Section_J_-_21_MAR_03_-_Title_V_Permit_70550_Redacted.pdf

Virginia Title V Operating Permit

Until such time as this permit is reopened and revised, modified, revoked, terminated or expires, the permittee is authorized to operate in accordance with the terms and conditions contained herein. This permit is issued under the authority of Title 10.1, Chapter 13, §10.1-1322 of the Air Pollution Control Law of Virginia. This permit is issued consistent with the Administrative Process Act, and 9 VAC 5-80-50 through 9 VAC 5-80-300 of the State Air Pollution Control Board Regulations for the Control and Abatement of Air Pollution of the Commonwealth of Virginia.

Authorization to operate a Stationary Source of Air Pollution as described in this permit is hereby granted to:

Permittee Name:

Facility Name:

Facility Location:

Registration Number:

Permit Number:

U.S. Army Garrison, Fort Belvoir

U.S. Army Garrison, Fort Belvoir 9820 Flagler Road, STE 230 Fort Belvoir, Virginia 22060-5928

70550

NVRO70550

March 21, 2003 Effective Date

March 21, 2008 Expiration Date

Robert G. Burnley Director, Department of Environmental Quality

Signature Date

Table of Contents, 2 pages Permit Conditions, 67 pages

U.S. Army Garrison, Fort Belvoir Permit Number: NVRO70050

Table of Contents

I. FACILITY INFORMATION

II. EMISSION UNITS

III. CENTRAL HEATING PLANT REQUIREMENTS – (EMISSION UNIT ID#B-1A, B-2A, B-3A)

A. LIMITATIONS

B. MONITORING AND RECORDKEEPING

C. TESTING

D. REPORTING

IV. R&D HEATING PLANT REQUIREMENTS – (EMISSION UNITS ID#B-4,B-5)

A. LIMITATIONS

B. MONITORING AND RECORDKEEPING

C. TESTING

V. R&D HEATING PLANT SUMMER BOILER REQUIREMENTS – (EMISSION UNIT ID#B-107) .. 17

A. LIMITATIONS

B. MONITORING AND RECORDKEEPING

C. TESTING

D. REPORTING

VI. OTHER OIL-FIRED BOILERS REQUIREMENTS – (EMISSION UNITS ID#B27-B115)

A. LIMITATIONS

B. MONITORING AND RECORDKEEPING

VII. GENERATORS – (EMISSION UNIT ID#EG13-22, EG70-EG73)

A. LIMITATIONS

B. MONITORING AND RECORDKEEPING

C. TESTING

D. REPORTING

VIII. SCHOOL GENERATORS – (EMISSION UNITS ID# G51-G57, G61-G64)

A. LIMITATIONS

B. MONITORING AND RECORDKEEPING

C. TESTING

IX. OTHER GENERATOR REQUIREMENTS – (EMISSION UNITS ID#EG38-EG43, EG66-EG69) . 35

A. LIMITATIONS

B. MONITORING AND RECORDKEEPING

X. FIREFIGHTING TRAINING EQUIPMENT – (EMISSION UNITS ID#FT-1, FT-2)

A. LIMITATIONS

B. MONITORING AND RECORDKEEPING

C. TESTING

XI. VETERINARY CLINIC INCINERATOR – (EMISSION UNIT ID#I-2)

A. LIMITATIONS

B. MONITORING AND RECORDKEEPING

C. TESTING

D. REPORTING

Permit Number: NVRO70050

XII. INCINERATOR – (EMISSION UNIT ID#I-4)

A. LIMITATIONS

B. MONITORING AND RECORDKEEPING

C. TESTING

D. REPORTING

XIII. COLD SOLVENT CLEANING DEGREASERS – (EMISSION UNIT ID#DG)

A. LIMITATIONS

B. MONITORING

C. RECORDKEEPING

XIV. STORAGE TANKS – (EMISSION UNITS ID#T- ) 27 NSPS (NON-GASOLINE) TANKS

A. LIMITATIONS

B. RECORDKEEPING

XV. GASOLINE SERVICE STATION AT BUILDING – (EMISSION UNITS ID#T-9,T-10)

A. LIMITATIONS

XVI. FACILITY WIDE CONDITIONS

A. LIMITATIONS

XVII. INSIGNIFICANT EMISSION UNITS

XVIII. PERMIT SHIELD & INAPPLICABLE REQUIREMENTS

XIX. GENERAL CONDITIONS

A. FEDERAL ENFORCEABILITY

B. PERMIT EXPIRATION

C. RECORDKEEPING AND REPORTING

D. ANNUAL COMPLIANCE CERTIFICATION

E. PERMIT DEVIATION REPORTING

F. FAILURE/MALFUNCTION REPORTING

G. SEVERABILITY

H. DUTY TO COMPLY

I. NEED TO HALT OR REDUCE ACTIVITY NOT A DEFENSE

J. PERMIT ACTION FOR CAUSE

K. PROPERTY RIGHTS

L. DUTY TO SUBMIT INFORMATION

M. DUTY TO PAY PERMIT FEES

N. FUGITIVE DUST EMISSION STANDARDS

O. STARTUP, SHUTDOWN, AND MALFUNCTION

P. ALTERNATIVE OPERATING SCENARIOS

Q. INSPECTION AND ENTRY REQUIREMENTS

