AUTHORITY TO CONSTRUCT
 

ISSUED PURSUANT TO
 

PREVENTION OF SIGNIFICANT DETERIORATION (PSD)
 

REQUIREMENTS AT 40 CFR 52.21
 

PSD PERMIT NUMBER: SE 07-02
 

U.S. EVIRONMENTAL PROTECTION AGENCY, REGION IX 

PERMITTEE: City of Victorville 

FACILITY LOCATION: Victorville, San Bernardino County, CA 

This Permit is issued pursuant to the Prevention of Significant Deterioration (PSD) requirements of 

the Clean Air Act, as amended, 42 U.S.c. §§ 7401 - 7671, et seq. City of Victorville is granted 

approval to construct the hybrid solar and combined cycle natural gas-fired power plant, as 

described herein, in accordance with the permit application (and plans submitted with the permit 

application), federal regulations governing the Prevention of Significant Deterioration of air quality 

(40 CFR § 52.21), and other terms and conditions set forth in this PSD Permit. 

Failure to comply with any condition or term set forth in this PSD Permit is subject to 

enforcement action pursuant to Section 113 of the Clean Air Act. 

This PSD Permit does not relieve the Permittee from the responsibility to comply with any other 

applicable provisions of the Clean Air Act (including 40 CFR Parts 51, 52, 60, 61, 63, and 72 

through 75), other federal, or Mojave Desert Air Quality Management District requirements. 

This PSD Permit becomes effective immediately on the date of issuance pursuant to 40 CFR § 

124.15(b)(3). 

-------+tt:f)~!At; r11VL/ De~Jordan / Date 

Director, Air DivisIOn 

Vic/orville 2 (SE 07-02) Final PSD Permit
 

March 2UIU
 
2 

Victorville 2 (SE 07-02) Final PSD Permit 

March 2010 

VICTORVILLE 2 HYBRID POWER PROJECT (SE 07-02)

PREVENTION OF SIGNIFICANT DETERIORATION PERMIT 

FINAL PERMIT CONDITIONS 

PROJECT DESCRIPTION 

The proposed facility is a combined-cycle power plant capable of generating up to 563 megawatts 

(MW, nominal) of net power. Electrical power will be generated from the combustion of natural gas 

in two 154 MW combustion turbine generators (CTG). Exhaust from each gas turbine will flow 

through a dedicated Heat Recovery Steam Generator (HRSG) to produce steam to power a shared 

267 MW Steam Turbine Generator (STG). Each HRSG will be equipped with natural gas-fired duct 

burners to augment steam production during peaking operation. The facility will include a field of 

parabolic trough solar collectors to produce additional high pressure steam for the HRSG. Solar 

thermal energy can displace up to 50 MW of duct burning, with the same total overall capacity. 

The facility is subject to the Prevention of Significant Deterioration (PSD) Program for emissions of 

Carbon Monoxide (CO), Nitrogen Dioxide (NO2), Particulate Matter (PM), and Particulate Matter 

under 2.5 micrometers (μm) in diameter (PM2.5). 

The following devices are subject to this PSD permit: 

Device ID Description 

D1 

• 154 MW Combustion Turbine Generator (CTG) 

• Natural gas-fired GE 7FA Rapid Start Process 

• Vented to a dedicated Heat Recovery Steam Generator (HRSG) and a 267 MW 

Steam Turbine Generator (STG) shared with D2 

• Emissions of NO2 and CO controlled by Selective Catalytic Reduction (SCR) 

and an Oxidation Catalyst (Ox-Cat) 

D2 

• 154 MW Combustion Turbine Generator (CTG) 

• Natural gas-fired GE 7FA Rapid Start Process 

• Vented to a dedicated HRSG and a 267 MW STG shared with D1 

• Emissions of NO2 and CO controlled by SCR and an Ox-Cat 

D3 • 424.3 MMBtu/hr (HHV) Duct Burner for D1, fired on natural gas 

D4 • 424.3 MMBtu/hr (HHV) Duct Burner for D2, fired on natural gas 

D5 • 40 MMBtu/hr (HHV) Auxiliary Heater with ultra low-NOx burner 

D6 • 35 MMBtu/hr (HHV) Auxiliary Boiler with ultra low-NOx burner 

D7 • 2000 KW (2,683 hp) Internal Combustion (IC) Diesel-fired Emergency Engine 

D8 • 135 KW (182 hp) IC Diesel-fired Emergency Firewater Pump Engine 

D9 • 130,000 gallons per minute (maximum circulation rate) Cooling Tower 
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Victorville 2 (SE 07-02) Final PSD Permit 

