2.015 and PF1.012 (continued) 

4. NAC 445B.3405 (445B.316) Part 70 Program

Monitoring, Record keeping and Compliance

The Permittee, upon issuance of this operating permit will: 

i. Monitor and record the throughput of soda ash for PF1.012 and S2.015 each on a daily basis. 

ii. Monitor and record the hours of operation for PF1.012 and S2.015 each on a daily basis. 

iii. The required monitoring established in (i.) through (ii.) above, will be maintained in a contemporaneous log 

containing at a minimum, the following record keeping for each day, or part of a day that PF1.012 and/or S2.015

are operating: 

(a) The calendar date of any required monitoring. 

(b) The total daily throughput rate of soda ash, in tons, for the corresponding date. 

(c) The total daily hours of operation for the corresponding date. 

(d) The corresponding average hourly throughput rate of soda ash, in tons per hour. The average hourly 

throughput rate will be determined from the daily throughput rate and the total daily hours of operation 

recorded in (b) and (c) above. 

5. NAC 445B.3405 (445B.316) Part 70 Program

Shielded Requirements

No shielded provisions are established for these emission units. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-75

Section VI. Specific Operating Conditions (continued) 

T. Emission Units # S2.016 and PF1.013. UTM: North 4,059.35 km, East 711.68 km (Zone 11). 

System 16 - Unit #4 FGD Soda Ash Slurry Tank 

S2.016 Loading of Unit #4 FGD Soda Ash Slurry Tank (W-02), manufactured by Portec, serial #T-403-1. 

PF1.013 Unloading of Unit #4 FGD Soda Ash Slurry Tank (W-02), manufactured by Portec, serial #T-403-1. 

1. NAC 445B.3405 (445B.316) Part 70 Program

Air Pollution Equipment

a. Emissions from S2.016 shall be ducted to an inverted venturi scrubber with 100% capture efficiency installed on 

S2.016. 

b. Control system for PF1.013 shall consist of a wet (saturated) process. 

2. NAC 445B.3405 (445B.316) Part 70 Program

Emission Limits

On and after the date of startup of S2.016 and PF1.013, each, the Permittee will not discharge or cause the 

discharge into the atmosphere the following pollutants in excess of the following specified limits: 

a. SIP 445.732 Federally Enforceable SIP Requirement - The discharge of PM to the atmosphere from S2.016 and 

PF1.013 each will not exceed 6.63 pounds per hour. 

b. NAC 445B.22033 State-Only Requirement - The discharge of PM10 to the atmosphere from S2.016 and PF1.013 

each will not exceed 6.63 pounds per hour. 

c. NAC 445B.305 Part 70 Program - The discharge of PM (particulate matter) and PM10 (particulate matter less 

than 10 microns in diameter) to the atmosphere from S2.016 and PF1.013 combined will not exceed 0.11 pound 

per hour nor more than 0.49 ton per year. 

d. SIP 445.721 Federally Enforceable SIP Requirement - Unless otherwise provided in SIP 445.721 inclusive, no 

owner or operator may cause or permit the discharge into the atmosphere from any stationary source of any air 

contaminant for a period or periods aggregating more than 3 minutes in any 1 hour which is of an opacity equal 

to or greater than 20 percent. 

e. NAC 445B.22017 (State Only Requirement) - The opacity from the discharges of S2.016 and PF1.013 each, to 

the atmosphere will not equal or exceed 20%. 

3. NAC 445B.3405 (445B.316) Part 70 Program

Operating Parameters

a. Maximum allowable throughput of soda ash in S2.016 will not exceed 2.05 tons per hour. 

b. Maximum allowable throughput of soda ash solution for PF1.013 will not exceed 2.05 tons per hour. 

c. Hours

S2.016 and PF1.013 each may operate 8,760 hours per calendar year.
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-76

Section VI. Specific Operating Conditions (continued) 

T. Emission Units # S2.016 and #PF1.013 (continued) 

4. NAC 445B.3405 (445B.316) Part 70 Program

Monitoring, Record keeping and Compliance

The Permittee, upon issuance of this operating permit will: 

i. Monitor and record the throughput of soda ash for PF1.013 and S2.016 each on a daily basis. 

ii. Monitor and record the hours of operation for PF1.013 and S2.016 each on a daily basis. 

iii. The required monitoring established in (i.) through (ii.) above, will be maintained in a contemporaneous log 

containing at a minimum, the following record keeping for each day, or part of a day that PF1.013 and/or S2.016

are operating: 

(a) The calendar date of any required monitoring. 