R. REOPENING FOR CAUSE

S. PERMIT AVAILABILITY

T. TRANSFER OF PERMITS

U. MALFUNCTION AS AN AFFIRMATIVE DEFENSE

V. PERMIT REVOCATION OR TERMINATION FOR CAUSE

W. DUTY TO SUPPLEMENT OR CORRECT APPLICATION

X. STRATOSPHERIC OZONE PROTECTION

Y. ACCIDENTAL RELEASE PREVENTION

Z. CHANGES TO PERMITS FOR EMISSIONS TRADING

AA. EMISSIONS TRADING

BB. GENERAL CONFORMITY REQUIREMENTS

Registration Number: 70550 March 21, 2003

I. Facility Information

Permittee U.S. Army Garrison, Fort Belvoir 9820 Flagler Road, STE230 Fort Belvoir, Virginia 22060-5928

Responsible Official Colonel Thomas W. Williams Garrison Commander

Facility U.S. Army Garrison, Fort Belvoir DIS-PWE, 9430 Jackson Loop, STE107 Fort Belvoir, Virginia 22060-5130

Contact Person Mr. Patrick M. McLaughlin Environmental and Natural Resources Directorate

(703) 806-4007

AIRS Identification Number: 51-059-00018

Facility Description: SIC Code [9711] – [National Security]

U.S. Army Garrison Fort Belvoir is a military post covering 9,237 acres in Fairfax County.

Nearly 24,000 people live and work at Fort Belvoir. There are approximately 100 tenant organizations which employ about 18,000 people. The post also has a residential population of about 6,000 military personnel and family members. There are various activities in support of the tenants and the civilian staff, which are subject to the Virginia air regulations.

There are four boilers with air permits, about 45 boilers subject to existing source rule and 70 others are exempt. There are about 60 diesel engine generators used mostly for emergency power. Air permits were issued for 14 generators at and 10 generators used for training at the School. A few other generators are subject to existing source rule but the rest are small and considered insignificant. Other permitted equipment include a 120 lbs/hour veterinary clinic incinerator and 1050 lbs/hour capacity classified waste incinerator at . At the Davison Army Airfield, there are two firefighting trainer devices with permits to produce controlled fires using propane. The post has other operations with minor emissions that are subject to the regulations, including cold solvent cleaning and fuel storage tanks. Only 10 tanks are subject to the air regulations, with 90 other tanks considered exempt. Six loading racks, including use for gasoline transfer, are exempt since the operation does not qualify as a bulk gasoline terminal. Also, just one of three gasoline service stations are included in the permit, since the others are not only restricted to military personnel, but rather military families and retirees can use them. Other minor sources, including 10 oil-water separators, closed landfills, minor pesticide use, spray painting, printing and woodworking operations, are considered insignificant.

March 21, 2003

II. Emission Units

Equipment to be operated consists of:

Emission Unit ID

Stack

ID

Bldg.

No. Emission Unit Description Size/Rated

Capacity*

Pollution Control Device (PCD)

Description PCD ID Pollutant

Controlled Applicable Permit

Date

Fuel Burning Equipment – Building – Central Heating Plant B-1a, B-2a, B-3a

BS-1a, BS-2a, BS-3a

Replacement boilers, gas/No.

2 oil, at Central Heating Plant, Cleaver Brooks CB-LE-200

25.0 mil.Btu/hr, each

Low NOx emissions control technology

N/A (built-

in) NOx 9/21/98, as amended 1/24/01

Fuel Burning Equipment – Building – R&D Heating Plant B-4, B-5

BS-4,

BS-5

Erie City Iron Works HSB No.2 oil/gas

32.2 mil.Btu/hr, each - - - -

B-107 BS107 Cleaver Brooks CB400 No. 2/gas-fired boilers 16.75 mil.Btu/hr - - - 11/4/98, as amended 1/24/01 Fuel Burning Equipment – Other small No. 2 Oil or No. 2 Oil/Gas-Fired Boilers B-6, B-7