March 2010 

I. PERMIT EXPIRATION

As provided in 40 CFR 52.21(r), this PSD Permit shall become invalid if construction: 

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

approval takes effect; or 

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

C. is not completed within a reasonable time. 

II. PERMIT NOTIFICATION REQUIREMENTS

Permittee shall notify EPA Region 9 in writing or by electronic mail of the: 

A. date construction is commenced, postmarked within 30 days of such date. 

B. actual date of initial startup, as defined in 40 CFR 60.2, postmarked within 15 days 

of such date. 

C. date upon which initial performance tests will commence, in accordance with the 

provisions of Condition IX.H, postmarked not less than 30 days prior to such date. 

Notification may be provided with the submittal of the performance test protocol 

required pursuant to Condition IX.H. 

D. date upon which initial performance evaluation of the CEMS will commence in 

accordance with 40 CFR 60.13(c), postmarked not less than 30 days prior to such 

date. Notification may be provided with the submittal of the CEMS performance test 

protocol required pursuant to Condition IX.G 

III. FACILITY OPERATION 

At all times, including periods of startup, shutdown, shakedown, and malfunction, 

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

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

control practice for minimizing emissions. Determination of whether acceptable 

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

available to the EPA which may include, but is not limited to, monitoring results, opacity 

observations, review of operating maintenance procedures and inspection of the source. 
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Victorville 2 (SE 07-02) Final PSD Permit 

March 2010 

IV. MALFUNCTION REPORTING

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

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

equipment, or of a process to operate in a normal manner, which results in an 

increase in emissions above the allowable emission limits stated in Section IX of 

this permit. 

B. In addition, Permittee shall provide an additional notification to EPA in writing or 

electronic mail within fifteen (15) days of any such failure described under 

Condition IV.A. This notification shall include a description of the 

malfunctioning equipment or abnormal operation, the date of the initial 

malfunction, the period of time over which emissions were increased due to the 

failure, the cause of the failure, the estimated resultant emissions in excess of 

those allowed in Section IX, and the methods utilized to mitigate emissions and 

restore normal operations. 

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

otherwise constitute a defense to any violation of this permit or any law or 

regulation such malfunction may cause. 

V. RIGHT OF ENTRY

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

presentation of credentials, shall be permitted: 

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

to be kept under the terms and conditions of this PSD Permit; 

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

to be kept under the terms and conditions of this PSD Permit; 

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

PSD Permit; and 

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

VI. TRANSFER OF OWNERSHIP

In the event of any changes in control or ownership of the facilities to be constructed, this 

PSD Permit shall be binding on all subsequent owners and operators. Permittee shall 

notify the succeeding owner and operator of the existence of this PSD Permit and its 
5 

Victorville 2 (SE 07-02) Final PSD Permit 

March 2010 

conditions by letter, a copy of which shall be forwarded to EPA Region IX. 

VII. SEVERABILITY

The provisions of this PSD Permit are severable, and, if any provision of the PSD Permit 

is held invalid, the remainder of this PSD Permit shall not be affected. 

VIII. ADHERENCE TO APPLICATION AND COMPLIANCE WITH OTHER 

ENVIRONMENTAL LAWS

Permittee shall construct this project in compliance with this PSD permit, the application 

on which this permit is based, the Terms and Conditions of the final Biological Opinion 

issued on January 23, 2008 pursuant to the Section 7 Consultation with the U.S. Fish and 

Wildlife Service, and all other applicable federal, state, and local air quality regulations, 

including, but not limited to, the Standards of Performance for New Stationary Sources 

(40 CFR Part 60) Subparts A, Dc, KKKK, and IIII of this regulation. This PSD permit 

does not release the Permittee from any liability for compliance with other applicable 

federal, state and local environmental laws and regulations, including the Clean Air Act. 

IX. SPECIAL CONDITIONS 

 A. Annual Facility Emission Limits 

Annual emissions, in tons per year (tpy) on a 12-month rolling average basis, shall 

not exceed the following: 

NOx CO PM PM2.5

Total Facility 108.4 tpy 254.2 tpy 124.5 tpy 120.9 tpy 

B. Air Pollution Control Equipment and Operation 

On or before the date of initial start-up of the power plant (as defined in 40 C.F.R. 