(b) The total daily throughput rate of soda ash, in tons, for the corresponding date. 

(c) The total daily hours of operation for the corresponding date. 

(d) The corresponding average hourly throughput rate of soda ash, in tons per hour. The average hourly 

throughput rate will be determined from the daily throughput rate and the total daily hours of operation 

recorded in (b) and (c) above. 

5. NAC 445B.3405 (445B.316) Part 70 Program

Shielded Requirements

No shielded provisions are established for these emission units. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-77

Section VI. Specific Operating Conditions (continued) 

U. Emission Units # S2.017 and PF1.014. UTM: North 4,059.35 km, East 711.68 km (Zone 11).

System 17 – Unit #4 FGD Lime Storage Silo 

S2.017 Loading of Unit #4 FGD Lime Storage Silo (W-03), manufactured by O.A. Newton, serial #276901. 

PF1.014 Unloading of Unit #4 FGD Lime Storage Silo (W-03), manufactured by O.A. Newton, serial #276901. 

1. NAC 445B.3405 (445B.316) Part 70 Program

Air Pollution Equipment

a. Emissions from S2.017 shall be ducted to pulse-jet fabric filter with 100% capture efficiency installed on S2.017. 

b. Control system for PF1.014 consisting of an enclosure. 

2. NAC 445B.3405 (445B.316) Part 70 Program

Emission Limits

On and after the date of startup of S2.017 and PF1.014 each, the Permittee will not discharge or cause the 

discharge into the atmosphere the following pollutants in excess of the following specified limits: 

a. SIP 445.732 Federally Enforceable SIP Requirement - The discharge of PM to the atmosphere from S2.017 and 

PF1.014 each will not exceed 1.79 pounds per hour. 

b. NAC 445B.22033 State-Only Requirement - The discharge of PM10 to the atmosphere from S2.017 and PF1.014 

each will not exceed 1.79 pounds per hour. 

c. NAC 445B.305 Part 70 Program - The discharge of PM (particulate matter) and PM10 (particulate matter less 

than 10 microns in diameter) to the atmosphere from S2.017 and PF1.014 combined will not exceed 0.008 

pound per hour nor more than 0.03 ton per year. 

d. SIP 445.721 Federally Enforceable SIP Requirement - Unless otherwise provided in SIP 445.721 inclusive, no 

owner or operator may cause or permit the discharge into the atmosphere from any stationary source of any air 

contaminant for a period or periods aggregating more than 3 minutes in any 1 hour which is of an opacity equal 

to or greater than 20 percent. 

e. NAC 445B.22017 (State Only Requirement) - The opacity from the discharges of S2.017 and PF1.014 each, to 

the atmosphere will not equal or exceed 20%. 

3. NAC 445B.3405 (445B.316) Part 70 Program

Operating Parameters

a. Maximum allowable throughput of lime in S2.017 will not exceed 0.29 ton per hour. 

b. Maximum allowable throughput of lime in PF1.014 will not exceed 0.29 ton per hour. 

c. Hours

S2.010 and PF1.014 each may operate 8,760 hours per calendar year.
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-78

Section VI. Specific Operating Conditions (continued) 

U. Emission Units # S2.017 and #PF1.014 (continued) 

4. NAC 445B.3405 (445B.316) Part 70 Program

Monitoring, Recordkeeping, Compliance and Reporting

a. Monitoring, Record keeping and Compliance 

The Permittee, upon issuance of this operating permit will: 

i. Monitor and record the throughput of lime for PF1.014 and S2.017 each on a daily basis. 

ii. Monitor and record the hours of operation for PF1.014 and S2.017 each on a daily basis. 

iii. The required monitoring established in (i.) through (ii.) above, will be maintained in a contemporaneous log 

containing at a minimum, the following record keeping for each day, or part of a day that PF1.014 and/or 

S2.017 are operating: 

(a) The calendar date of any required monitoring. 

(b) The total daily throughput rate of lime, in tons, for the corresponding date. 

(c) The total daily hours of operation for the corresponding date. 