BS-6,

BS-7

Trane PBAL 3F-5 No. 2/gas-fired boilers

11 mil.Btu/hr, each - - - -

B-55 BS-55 Weil McLain BL 786 SF 1.7 mil.Btu/hr - - - - B-56 BS-56 Weil McLain 588, gas/No. 2 oil 1.36 mil. Btu/hr B-59 BS-59 Weil McLain 688 1.57 mil.Btu/hr - - - - B-65 BS-65 Cleaver Brooks, gas/No. 2 oil 2.9 mil.Btu/hr - - - - B-66 BS-66 Cleaver Brooks, gas/No. 2 oil 2.9 mil.Btu/hr - - - - B-67 BS-67 Cl. Brooks CBW, gas/No. 2 oil 6.28 mil.Btu/hr - - - - B-68 BS-68 Cl. Brooks CBW, gas/No. 2 oil 6.28 mil.Btu/hr - - - - B-71 BS-71 Iron Fireman R10.9 2.41 mil.Btu/hr - - - - B-84 BS-84 Weil McLain 1188 3.39 mil.Btu/hr - - - - B-88 BS-88 Weil McLain 1.08 mil.Btu/hr - - - - B-95 BS-95 Bryan CL 1.8 mil.Btu/hr - - - - B-96 BS-96 Cleaver Brooks M4S-4500 4.5 mil.Btu/hr - - - - B-97 BS-97 Cleaver Brooks M4S-4500 4.5 mil.Btu/hr - - - - B-98 BS-98 Cleaver Brooks M4W-1500 1.5 mil.Btu/hr - - - - B-99 BS-99 PBI Industries 1.6 mil.Btu/hr - - - - B-100 BS-100 Cleaver Brooks 6000 6 mil.Btu/hr - - - - B-101 BS-101 Cleaver Brooks 6000 6 mil.Btu/hr - - - - B-103 BS-103 Cl. Brooks FLE, gas/No. 2 oil 4 mil.Btu/hr - - - -

March 21, 2003

B-104 BS-104 Cl. Brooks FLE, gas/No. 2 oil 4 mil.Btu/hr - - - - B-105 BS-105 Cleaver Brooks CB-600-125 5.23 mil.Btu/hr - - - - B-108 BS-108 Cl.Brooks CB500, gas/No.2 oil 4.18 mil.Btu/hr - - - - B-109 BS-109 Weil McLain P688W, gas/No.2 1.7 mil.Btu/hr - - - - B-111 BS-111 Cl. Brooks CB800, gas/No.2 1.68 mil.Btu/hr - - - - B-112 BS-112 Peerless 0-707-FBA-WUP 1.07 mil.Btu/hr - - - - B-135 BS-135 Cleaver Brooks CB-M4W 2.5 mil.Btu/hr - - - - B-136 BS-136 Cleaver Brooks CB-M4W 2.5 mil.Btu/hr - - - - Process A – Generators

EG-13,

EG-14,

EG-15,

EG-16,

EG-17,

EG-18,

EG-19,

EG-20,

EG-21

EG-22

EGS-13,

EGS-14,

EGS-15,

EGS-16,

EGS-17,

EGS-18,

EGS-19,

EGS-20,

EGS-21,

EGS-22,

Caterpillar 3516 diesel-fired emergency generators at

1500 kilowatts (KW), each or 2168 brake horsepower (bhp), each

- - - 7/1/02

EG-29 EGS-29 Diesel generator,Cummins VT 500 KW - - - -

EG-38,

EG-39,

EG-40

EGS-38,

EGS-39,

EGS-40

Diesel generators 1000 KW, each - - - -

EG-41 EGS-41 Diesel generator, Cat. SR-4 1500 KW - - - -

EG-42

EG-43

EGS-42

EGS-43

No. 2 fuel oil generators KTA50-GS/GC1 750 KW, each - - - -

EG-66

EG-67

EG-68

EG-69

EGS66

EGS67

EGS68

EGS69

Diesel generators, Caterpillar SR-4 Emergency diesel generators

800 KW, each - - - 7/1/02

EG-70

EG-71

EG-72

EG-73

EGS70

EGS71

EGS72

EGS73

Caterpillar model 3516B (or equivalent) emergency diesel generators

1640 KW, each or 2377 bhp, each

EG-107 EGS107 Diesel Generator, All-Power About 600 KW - - - - G-51, G-52, G-53, G-54