60.2), and thereafter, except as noted below in section IX.D., the Permittee shall 

install, continuously operate, and maintain Selective Catalytic Reduction (SCR) 

systems for control of NOx and oxidation catalysts for control of CO for Units D1 

and D2. Permittee shall also perform any necessary operations to minimize 
6 

Victorville 2 (SE 07-02) Final PSD Permit 

March 2010 

emissions so that emissions are at or below the emission limits specified in this 

permit. 

 

C. Combustion Turbine Generator Emission Limits 

1. Except as noted below under Condition IX.D, on and after the date of initial 

start-up, Permittee shall not discharge or cause the discharge of emissions 

from each combustion turbine generator (CTG) unit (D1 and D2) into the 

atmosphere in excess of the following: 

Emission Limit (per CTG) 

(no duct burning) 

Emission Limit (per CTG) 

(with duct burning) 

NO2

• 11.55 lb/hr 

• 1-hr average 

• 2.0 ppmvd @ 15% O2

• 14.6 lb/hr 

• 1-hr average 

• 2.0 ppmvd @ 15% O2

CO 

• 7.65 lb/hr 

• 1-hr average 

• 2.0 ppmvd @ 15% O2

• 13.35 lb/hr 

• 1-hr average 

• 3.0 ppmvd @ 15% O2

PM and PM2.5

• 12.0 lb/hr 

• 12-month rolling average 

• PUC-quality natural gas 

• Sulfur content of no greater 

than 0.2 grains per 100 dscf 

• 18.0 lb/hr 

• 12-month rolling average 

• PUC-quality natural gas 

• Sulfur content of no greater 

than 0.2 grains per 100 dscf 

2. Combined hours of operation for both duct burners (D3 and D4) shall not 

exceed 2000 hours per 12-month rolling average. The Permittee shall ensure 

that the duct burners are not operated unless the associated turbine units are in 

operation. 

 D. Requirements during Gas Turbine (D1 and D2) Startup and Shutdown 

1. Startup is defined as the period beginning with ignition and lasting until either 

the equipment complies with all operating permit limits for two consecutive 

15-minute averaging periods or the maximum time allowed for the event after 

ignition, whichever occurs first. 

a. A cold startup means a startup when the CTG has not been in operation 
7 

Victorville 2 (SE 07-02) Final PSD Permit 

March 2010 

during the preceding 48 hours. 

b. Warm and hot start-ups include all startups that are not a cold startup. 

c. Shutdown is defined as the period beginning with the lowering of 

equipment from normal operating load and lasting until fuel flow is 

completely off and combustion has ceased. 

2. During startup and shutdown periods emissions from each CTG and 

associated HRSG unit, verified by the Continuous Emissions Monitoring 

System (CEMS), shall not exceed the following: 

NOx CO Duration Annual Event 

Limit 

Cold Startup 52.4 lb/hr 

96 lb/event 

224 lb/hr 

410 lb/event 1.8 hr/event 50 events/yr 

Warm and Hot 

Startup 

30 lb/hr 

40 lb/event 

247 lb/hr 

329 lb/event 1.3 hr/event 260 events/yr 

Shutdown 114 lb/hr 

57 lb/event 

674 lb/hr 

337 lb/event 0.5 hr/event 310 events/yr 

3. The Permittee must operate the CEMS during startups and shutdowns. 

4. The Permittee must record the time, date, and duration of each startup and 

shutdown event. The records must include calculations of NOx and CO 

emissions during each event based on the CEMS data. These records must be 

kept for five years following the date of such event. 

5. The SCR system, including ammonia injection, shall be operated as soon as 

the SCR reaches an operating temperature of 550 degrees Fahrenheit. 