(d) The corresponding average hourly throughput rate of lime, in tons per hour. The average hourly 

throughput rate will be determined from the daily throughput rate and the total daily hours of operation 

recorded in (b) and (c) above. 

b. Reporting 

i. Federally Enforceable PSD Permit Requirement (PSD Permit Issued 1/3/80) – The following reporting 

requirement applies only to Section VIII of the PSD Permit issued 1/3/80: 

The Regional Administrator (USEPA) shall be notified by telephone (by The Permitee) within 48 hours 

following any failure of air pollution control equipment, process equipment, or of a process to operate in a 

normal manner which results an increase in emissions above any allowable emissions limit stated in Section 

VIII of the USEPA-issued PSD permit dated January 3, 1980 of these conditions. In addition the Regional 

Administrator shall be notified in writing within fifteen (15) days of any such failure. This notification shall 

include a description of the malfunctioning equipment or abnormal operation, the date of the initial failure, the 

period of time over which emissions were increased due to failure, the cause of the failure, the estimated 

resultant emissions in excess of those allowed under Section VIII of these conditions, and the methods 

utilized to restore normal operations. Compliance with this malfunction notification provision shall not excuse 

or otherwise constitute a defense to any violations of this permit or of any law or regulations, which such 

malfunction, may cause. 

5. NAC 445B.3405 (445B.316) Part 70 Program

Shielded Requirements

No shielded provisions are established for these emission units. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-79

Section VI. Specific Operating Conditions (continued) 

V. Emission Units # S2.018 and #PF1.015. UTM: North 4,059.35 km, East 711.68 km (Zone 11).

System 18 – Unit #4 Water Treatment Soda Ash Silo 

S2.018 Loading of Unit #4 Water Treatment Soda Ash Silo (W-04), manufactured by O. A. Newton. 

PF1.015 Unloading of Unit #4 Water Treatment Soda Ash Silo (W-04), manufactured by O. A. Newton. 

1. NAC 445B.3405 (445B.316) Part 70 Program

Air Pollution Equipment

a. Emissions from S2.018 shall be ducted to pulse-jet fabric filter with 100% capture efficiency installed on S2.018. 

b. Control system for PF1.015 consisting of an enclosure. 

2. NAC 445B.3405 (445B.316) Part 70 Program

Emission Limits

On and after the date of startup of S2.018 and PF1.015 each, the Permittee will not discharge or cause the 

discharge into the atmosphere the following pollutants in excess of the following specified limits: 

a. SIP 445.732 Federally Enforceable SIP Requirement - The discharge of PM to the atmosphere from S2.018 and 

PF1.015 each will not exceed 3.85 pounds per hour. 

b. NAC 445B.22033 State-Only Requirement - The discharge of PM10 to the atmosphere from S2.018 and PF1.105 

each will not exceed 3.85 pounds per hour. 

c. NAC 445B.305 Part 70 Program - The discharge of PM (particulate matter) and PM10 (particulate matter less 

than 10 microns in diameter) to the atmosphere from S2.013 and PF1.015 combined will not exceed 0.02 pound 

per hour nor more than 0.06 tons per year. 

d. SIP 445.721 Federally Enforceable SIP Requirement - Unless otherwise provided in SIP 445.721 inclusive, no 

owner or operator may cause or permit the discharge into the atmosphere from any stationary source of any air 

contaminant for a period or periods aggregating more than 3 minutes in any 1 hour which is of an opacity equal 

to or greater than 20 percent. 

e. NAC 445B.22017 (State Only Requirement) - The opacity from the discharges of S2.018 and PF1.015 each, to 

the atmosphere will not equal or exceed 20%. 

3. NAC 445B.3405 (445B.316) Part 70 Program

Operating Parameters

a. Maximum allowable throughput of soda ash in S2.018 will not exceed 0.91 ton per hour. 

b. Maximum allowable throughput of soda ash in PF1.015 will not exceed 0.91 ton per hour. 

c. Hours

S2.018 and PF1.015 each may operate 8,760 hours per calendar year. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-80

Section VI. Specific Operating Conditions (continued) 

V. Emission Units # S2.018 and #PF1.015 (continued) 

4. NAC 445B.3405 (445B.316) Part 70 Program

Monitoring, Record keeping and Compliance

The Permittee, upon issuance of this operating permit will: 

i. Monitor and record the throughput of soda ash for PF1.015 and S2.018 each on a daily basis. 

ii. Monitor and record the hours of operation for PF1.015 and S2.018 each on a daily basis. 

iii. The required monitoring established in (i.) through (ii.) above, will be maintained in a contemporaneous log 

containing at a minimum, the following record keeping for each day, or part of a day that PF1.015 and/or S2.018

are operating: 

(a) The calendar date of any required monitoring. 