GS-51,

GS-52,

GS-53,

GS-54

Four EMD MP-36A Diesel generators for training

1500 KW, each or 2170 bhp, each

- - - 5/31/02

March 21, 2003

G-55, G-56, G-57

GS-55,

GS-56,

GS-57

Diesel generators for training, Two Cummins MEP-208A and One Cummins MEP-012A

750 KW, each or 1085 bhp, each

G-61 GS-61 EMD model 12567E diesel gen. 750 KW - - - - G-62, G-63, G-64

GS-62,

GS-63,

GS-64

Three Caterpillar 3456 Diesel generators for training

920 KW, each or 1338 bhp, each

- - - 5/31/02

Process B – Firefighting Training Equipment

FT-1 Symtron Systems, Inc. Fixed Structural fire fighting trainer

36 mil.Btu/hr (propane-fired) - - - 1/24/01

FT-2 Symtron Systems, Inc. Mobile aircraft fire rescue trainer

11.7 mil. Btu/hr (propane-fired) - - - 1/24/01

Process C – Incinerators

I-2 IS-2 Shenandoah P25-2GT Veterinary clinic incinerator 120 lbs/hour - - - 4/16/90, amended

11/4/98

I-4 IS-4 Consumat C-325-ATC Classified waste incinerator 1050 lbs/hour - - - 2/8/89

Process D – Cold Cleaning (Degreasers) DG (41) cold cleaning degreasers - - - - Process E – Storage Tanks T-03162A T-03612B Underground storage tanks 13,000 gallons, each - - - -

T-01133E Underground storage tank 25,000 gallons - - - 5/31/02 T-02856B Underground storage tank 15,000 gallons - - - 7/1/02 T-00332H T-00332I T-00332J

Underground storage tanks 25,000 gallons, each - - - -

T-01422J T-01422K T-01422L T-01422M T-01422N

Underground storage tanks (residual No. 6 fuel oil)

25,000 gallons, each - - - -

T-01422P T-01422Q T-01422R T-01422S T-01422T

Underground storage tanks (distillate No. 2 fuel oil)

25,000 gallons, each - - - -

T-03138H T-03138I Underground storage tanks 30,000 gallons, each - - - -

March 21, 2003

T-02117C Underground storage tank 25,000 gallons - - - - T-02800A Underground storage tank 25,000 gallons - - - - T-02310A Underground storage tank 25,000 gallons - - - - T-02444C Underground storage tank 25,000 gallons - - - - T-02462A Underground storage tank 25,000 gallons - - - - T-02803A Underground storage tank 25,000 gallons - - - - T-02117C Underground storage tank 25,000 gallons - - - - T-02800A Underground storage tank 25,000 gallons - - - - T-01124C Underground storage tanks 12,000 gallons - - - -

Process F – Building - Gasoline Service Station T-9, T-10

Stage I and Stage II vapor recovery from gasoline station - - - -

*The Size/Rated capacity [and PCD efficiency] is provided for informational purposes only, and is not an applicable requirement.

U.S. Army, Fort Belvoir

March 21, 2003

III. Fuel Burning Equipment Requirements- (emission units ID#B-1a, B-2a and B-3a) - Building - Central Heating Plant

A. Limitations

1. Emissions of nitrogen oxides (NOx) from each of boilers B-1a, B-2a, and B-3a shall be controlled by a low NOx emission control technology. NOx emissions from each boiler shall not exceed 0.05 lbs/106 Btu during the firing of natural gas, and 0.14 lbs/106 Btu during the firing of distillate oil. Each boiler shall be provided with adequate access for inspection.

(9 VAC 5-80-110 and Condition 3 of 9/21/98 Permit, as amended on 1/24/2001)

2. The approved fuels for boilers B-1a, B-2a, and B-3a are natural gas and distillate oil. Distillate oil is defined as fuel oil that meets the specifications for fuel oil numbers 1 or 2 under the American Society for Testing and Materials. A change in the fuels may require a permit to modify and operate.

(9 VAC 5-80-110 and Condition 14 of 9/21/98 Permit, as amended on 1/24/2001)

3. Sulfur dioxide (SO2) emissions from boilers B-1a, B-2a, and B-3a shall be controlled by burning natural gas or distillate oil with maximum sulfur content not to exceed 0.5 weight percent per shipment.

(9 VAC 5-80-110 and Conditions 4 and 15 of 9/21/98 Permit, as amended on 1/24/2001)

4. Total suspended particulate (TSP), particulate matter less than 10 microns in diameter (PM10), carbon monoxide (CO), and volatile organic compound (VOC) emissions from boilers B-1a, B-2a, and B-3a shall be controlled by firing clean burning fuels, as stipulated in Condition III.A.2, and by maintaining good combustion.