E. Auxiliary Combustion Equipment Emission Limits 

At all times, including equipment startup and shutdown, Permittee shall not 

discharge or cause the discharge of emissions from each unit into the atmosphere 

in excess of the following: 
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Victorville 2 (SE 07-02) Final PSD Permit 

March 2010 

NOx CO PM and PM2.5

Restrictions on 

Usage 

Unit D5 

40 MMBtu/hr 

(HHV) Heater 

• 9 ppmvd @ 

3% O2

• 1-hr average 

• 50 ppmvd @ 

3% O2

• 1-hr average 

• 0.2 grains per 100 

dscf 

• PUC-quality 

natural gas 

• 1000 hr/yr 

Unit D6 

35 MMBtu /hr 

(HHV) Boiler 

• 500 hr/yr 

Unit D7 

2000 KW (2,683 

hp) engine 

• 6.0 g/KW-hr, 

(4.5 g/hp-hr)1

• 3.5 g/KW-hr, 

(2.6 g/hp-hr) 

• 0.20 g/KW-hr, 

(0.15 g/hp-hr ) 

• Use of ultra-low 

sulfur fuel, not to 

exceed 15 ppmvd 

fuel sulfur 

• 50 hr/yr 

Unit D8 

135 KW (182 hp) 

firewater pump 

• 3.8 g/KW-hr, 

(2.8 g/hp-hr)2

• As required 

for fire safety 

testing 

• Not to exceed 

50 hr/yr 

Unit D9 

130,000 gpm 

Cooling Tower 

n/a n/a • 1.6 lb/hr (as total 

PM) 

• < 0.0005% drift 

• < 5000 ppm total 

dissolved solids 

n/a 

 F. Cooling Tower Emission Limits

1. The cooling tower drift rate shall not exceed 0.0005% with a maximum 

circulation rate of 130,000 gallons per minute (gpm). The maximum total 

dissolved solids (TDS) shall not exceed 5000 ppm. 

2. The maximum hourly total PM emission rate from the cooling tower and the 

evaporative condenser combined shall not exceed 1.6 lb/hr. 

 G. Continuous Emissions Monitoring System (CEMS) for Units D1 and D2 

 

1

 Emission standards for NOx in the New Source Performance Standard for stationary compression ignition internal 

combustion engines (40 CFR Part 60 Subpart IIII) and the California Tier Emission Standards are based on the sum 

of NOx and non-methane hydrocarbons (NMHC). For the NOx emission limits, the applicant assumes NMHC + NOx

emissions from the engine are 95% NOx. 
9 

Victorville 2 (SE 07-02) Final PSD Permit 

March 2010 

1. At the earliest feasible opportunity before beginning commercial operation, in 

accordance with the recommendations of the equipment manufacturer and the 

construction contractor, Permittee shall install, and thereafter operate, 

maintain, certify, and quality-assure a continuous emission monitoring system 

(CEMS) for each combustion turbine generator that measures stack gas NOx , 

CO, and O2 concentrations in ppmv. The concentrations shall be corrected to 

15% O2 on a dry basis. 

2. The NOx and O2 CEMS shall meet the applicable requirements of 40 CFR Part 

60 Appendix B, Performance Specifications 2 and 3, and 40 CFR Part 60 

Appendix F, Procedure 1. Alternatively, the NOx CEMS shall meet the 

installation and certification requirements of 40 CFR Part 75. 

3. The CO CEMS shall meet the applicable requirements of 40 CFR Part 60 

Appendix B, Performance Specification 4, and 40 CFR Part 60 Appendix F, 

Procedure 1, except the relative accuracy specified in section 13.2 of 40 CFR 

Part 60 Appendix B, Performance Specification 4 shall not exceed 20 percent. 

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

analyzing, and data recording) for each successive 15-minute clock-hour 

period. 

5. The CEMS shall be certified and tested in accordance with Condition IX.G.7. 

6. The performance evaluation of the CEMS may either be conducted separately, 

as specified in 40 CFR 60.334(b)(1), or as part of the initial performance test 

of each emission unit. CEMS must undergo and pass initial performance 

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

7. CEMS shall meet the requirements of 40 CFR 60.13. Data sampling, 

analyzing, and recording shall also be adequate to demonstrate compliance 

with emission limits during startup and shutdown. 