(b) The total daily throughput rate of soda ash, in tons, for the corresponding date. 

(c) The total daily hours of operation for the corresponding date. 

(d) The corresponding average hourly throughput rate of soda ash, in tons per hour. The average hourly 

throughput rate will be determined from the daily throughput rate and the total daily hours of operation 

recorded in (b) and (c) above. 

5. NAC 445B.3405 (445B.316) Part 70 Program

Shielded Requirements

No shielded provisions are established for these emission units. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-81

Section VI. Specific Operating Conditions (continued) 

W. Emission Units # S2.019 and #PF1.016. UTM: North 4,059.35 km, East 711.68 km (Zone 11). 

System 19 – Unit #4 FGD Backup Quicklime Storage and Feed System 

S2.019 Loading of Unit #4 FGD Backup Quicklime Storage & Feed System (W-05), manufactured by Portec, 

model #850-QL-92. 

PF1.016 Unloading of Unit #4 FGD Backup Quicklime Storage & Feed System (W-05), manufactured by Portec, 

model #850-QL-92. 

1. NAC 445B.3405 (445B.316) Part 70 Program

Air Pollution Equipment

a. Emissions from S2.019 shall be ducted to fabric filter with 100% capture efficiency installed on S2.019. 

b. Control system for PF1.016 consisting of best operational practices to ensure compliance with the emission limits 

stated below. 

2. NAC 445B.3405 (445B.316) Part 70 Program

Emission Limits

On and after the date of startup of S2.019 and PF1.016, the Permittee will not discharge or cause the discharge into 

the atmosphere the following pollutants in excess of the following specified limits: 

a. SIP 445.732 Federally Enforceable SIP Requirement - The discharge of PM to the atmosphere from S2.019 and 

PF1.016 each, will not exceed 3.20 pounds per hour. 

b. NAC 445B.22033 State-Only Requirement - The discharge of PM10 to the atmosphere from S2.019 and PF1.016 

each, will not exceed 3.20 pounds per hour. 

c. NAC 445B.305 Part 70 Program - The discharge of PM (particulate matter) and PM10 (particulate matter less 

than 10 microns in diameter) to the atmosphere from S2.019 and PF1.016 combined will not exceed 0.0021 

pound per hour nor more than 0.009 ton per year. 

d. SIP 445.721 Federally Enforceable SIP Requirement - Unless otherwise provided in SIP 445.721 inclusive, no 

owner or operator may cause or permit the discharge into the atmosphere from any stationary source of any air 

contaminant for a period or periods aggregating more than 3 minutes in any 1 hour which is of an opacity equal 

to or greater than 20 percent. 

e. NAC 445B.22017 (State Only Requirement) - The opacity from the discharges of S2.019 and PF1.016 each, to 

the atmosphere will not equal or exceed 20%. 

3. NAC 445B.3405 (445B.316) Part 70 Program

Operating Parameters

a. Maximum allowable throughput of quicklime in S2.019 will not exceed 0.69 ton per hour. 

b. Maximum allowable throughput of quicklime in PF1.016 will not exceed 0.69 ton per hour. 

c. Hours

S2.019 and PF1.016 each may operate 8,760 hours per calendar year. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-82

Section VI. Specific Operating Conditions (continued) 

W. Emission Units # S2.019 and #PF1.016 (continued) 

4. NAC 445B.3405 (445B.316) Part 70 Program

Monitoring, Recordkeeping, Compliance and Reporting

a. Monitoring, Record keeping and Compliance 

The Permittee, upon issuance of this operating permit will: 

i. Monitor and record the throughput of quicklime for PF1.016 and S2.019 each on a daily basis. 

ii. Monitor and record the hours of operation for PF1.016 and S2.019 each on a daily basis. 

iii. The required monitoring established in (i.) through (ii.) above, will be maintained in a contemporaneous log 

containing at a minimum, the following record keeping for each day, or part of a day that PF1.016 and/or 

S2.019 are operating: 

(a) The calendar date of any required monitoring. 

(b) The total daily throughput rate of quicklime, in tons, for the corresponding date. 

(c) The total daily hours of operation for the corresponding date. 