(9 VAC 5-80-110 and Condition 5 of 9/21/98 Permit, as amended on 1/24/2001)

5. Boilers B-1a, B-2a, and B-3a shall consume no more than 501 x 106 cubic feet of natural gas, and 941,230 gallons of distillate oil per year, calculated monthly as the sum of each consecutive 12-month period. These values represent the combined total allowable throughput for all three boilers located at Building .

(9 VAC 5-80-110 and Condition 6 of 9/21/98 Permit, as amended on 1/24/2001)

6. Emissions resulting from the operation of each boiler, B-1a, B-2a and B-3a, shall not exceed the limits specified below:

Total Suspended 0.024 lbs/106 Btu (9 VAC 5-50-260) Particulate

March 21, 2003

PM-10 0.024 lbs/106 Btu (9 VAC 5-50-260)

Sulfur Dioxide 0.52 lbs/106 Btu (9 VAC 5-50-260)

Nitrogen Oxides 0.05 lbs/106 Btu (gas firing) (9 VAC 5-50-260) (as NO2) 0.14 lbs/106 Btu (No. 2 oil firing) (9 VAC 5-50-260)

Carbon Monoxide 0.098 lbs/106 Btu (9 VAC 5-50-260)

Volatile Organic 0.03 lbs/106 Btu (9 VAC 5-50-260) Compounds

(9 VAC 5-80-110 and Condition 8 of 9/21/98 Permit, as amended on 1/24/2001)

7. Emissions from the combined operation of boilers B-1a, B-2a, and B-3a shall not exceed the limits specified below:

Total Suspended 2.1lbs/hr 4.1 tons/yr (9 VAC 5-50-260) Particulate

PM-10 2.1lbs/hr 4.1 tons/yr (9 VAC 5-50-260)

Sulfur Dioxide 45.6 lbs/hr 33.5 tons/yr (9 VAC 5-50-260)

Nitrogen Oxides 12.4 lbs/hr 22.0 tons/yr (9 VAC 5-50-260) (as NO2)

Carbon Monoxide 8.6 lbs/hr 25.6 tons/yr (9 VAC 5-50-260)

Volatile Organic 2.7 lbs/hr 6.1 tons/yr (9 VAC 5-50-260) Compounds

Records of DEQ-approved emission factors, equations and throughput data shall be maintained to calculate annual emissions for each consecutive 12 month period.

(9 VAC 5-80-110 and Condition 9 of 9/21/98 Permit, as amended on 1/24/2001)

8. Visible emissions from the boiler B-1a stack, the boiler B-2a stack, and the boiler B-3a stack shall not exceed twenty percent (20%) opacity except during one six-minute period in any one hour in which visible emissions shall not exceed thirty percent (30%) opacity. This condition applies at all times except during start-up, shutdown, or malfunction.

(9 VAC 5-80-110 and Condition 10 of 9/21/98 Permit, as amended on 1/24/2001)

March 21, 2003

9. Boiler B-1a, B-2a, and B-3a emissions shall be controlled by proper operation and maintenance. Boiler operators shall be trained in the proper operation of all such equipment. Training shall consist of a review and familiarization of the manufacturer's operating instructions, at minimum.

(9 VAC 5-80-110 and Condition 16 of 9/21/98 Permit, as amended on 1/24/2001)

B. Monitoring and Recordkeeping

1. The permittee shall obtain a certification from the fuel supplier with each shipment of distillate oil. Each fuel supplier certification shall include the following:

a. The name of the fuel supplier,

b. The date on which the oil was received,

c. The volume of distillate oil delivered in the shipment,

d. A statement that the oil complies with the American Society for Testing and Materials specifications for fuel oil numbers 1 and 2, and

e. The sulfur content of the oil.

(9 VAC 5-80-110 and Condition 15 of 9/21/98 Permit, as amended on 1/24/2001)

2. The permittee shall maintain records of all emission data and operating parameters necessary to demonstrate compliance with this permit. The content and format of such records shall be arranged with the Air Compliance Manager, Northern Virginia Regional Office. These records shall include, but are not limited to:

a. The monthly throughput of natural gas and the daily and monthly throughput of distillate oil for boilers B-1a, B-2a, and B-3a. The annual throughput shall be calculated as the sum of each consecutive twelve (12) month period.

b. All fuel supplier certifications.

c. DEQ-approved emission factors and equations used to calculate emissions from the boilers.

These records shall be available on site for inspection by the DEQ and shall be current for the most recent five (5) years.

(9 VAC 5-80-110, Condition 18 of 9/21/98 Permit, as amended on 1/24/2001 and 40 CFR Part 60 Subpart Dc)

March 21, 2003

3. The permittee shall maintain records of the required training including a statement of time, place and nature of training provided. The permittee shall have available good written operating procedures and a maintenance schedule for the boiler. These procedures shall be based on the manufacturer's recommendations, at minimum. A record of completed service and maintenance work shall be maintained on file for the most recent five year period. All records required by this condition shall be kept on site and made available for inspection by the DEQ.