8. Not less than 90 days prior to the date of initial startup of the Facility, the 

Permittee shall submit to the EPA a quality assurance project plan for the 

certification and operation of the continuous emission monitors. Such a plan 

shall conform to EPA requirements contained in 40 CFR 60, Appendix F for 

CO, NOx, and O2, and 40 CFR 75 Appendix B for stack flow. The plan shall 

be updated and resubmitted upon request by EPA. The protocol shall specify 

how emissions during startups and shutdowns will be determined and 

calculated, including quantifying flow accurately if calculations are used. 
10 

Victorville 2 (SE 07-02) Final PSD Permit 

March 2010 

9. The gas turbine CEMS shall be tested annually and quarterly in accordance 

with the requirements of 40 CFR Part 60 Appendix F, Procedure 1. Permittee 

shall perform a full stack traverse during initial run of annual RATA testing of 

the CEMS, with testing points selected according to 40 CFR Part 60 Appendix 

A, Method 1. 

10. Permittee shall submit a CEMS performance test protocol to the EPA no later 

than 30 days prior to the test date to allow review of the test plan and to 

arrange for an observer to be present at the test. The performance test shall be 

conducted in accordance with the submitted protocol, and any changes 

required by EPA. 

11. Permittee shall furnish the EPA a written report of the results of performance 

tests within 60 days of completion. 

12. The stack gas volumetric flow rates shall be calculated in accordance with the 

fuel flowmeter requirements of 40 CFR Part 75 Appendix D in combination 

with the appropriate parts of EPA Method 19. 

13. Prior to the date of initial start-up Permittee shall install, and thereafter 

maintain and operate, continuous monitoring and recording systems to 

measure and record the following operational parameters: 

a. The ammonia injection rate of the ammonia injection system of the 

SCR system. 

b. Exhaust gas temperature at the inlet to the SCR reactor 

 H. Performance Tests

1. Stack Tests 

a. Within 60 days after achieving normal operation, but not later than 180 

days after the initial start-up of equipment, and annually thereafter (within 

30 days of the initial performance test anniversary), Permittee shall 

conduct performance tests (as described in 40 CFR 60.8) as follows: 

i. NOx, CO, PM, and PM2.5 emissions from each gas turbine (Units 

D1/D3 and D2/D4), 
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Victorville 2 (SE 07-02) Final PSD Permit 

March 2010 

ii. NOx, CO, PM, and PM2.5 emissions the 40 MMBtu/hr heater (D5), the 

35 MMBtu/hr boiler (D6), 

iii. NOx, CO, PM, and PM2.5 emissions from the 2000 KW (2,683 hp) 

internal combustion engine (D7). 

iv. NOx, CO, PM, and PM2.5 emissions from the 135 KW/hr firewater 

pump (D8) upon notification by EPA 

v. PM emissions from the cooling tower (D9). 

b. The annual performance tests shall be conducted in accordance with the 

requirements of 40 CFR Part 60, Appendix F, Procedure 1, Section 5.11. 

c. Permittee shall submit a performance test protocol to EPA no later than 30 

days prior to the test to allow review of the test plan and to arrange for an 

observer to be present at the test. The performance test shall be conducted 

in accordance with the submitted protocol, and any changes required by 

EPA. 

d. Performance tests shall be conducted in accordance with the test methods 

set forth in 40 CFR 60.8 and 40 CFR Appendix A, as modified below. In 

lieu of the specified test methods, equivalent methods may be used with 

prior written approval from EPA: 

i. EPA Methods 1-4 and 7E for NOx emissions measured in ppmvd, 

ii. EPA Methods 1-4, 7E, and 19 for NOx emissions measured on a heat 

input basis, 

iii. EPA Methods 1-4 and 10 for CO emissions, 

iv. EPA Methods 5 and 202 for both PM and PM2.5, in accordance with 

the test methods set forth in 40 CFR § 60.8 and 40 CFR Part 60, 

Appendix A. In lieu of Method 202, the Permittee may use EPA 

Conditional Test Methods for particulate matter: CTM-039 or CTM040. If Method 202 is used, the test methodology must include: 

a. one hour nitrogen purge 

b. the alternative procedure described in section 8.1 to neutralize the 

sulfuric acid 

c. evaporation of the last 1 ml of the inorganic fraction by air drying 

following evaporation of the bulk of the impinger water in a 105 oC 
12 

Victorville 2 (SE 07-02) Final PSD Permit 

March 2010 

oven as described in the first sentence of section 5.3.2.3. 

v. Modified Method 306 or the Cooling Tower Institute’s heated bead 

test method for PM emissions from the cooling tower, and 

vi. the provisions of 40 CFR Part 60.8 (f). 