(d) The corresponding average hourly throughput rate of quicklime, in tons per hour. The average hourly 

throughput rate will be determined from the daily throughput rate and the total daily hours of operation 

recorded in (b) and (c) above. 

b. Reporting 

i. Federally Enforceable PSD Permit Requirement (PSD Permit Issued 1/3/80) – The following reporting 

requirement applies only to Section VIII of the PSD Permit issued 1/3/80: 

The Regional Administrator (USEPA) shall be notified by telephone (by The Permitee) within 48 hours 

following any failure of air pollution control equipment, process equipment, or of a process to operate in a 

normal manner which results an increase in emissions above any allowable emissions limit stated in Section 

VIII of the USEPA-issued PSD permit dated January 3, 1980 of these conditions. In addition the Regional 

Administrator shall be notified in writing within fifteen (15) days of any such failure. This notification shall 

include a description of the malfunctioning equipment or abnormal operation, the date of the initial failure, the 

period of time over which emissions were increased due to failure, the cause of the failure, the estimated 

resultant emissions in excess of those allowed under Section VIII of these conditions, and the methods 

utilized to restore normal operations. Compliance with this malfunction notification provision shall not excuse 

or otherwise constitute a defense to any violations of this permit or of any law or regulations, which such 

malfunction, may cause. 

5. NAC 445B.3405 (445B.316) Part 70 Program

Shielded Requirements

No shielded provisions are established for these emission units. 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-83

Section VI. Specific Operating Conditions (continued) 

X. Emission Units # S2.020 and PF1.017. UTM: North 4,059.35 km, East 711.68 km (Zone 11).

System 20 – Unit #4 FGD Lime Storage Silo 

S2.020 Loading of Unit #4 FGD Lime Storage Silo (W-06), manufactured by Portec, serial #T-406-1-A. 

PF1.017 Unloading of Unit #4 FGD Lime Storage Silo (W-06), manufactured by Portec, serial #T-406-1-A. 

1. NAC 445B.3405 (445B.316) Part 70 Program

Air Pollution Equipment

a. Emissions from S2.020 shall be ducted to fabric filter with 100% capture efficiency installed on S2.020.

b. Control system for PF1.017 consisting of best operational practices to ensure compliance with the emission limits 

stated below. 

2. NAC 445B.3405 (445B.316) Part 70 Program

Emission Limits

On and after the date of startup of S2.020 and PF1.017, the Permittee will not discharge or cause the discharge into 

the atmosphere the following pollutants in excess of the following specified limits: 

a. SIP 445.732 Federally Enforceable SIP Requirement - The discharge of PM to the atmosphere from S2.020 and 

PF1.017 each, will not exceed 3.20 pounds per hour. 

b. NAC 445B.22033 State-Only Requirement - The discharge of PM10 to the atmosphere from S2.020 and PF1.017 

each, will not exceed 3.20 pounds per hour. 

c. NAC 445B.305 Part 70 Program - The discharge of PM (particulate matter) and PM10 (particulate matter less 

than 10 microns in diameter) to the atmosphere from S S2.020 and PF1.017 combined will not exceed 0.02 

pound per hour nor more than 0.03 ton per year. 

d. SIP 445.721 Federally Enforceable SIP Requirement - Unless otherwise provided in SIP 445.721 inclusive, no 

owner or operator may cause or permit the discharge into the atmosphere from any stationary source of any air 

contaminant for a period or periods aggregating more than 3 minutes in any 1 hour which is of an opacity equal 

to or greater than 20 percent. 

e. NAC 445B.22017 (State Only Requirement) - The opacity from the discharges of S2.020 and PF1.017 each to 

the atmosphere will not equal or exceed 20%. 

3. NAC 445B.3405 (445B.316) Part 70 Program

Operating Parameters

a. Maximum allowable throughput of lime in S2.020 will not exceed 0.69 ton per hour. 

b. Maximum allowable throughput of lime in PF1.017 will not exceed 0.69 ton per hour. 

c. Hours

S2.020 and PF1.017 each may operate 8,760 hours per calendar year.
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VI-84

Section VI. Specific Operating Conditions (continued) 

X. Emission Units #S2.020 and #PF1.017 (continued) 

4. NAC 445B.3405 (445B.316) Part 70 Program

Monitoring, Record keeping, Compliance and Reporting

a. Monitoring, Recordkeeping and Compliance 

The Permittee, upon issuance of this operating permit will: 

i. Monitor and record the throughput of lime for PF1.017 and S2.020 each on a daily basis. 

ii. Monitor and record the hours of operation for PF1.017 and S2.020 each on a daily basis. 

iii. The required monitoring established in (i.) through (ii.) above, will be maintained in a contemporaneous log 

containing at a minimum, the following record keeping for each day, or part of a day that PF1.017 and/or 

S2.020 are operating: 

(a) The calendar date of any required monitoring. 