(9 VAC 5-80-110 and Condition 16 of 9/21/98 Permit, as amended on 1/24/2001)

4. Visible emission observations shall be used by the permittee to assist in determining whether the emission units are operating properly. Each boiler, B- 1a, B-2a, and B-3a, shall be observed during each calendar week it operates for normal visible emissions exhaust from the stack, excluding condensed water vapor. The results of the observations shall be recorded and records kept on site, available for review and be current for the most recent five years.

(9 VAC 5-80-110)

5. Whenever any emission unit appears to be exceeding the normal visible emissions, the permittee shall check the emission unit operating parameters, and if the parameters are not within normal range, then

a. Corrective action shall be taken to return the emission unit to proper operation.

b. The visible emission observation shall be repeated to confirm proper operation.

c. A record of observations and the corrective actions shall be retained on site, available for review and be current for the most recent five years.

(9 VAC 5-80-110)

6. If initial corrective action does not appear to adequately reduce visible emissions, then a visible emissions evaluation shall be conducted by certified personnel for at least 60 minutes in accordance with EPA Reference Method 9 (40 CFR Part 60, Appendix A) to demonstrate compliance with the opacity limit. If exceedance of the opacity limit is determined by the evaluation, then the permittee shall proceed as following:

a. Remove the emission unit from service and make necessary repairs and adjustments to bring the operation into compliance with the permit limit.

b. Document the maintenance and repairs performed on the unit.

March 21, 2003

c. Repeat the visible emissions evaluation to demonstrate compliance with the opacity limit before the emission unit is returned to service.

d. In the event that the emission unit still cannot meet the opacity standard in the permit, appropriate action will be agreed upon and implemented by U.S. Army Fort Belvoir and DEQ before the emission unit can be returned to service.

The results of the visible emissions evaluation for the emission unit(s) shall be available on site for inspection by the DEQ and be current for the most recent five years.

(9 VAC 5-80-110)

C. Testing

1. The permitted facility shall be constructed so as to allow for emissions testing at any time using appropriate methods. Test ports will be provided at the appropriate locations.

(9 VAC 5-80-110 and Condition 13 of 9/21/98 Permit, as amended on 1/24/2001)

2. When testing is conducted in addition to the monitoring specified in this permit, the permittee shall use the following methods in accordance with procedures approved by the DEQ as follows:

Pollutant Test Method (40 CFR Part 60, Appendix A)

VOC EPA Methods 18, 25, 25a NOx EPA Method 7, 7E SO2 EPA Method 6, 6C CO EPA Method 10

PM/PM-10 EPA Method 5, 17, 201a Visible Emissions EPA Method 9

(9 VAC 5-80-110)

D. Reporting

1. The permittee shall submit fuel quality reports to the Air Compliance Manager, Northern Virginia Regional Office within 30 days after the end of each semi-annual period. If no shipments of distillate oil were received during the semi-annual period, the semi-annual report shall consist of the dates included in the semi-annual period and a statement that no oil was received during the semi-annual period. If distillate oil was received during the semi-annual period, the reports shall include:

March 21, 2003

a. The dates included in the semi-annual period,

b. A copy of all fuel supplier certifications for all shipments of distillate oil received during the semi-annual period or a semi-annual summary from each fuel supplier that includes the information specified in Condition III.B.1 for each shipment of distillate oil, and

c. A signed statement from the owner or operator of the facility that the fuel supplier certifications or summaries of fuel supplier certifications represent all of the distillate oil burned or received at the facility.

(9 VAC 5-80-110, Condition 19 of 9/21/98 Permit, as amended on 1/24/2001, as amended on 1/24/2001 and 40 CFR Part 60 Subpart Dc)

IV. Fuel Burning Equipment Requirements – (emission units ID# B-4, B-5) Building – R&D Heating Plant – (Existing Larger Boilers)

A. Limitations

1. Emissions from the operation of each of the two Erie City Iron Works boilers (B-4, B-5) shall not exceed the limits specified below:

Total Suspended Particulate/PM-10 0.3 lbs/106 Btu (9 VAC 5-40-900 A. 2.)

Sulfur Dioxide 1.06 lbs/106 Btu (9 VAC 5-40-930 A. 2.)

(9 VAC 5-80-110)

2. Visible emissions from each of the boiler stacks shall not exceed twenty percent opacity, except for one six-minute period in any one hour of not more than sixty percent opacity. Failure to meet the requirements of this condition because of the presence of water vapor shall not be a violation of this condition.