e. The initial performance test conducted after initial startup shall use the test 

procedures for a ‘high NO2 emission site,’ as specified in San Diego Test 

Method 100, to measure NO2 emissions. The source shall be classified as 

either a 'low' or 'high' NO2 emission site based on these test results. If the

emission source is classified as a: 

i. ‘high NO2 emission site,’ then each subsequent performance test shall 

use the test procedures for a ‘high NO2 emission site,’ as specified in 

San Diego Test Method 100. 

ii. ‘low NO2 emission site,’ then the test procedures for a ‘high NO2

emission site,’ as specified in San Diego Test Method 100, shall be 

performed once every five years to verify the source's classification as 

a 'low NO2 emission site.' 

f. The performance test methods specified in Condition X.F.3., may be 

modified as follows: 

i. Perform a minimum of 9 reference method runs, with a minimum time 

per run of 21 minutes, at a single load level, between 90 and 100 

percent of peak (or the highest physically achievable) load. 

ii. Use the test data both to demonstrate compliance with the applicable 

NOx emission limit and to provide the required reference method data 

for the RATA of the CEMS. 

g. Upon written request and adequate justification from the Permittee, EPA 

may waive a specific annual test and/or allow for testing to be done at less 

than maximum operating capacity. 

h. For performance test purposes, sampling ports, platforms, and access shall 

be provided on the emission unit exhaust system in accordance with the 

requirements of 40 CFR 60.8(e). 
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Victorville 2 (SE 07-02) Final PSD Permit 

March 2010 

i. Permittee shall furnish the EPA a written report of the results of 

performance tests within 60 days of completion. 

2. Cooling Tower Total Dissolved Solids Testing 

a. Permittee shall perform weekly tests of the blow-down water quality using 

a EPA approved method. The operator shall maintain a log that contains 

the date and result of each blow-down water quality test, and the resulting 

mass emission rate. This log shall be maintained on site for a minimum of 

five years and shall be provided to EPA and District personnel on request. 

b. Permittee shall calculate PM and PM2.5 emission rate using an EPAapproved calculation based on the TDS and water circulation rate. 

c. The operator shall conduct all required cooling tower water quality tests in 

accordance with an EPA-approved test and emissions calculation protocol. 

Thirty (30) days prior to the first such test the operator shall provide a 

written test and emissions calculation protocol for EPA review and 

approval, with a copy to the District as specified in Condition XI below. 

d. A maintenance procedure shall be established that states how often and 

what procedures will be used to ensure the integrity of the drift 

eliminators, to ensure that the TDS limits are not exceeded, and to ensure 

compliance with recirculation rates. This procedure is to be kept onsite and 

available to EPA and District personnel on request. The permittee shall 

promptly report any deviations from this procedure.

3. Fuel Testing 

a. Permittee shall take monthly samples of the natural gas combusted. The 

samples shall be analyzed for sulfur content using an ASTM method. The 

sulfur content test results shall be retained on site pursuant to Special 

Conditions IX.C and IX.E for Units D1 – D6. 

I. Monitoring for Auxiliary Combustion Equipment 

1. Permittee shall install and maintain an operational non-resettable totalizing 

mass or volumetric flow meter in each fuel line for the 40 MMBtu/hr heater 

(Unit D5) and the 35 MMBtu /hr boiler (Unit D6). 

2. Permittee shall install and maintain an operational non-resettable elapsed time 

meter for the 40 MMBtu/hr heater (Unit D5), the 35 MMBtu /hr boiler (Unit 

D6), the 2000 KW emergency use engine (Unit D7) and the 135 KW 
14 

Victorville 2 (SE 07-02) Final PSD Permit 

March 2010 

emergency-use firewater pump (Unit D8). 

 J. Recordkeeping and Reporting 

1. Permittee shall maintain a file of all records, data, measurements, reports, and 

documents related to the operation of the Facility, including, but not limited 

to, the following: all records or reports pertaining to adjustments and/or 

maintenance performed on any system or device at the Facility; all records 

relating to performance tests and monitoring of auxiliary combustion 

equipment; for each diesel fuel oil delivery, documents from the fuel supplier 

certifying compliance with the fuel sulfur content limit of Special Condition 

IX.E for Units D7 and D8; and all other information required by this permit 

recorded in a permanent form suitable for inspection. The file must be 

retained for not less than five years following the date of such measurements, 

maintenance, reports, and/or records. 