(b) The total daily throughput rate of lime, in tons, for the corresponding date. 

(c) The total daily hours of operation for the corresponding date. 

(d) The corresponding average hourly throughput rate of lime, in tons per hour. The average hourly 

throughput rate will be determined from the daily throughput rate and the total daily hours of operation 

recorded in (b) and (c) above. 

b. Reporting 

i. Federally Enforceable PSD Permit Requirement (PSD Permit Issued 1/3/80) – The following reporting 

requirement applies only to Section VIII of the PSD Permit issued 1/3/80: 

The Regional Administrator (USEPA) shall be notified by telephone (by The Permitee) within 48 hours 

following any failure of air pollution control equipment, process equipment, or of a process to operate in a 

normal manner which results an increase in emissions above any allowable emissions limit stated in Section 

VIII of the USEPA-issued PSD permit dated January 3, 1980 of these conditions. In addition the Regional 

Administrator shall be notified in writing within fifteen (15) days of any such failure. This notification shall 

include a description of the malfunctioning equipment or abnormal operation, the date of the initial failure, the 

period of time over which emissions were increased due to failure, the cause of the failure, the estimated 

resultant emissions in excess of those allowed under Section VIII of these conditions, and the methods 

utilized to restore normal operations. Compliance with this malfunction notification provision shall not excuse 

or otherwise constitute a defense to any violations of this permit or of any law or regulations, which such 

malfunction, may cause. 

5. NAC 445B.3405 (445B.316) Part 70 Program

Shielded Requirements

No shielded provisions are established for these emission units. 

************End of Specific Operating Conditions************** 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VII-1

Section VII. Emission Caps

A. No Emission Caps Defined 

************End of Emission Caps Conditions**************
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

VIII-1

Section VIII. Surface Area Disturbance Conditions

A. NAC 445B.22035 

Fugitive Dust

1. The Permittee may not cause or permit the handling, transporting, or storing of any material in a manner that allows 

or may allow controllable particulate matter to become airborne. 

2. Except as otherwise provided in subsection 4, the Permittee may not cause or permit the construction, repair, 

demolition, or use of unpaved or untreated areas without first putting into effect an ongoing program using the best 

practical methods to prevent particulate matter from becoming airborne. As used in this subsection, “best practical 

methods” includes, but is not limited to, paving, chemical stabilization, watering, phased construction, and revegetation. 

3. Except as provided in subsection 4, the Permittee may not disturb or cover 5 acres or more of land or its topsoil until 

the Permittee has obtained an Operating Permit for surface area disturbance to clear, excavate, or level the land or 

to deposit any foreign material to fill or cover the land. 

4. The provisions of subsections 2 and 3 do not apply to: 

a. Agricultural activities occurring on agricultural land; or 

b. Surface disturbances authorized by a permit issued pursuant to NRS 519A.180 which occur on land which is 

not less than 5 acres or more than 20 acres. 

B. NAC 445B.305 Federally Enforceable PSD Permit Requirement (PSD Permit Issued 1/3/80)

Fugitive Dust Air Pollution Control Equipment (PSD Permit Requirements, Section VIII. Special Conditions A.5. and A.7.) 

1. The Permittee shall install and continuously operate and maintain the following air pollution controls: 

a. General Access Roads - All general access roads to the plant shall be paved. 

b. Facility Roads - All roads between facilities shall be surfaced with gravel and treated with dust control chemicals. 

c. Active Coal Storage Piles - All active coal storage piles shall be controlled with a wet suppression system using 

surfactants. 

d. Inactive Coal Storage Piles - All inactive coal storage piles shall be controlled by compaction and chemical 

treatment if necessary. 