(9 VAC 5-40-940)

3. No owner or other person shall cause or permit to be discharged from any affected facility any nitrogen oxide emissions in excess of that resultant from using reasonably available control technology (RACT).

(9 VAC 5-40-310 and 9 VAC 5-80-110)

March 21, 2003

B. Monitoring and Recordkeeping

1. For the two Erie City Iron Works boilers, application of reasonably available control technology (RACT) for NOX emissions shall be the performance of an evaluation and adjustment of the combustion process at least semi-annually as to appropriately minimize the formation of NOX emissions. The evaluation and adjustment shall utilize a combustion analyzer and include, at a minimum, the following:

a. Development of a plan providing the schedule and procedure for the semi-annual evaluation and adjustment. The plan shall be approved by DEQ and updated as necessary.

b. Check condition of stack, clean, and perform minor repairs as necessary.

c. Inspect, clean, and adjust each oil burner nozzle assembly and conduct operational test of the boiler. Check automatic combustion control devices for proper operation. Perform adjustments and minor repairs as necessary to ensure efficient operation while minimizing all types of emissions to the air.

For each unit, compliance with applicable portions of 9 VAC 5 Chapter 40, Article 8 (Emission Standards for Fuel Burning Equipment) and consistent CO and NOX concentrations among the semi-annual (or more frequent) evaluations shall be considered sufficient to demonstrate compliance with the portion of this condition requiring minimizing all types of emissions to the air, unless credible evidence to the contrary is presented.

d. Documentation of each evaluation and adjustment conducted on the combustion process. This documentation shall include, at a minimum: (a) the date of the evaluation and adjustment; (b) identity of service company and technicians; and, (c) final NOX, CO, and excess oxygen emission rates and the type of combustion analyzer used to determine these emissions.

(9 VAC 5-80-110 and Condition 3 of 5/16/2000 Permit)

2. Each of the boilers shall be operated and maintained in accordance with the manufacturer’s specifications and good air pollution control practices. A copy of all relevant operation, maintenance, and specification documentation as provided by the manufacturer for each unit and device shall be maintained on the premises of the facility. Each unit shall be operated and maintained in adherence with this documentation to the degree appropriate and practicable with the intention of minimizing NOX emissions.

(9 VAC 5-80-110 and Condition 4 of 5/16/2000 Permit)

3. For each boiler, a record of each fuel shipment, including certified fuel type, quantity, sulfur content and nitrogen content as provided by the supplier shall be

March 21, 2003 maintained. For natural gas-fired units, a monthly record of fuel usage shall be maintained. These records shall be available on site for inspection by the DEQ and shall be current for the most recent five years.

(9 VAC 5-80-110 and Condition 5 of 5/16/2000 Permit)

4. Visible emission observations shall be used by the permittee to assist in determining whether the emission units are operating properly. Each boiler, B-4 and B-5, shall be observed during each calendar week it operates for normal visible emissions exhaust from the stack, excluding condensed water vapor. The results of the observations shall be recorded and records kept on site, available for review and be current for the most recent five years.

(9 VAC 5-80-110)

5. Whenever any emission unit appears to be exceeding the normal visible emissions, the permittee shall check the emission unit operating parameters, and if the parameters are not within normal range, then

a. Corrective action shall be taken to return the emission unit to proper operation.

b. The visible emission observation shall be repeated to confirm proper operation.

c. A record of observations and the corrective actions shall be retained on site, available for review and be current for the most recent five years.

(9 VAC 5-80-110)

6. If initial corrective action does not appear to adequately reduce visible emissions, then a visible emissions evaluation shall be conducted by certified personnel for at least 60 minutes in accordance with EPA Reference Method 9 (40 CFR Part 60, Appendix A) to demonstrate compliance with the opacity limit. If exceedance of the opacity limit is determined by the evaluation, then the permittee shall proceed as following:

a. Remove the emission unit from service and make necessary repairs and adjustments to bring the operation into compliance with the permit limit.

b. Document the maintenance and repairs performed on the unit.

c. Repeat the visible emissions evaluation to demonstrate compliance with the opacity limit before the emission unit is returned to service.

March 21, 2003

d. In the event that the emission unit still cannot meet the opacity standard in the permit, appropriate action will be agreed upon and implemented by U.S. Army Fort Belvoir and DEQ before the emission unit can be returned to service.

The results of the visible emissions evaluation for the emission unit(s) shall be available on site for inspection by the DEQ and be current for the most recent five years.