2. Permittee shall maintain CEMS records that contain the following: the 

occurrence and duration of any startup, shutdown, shakedown, or malfunction, 

performance testing, evaluations, calibrations, checks, adjustments, 

maintenance, duration of any periods during which a continuous monitoring 

system or monitoring device is inoperative, and corresponding emission 

measurements. 

3. Permittee shall maintain records of all source tests and monitoring and 

compliance information required by this permit. 

4. Permittee shall maintain records and submit a written report of all excess 

emissions to EPA semi-annually. The report is due on the 30th day following 

the end of the calendar quarter and shall include the following: 

a. Time intervals, data and magnitude of the excess emissions, the nature 

and cause (if known), corrective actions taken and preventive measures 

adopted; 

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

inoperative (monitor down-time), except for zero and span checks, and 

the nature of CEMS repairs or adjustments; and 

c. A negative declaration when no excess emissions occurred or when the 

CEMS has not been inoperative, repaired, or adjusted. 
15 

Victorville 2 (SE 07-02) Final PSD Permit 

March 2010 

d. Any failure to conduct any required sources testing, monitoring, or 

other compliance activities. 

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

restrictions on hours of operation. 

5. Excess emissions shall be defined as any period in which the facility 

emissions exceed the maximum emission limits set forth in this permit. 

6. A period of monitor down-time shall be any unit operating clock hour in 

which sufficient data are not obtained to validate the hour for NOx, CO or O2. 

7. Excess emissions indicated by the CEM system, source testing, or compliance 

monitoring shall be considered violations of the applicable emission limit for 

the purpose of this permit. 

8. All records required by this PSD Permit shall be retained for not less than five 

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

K. Shakedown Periods 

The combustion turbine emission limits and requirements in Sections IX.C, IX.D, 

and IX.E shall not apply during combustion shakedown periods. Shakedown is 

defined as the period beginning with initial startup and ending no later than initial 

performance testing, during which the Permittee conducts operational and 

contractual testing and tuning to ensure the safe, efficient and reliable operation of 

the plant. The requirement of section III of this permit shall apply at all times. 
16 

Victorville 2 (SE 07-02) Final PSD Permit 

March 2010 

X. ACROYNMS AND ABBREVIATIONS 

APCD Air Pollution Control District 

ASTM American Society for Testing and Materials 

BTU British Thermal Unit 

CEMS Continuous Emissions Monitoring System 

CFR Code of Federal Regulations 

CO Carbon Monoxide 

CTG Combustion Turbine Generator 

CTM Conditional Test Method 

District Mojave Desert Air Pollution Control District 

(d)scf (dry) Standard Cubic Feet 

EPA Environmental Protection Agency 

g grams 

gr grains 

HHV Higher Heating Value 

HRSG Heat Recovery Steam Generator 

hp Horsepower 

hr Hour 

KW Kilowatt 

lbs Pounds 

MMBtu Million British Thermal Units 

MW Megawatt 

NO2 Nitrogen Dioxide 

NOx Oxides of Nitrogen 

NSPS New Source Performance Standards 

O2 Oxygen 

PM Total Particulate Matter 

PM2.5 Particulate Matter with aerodynamic diameter less than 2.5 micrometers 

PM10 Particulate Matter with aerodynamic diameter less than 10 micrometers 

ppmvd Parts Per Million by Volume, Dry basis 

ppmv Parts Per Million by Volume 

PSD Prevention of Significant Deterioration 

PUC Public Utilities Commission 

RATA Relative Accuracy Test Audit 

SCR Selective Catalytic Reduction 

SO2 Sulfur Dioxide 

SOx Oxides of Sulfur 

STG Steam Turbine Generator 

TDS Total Dissolved Solids 

tpy Tons Per Year 

yr Year 
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Victorville 2 (SE 07-02) Final PSD Permit 

March 2010 

XI. AGENCY NOTIFICATIONS

 All correspondence as required by this Approval to Construct must be forwarded to: 

A. Director, Air Division (Attn: AIR-5) 

 EPA Region IX 

 75 Hawthorne Street 

 San Francisco, CA 94105-3901 

 Email: R9.AEO@epa.gov 

 Fax: (415) 947-3579 

B. Air Pollution Control Officer 

 Mojave Desert Air Quality Management District 

 14306 Park Avenue 

 Victorville, CA 92392-2310