************End of Surface Area Disturbance Conditions**************
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

IX-1

Section IX. Schedules of Compliance

A. NDEP’s Order: 

Pursuant to Order dated April 3, 2007, NPC is required to install gas igniters on Units 1-4 at Reid Gardner no later than 

July 1, 2009, and install baghouses on Units 1-3 at Reid Gardner no later than July 1, 2010 [re: NDEP-BAPC’s letter 

dated September 12, 2007, Reid Gardner Generating Station Permit Reopening]. NPC is required to comply with 

following requirements as listed in the Order: 

1. Igniter Installation Project: NPC shall replace the fuel oil igniters for Units 1-4 by installing natural gas igniters in 

Units 1-4; replace the Burner Management System for Units 1-4 as necessary to operate natural gas igniters; 

construct a natural gas pipeline connecting the Facility to the Kern River Natural Gas Pipeline; and undertake any 

other modifications at the Facility necessary to operate natural gas igniters in Units 1-4. 

NPC shall complete construction of the Igniter Installation Project required herein no later than July 1, 2009. On or 

after July 1, 2009, NPC shall not use oil for start-up or flame stabilization of any EGU at the Facility. 

2. Installation and Operation of Baghouses: NPC shall complete construction and begin operation of three separate 

baghouses at the Facility, for Units 1, 2, and 3, respectively. The completion of construction and commencement of 

operation of all of the baghouses shall occur on or before July 1, 2010. 

If construction of any one of the three baghouses has not been completed on or before July 1, 2010, NPC may shut 

down and cease operation of any one of the Units not operating a Baghouse at the Facility. 

If NPC does not receive approval from the Public Utilities Commission of Nevada (PUCN) for the installation and 

operation of the Baghouses for Units 1-3, NPC may decommission Units 1-3. If NPC chooses to decommission 

Units 1-3 due to disapproval of the Baghouse installation and/or operation, NPC shall provide written notice to the 

NDEP-BAPC that it intends to decommission Units 1-3 no later than November 30, 2007, or within one year of the 

PUCN decision on 

NPC’s Integrated Resource Plan, whichever is sooner; and, NPC shall shut down and permanently cease operation 

of Units 1-3 on or before November 30, 2008. 

3. Monitoring, Recordkeeping and Reporting. NPC shall comply with the monitoring, recordkeeping, and reporting 

requirements set forth in the Facility Operating Permit. 

B. Consent Decree Requirements: 

Reid Gardner Consent Decree was agreed to between the NPC, NDEP-BAPC and the United States Environmental 

Protection Agency on April 3, 2007, which was entered by the United States District Court on June 14, 2007. NPC is 

required to comply with following requirements as listed in the Consent Decree: 

1. Igniter Installation Project: NPC shall replace the fuel oil igniters for Units1-4 at the Facility by installing natural gas 

igniters in Units1-4; replace the Burner Management System for Units 1-4 as necessary to operate natural gas 

igniters; construct a natural gas pipeline connecting the Facility to the Kern River Natural Gas Pipeline; and 

undertake any other modifications at the Facility necessary to operate natural gas igniters in Units 1-4. 

NPC shall complete construction of the Igniter Installation Project required by this Paragraph no later than twentyfour months (24) after the Effective Date of this Decree. Beginning twenty-four (24) months after the Effective Dated 

of this Decree NPC shall not use oil for start up or flames stabilization of any EGU at the facility.” 
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

IX-2

Section IX. Schedules of Compliance (continued)

2. Installation and Operation of Baghouses: By no later than thirty-six (36) months after the Effective Date of this 

Decree NPC shall complete construction and begin operating three separate Baghouses at the Facility, for Units 1, 2, 

and 3 respectively. 

If construction of any one of the three Baghouses is not completed by within thirty-six (36) months after the Effective 

Date of this Decree NPC may, in its discretion, shut down and cease the operation of any one of the Units not 

operating a Baghouse at the Facility. NPC may, at its discretion, recommence operation of a Unit shutdown pursuant 

to this paragraph, provided that construction of a baghouse for the Unit is complete and the baghouse is operational. 

If NPC does not receive approval from the PUCN for the installation and operation of the Baghouses for Units 1-3 in 

its Integrated Resource Plan, NPC may, in its sole discretion, choose to decommission Units 1-3. If NPC chooses to 

decommission Units 1-3 pursuant to this Paragraph, the following shall apply: 

i. NPC shall notify the EPA and NDEP in writing, pursuant to Section XVI (Notices), that it intends to decommission 

Units 1-3 no later than November 30, 2007, or within one year of the PUCN decision on NPC’s Integrated 

Resource Plan, whichever is sooner; and 

ii. NPC shall shut down and permanently cease operation of Units 1-3 on or before November 30, 2008.” 

3. Monitoring, Recordkeeping and Reporting. NPC shall comply with the monitoring, recordkeeping, and reporting 

requirements set forth in the Operating Permit. 

4. SO2 Limitations and Operating Permit Modification

a. Beginning on the Effective Date of the Decree, measured separately, Units 1, 2 and 3 shall not have SO2

emissions in excess of 0.40 LB/MMBtu, based on a 10-day rolling average period. 

b. Compliance with the SO2 emission limitations in this Paragraph shall be demonstrated with SO2 CEMS and the 

procedures established in the appropriate section of NPC’s Operating Permit. 

c. In accord with Section XII (Permits), NPC shall modify its Operating Permit to include the SO2 emissions 

limitations required by this Paragraph. 

*********End of Schedules of Compliance**************
STATE OF NEVADA 

BUREAU OF AIR POLLUTION CONTROL

Facility ID NO. A0379 Permit NO. AP4911-0897

CLASS I AIR QUALITY OPERATING PERMIT

 SPECIFIC REQUIREMENTS

Issued to: Nevada Power Company—Reid Gardner Station Power Plant, as Permittee

Section X. Amendments

A. June 18, 2007 – Permittee’s Minor Revision Application requesting installation of Rotating Opposed Fired Air (ROFA) 

combustion system on Steam Boiler Unit #4 (B-04) to reduce NOx emissions [refer to Minor Revision Application 

received on March 19, 2007; additional submittals dated April 19, 2007; and subsequent emails dated April 28 and 30, 

2007]. 

B. March 17, 2008 – Permit revisions are made pursuant to a State-issued order and a Consent Decree entered between 

NPC, NDEP-BAPC and the United States Environmental Protection Agency on April 3, 2007, which was entered by the 

United States District Court on June 14, 2007. 

C. December 19, 2008 – Permit revision made for S2.004 – Pursuant to 40 CFR 76.7, Revised NOx Emission Limitations 

for Group 1, Phase II Boilers, the NOx emission limit for calendar years 2008 and 2009 revised to read 0.46 lb/MMBtu. 

This permit: 

1. Is non-transferable. (NAC 445B.287) Part 70 Program

2. Will be posted conspicuously at or near the stationary source. (NAC 445B.318)(State Only Requirement)

3. Will expire and be subject to renewal five (5) years from April 22, 2004 . (NAC 445B.315) Part 70 Program

4. A completed application for renewal of an operating permit must be submitted to the director on the form 

provided by him with the appropriate fee at least 180 calendar days before the expiration date of this operating 

permit. (NAC 445B.323.2) Part 70 Program

5. Any party aggrieved by the Department’s decision to issue this permit may appeal to the State Environmental 

Commission (SEC) within ten days after the date of notice of the Department’s action. (NRS 445B.340)(State 

Only Requirement)

THIS PERMIT EXPIRES ON: April 22, 2009 

Signature

Issued by: Matthew A. DeBurle, P.E. 

Supervisor, Class I Permitting Branch 

Bureau of Air Pollution Control 

Phone: (775) 687-9391 Date: December 19, 2008 

X-1 
Class I Non-Permit Equipment List 

Appended to #AP4911-0897 

The Bureau of Air Pollution Control, Nevada Division of Environmental Protection only has air pollution 

regulatory authority over the fossil fuel fired boilers and supporting equipment at this facility. All other 

emission units fall under the purview of the Clark County, Department of Air Quality Management. 

Unit #1&2 Emergency Diesel Generator (#G-01) Make = Detroit Williams 

HP = 335 HP 

KW = 250 KW 

Fuel = Diesel 

Hours of Operation = < 100 Hours 

Unit #3 Emergency Diesel Generator (#G-02) Make = Waukesha 

HP = 168 HP 

KW = 125 

Fuel = Diesel 

Hours of Operation = < 100 Hours 

Unit #4 Emergency Diesel Generator (#G-03) Make = Waukesha 

HP = 335 HP 

KW = 250 KW 

Fuel = Diesel 

Hours of Operation = < 100 Hours 

Units 1-3 Coal Yard A/G Diesel Tank (#T-01) 10,000 gallons. 1985 

Unit #4 Coal Yard A/G Diesel Tank (#T-02) 10,000 gallons. 1985 

(2) Site Motor Vehicle Diesel Tanks (#T-04) 500 gallons. 1985