(9 VAC 5-80-110)

C. Testing

1. The permitted facility shall be constructed so as to allow for emissions testing at any time using appropriate methods. Upon request from the Department, test ports shall be provided at the appropriate locations.

(9 VAC 5-40-30 and 9 VAC 5-80-110)

2. If testing is conducted in addition to the monitoring specified in this permit, the permittee shall use the following methods in accordance with procedures approved by the DEQ as follows:

Pollutant Test Method (40 CFR Part 60, Appendix A)

NOx EPA Method 7, 7E SO2 EPA Method 6, 6C

PM/PM-10 EPA Method 5, 17, 201A Visible Emissions EPA Method 9

(9 VAC 5-80-110)

V. Fuel Burning Equipment Requirements – (emission units ID# B-107)

- Building – R&D Heating Plant – (Summer Boiler)

A. Limitations

1. The approved fuels for the Cleaver Brooks CB200-400-150 boiler (B-107) are natural gas and distillate oil. Distillate oil is defined as fuel oil that meets the specifications for fuel oil numbers 1 or 2 under the American Society for Testing and Materials. A change in the fuels may require a permit to modify and operate.

(9 VAC 5-80-110 and Condition 10 of 11/4/98 Permit, as amended on 1/24/2001)

March 21, 2003

2. Sulfur dioxide emissions from the Cleaver Brooks CB200-400-150 boiler (B-107) shall be controlled by burning natural gas, or distillate oil with maximum sulfur content not to exceed 0.5 weight percent per shipment.

(9 VAC 5-80-110 and Conditions 3 and 11 of 11/14/98 Permit, as amended on 1/24/2001)

3. TSP, PM10, CO, NOX and VOC emissions from boiler B-107 shall be controlled by firing clean burning fuels, as stipulated in Condition V.A.1, and by maintaining good combustion.

(9 VAC 5-80-110 and Condition 4 of 11/4/98 Permit, as amended on 1/24/2001)

4 Boiler B-107 shall consume no more than 56.7 x 106 cubic feet of natural gas, and 106,592 gallons of distillate oil per year, calculated monthly as the sum of each consecutive 12-month period.

(9 VAC 5-80-110 and Condition 5 of 11/4/98 Permit, as amended on 1/24/2001)

5. Emissions from the operation of boiler B-107 shall not exceed the limits specified below:

Sulfur Dioxide 10.4 lbs/hr 3.8 tons/yr (9 VAC 5-50-260)

Nitrogen Oxides 2.9 lbs/hr 3.9 tons/yr (9 VAC 5-50-260) (as NO2)

Carbon Monoxide 1.6 lbs/hr 2.7 tons/yr (9 VAC 5-50-260)

Compliance with the emission limits contained in this condition shall be determined by compliance with Condition numbers V.A.1-4, A-7, and B.2. Also, records of DEQ-approved emission factors, equations and throughput data shall be maintained to calculate annual emissions for each consecutive 12 month period.

(9 VAC 5-80-110 and Condition 7 of 11/4/98 Permit, as amended on 1/24/2001)

6. Visible emissions from boiler B-107 shall not exceed twenty percent (20%) opacity except during one six-minute period in any one hour in which visible emissions shall not exceed thirty percent (30%) opacity. This condition is derived from the Virginia Regulations and applies at all times except during start-up, shutdown, or malfunction. In accordance with 40 CFR Part 60, 64.43c.(c), Boiler B-107 is not subject to a visible emission standard under the New Source Performance Standard.

(9 VAC 5-80-110 and Condition 8 of 11/4/98 Permit, as amended on 1/24/2001)

7. Boiler B-107 emissions shall be controlled by proper operation and maintenance.

Boiler operators shall be trained in the proper operation of all such equipment.

March 21, 2003

Training shall consist of a review and familiarization of the manufacturer's operating instructions, at minimum.

(9 VAC 5-80-110 and Condition 12 of 11/4/98 Permit, as amended on 1/24/2001)

B. Monitoring and Recordkeeping

1. The permittee shall obtain a certification from the fuel supplier with each shipment of distillate oil. Each fuel supplier certification shall include the following:

a. The name of the fuel supplier,

b. The date on which the oil was received,

c. The volume of distillate oil delivered in the shipment,

d. A statement that the oil complies with the American Society for Testing and Materials specifications for fuel oil numbers 1 and 2, and

e. The sulfur content of the oil.

(9 VAC 5-80-110 and Condition 11 of 11/4/98 Permit, as amended on 1/24/2001)

2. The permittee shall maintain records of all emission data and operating parameters necessary to demonstrate compliance with this permit. The content of and format of such records shall be arranged with the Air Compliance Manager, Northern Virginia Regional Office. These records shall include, but are not limited to:

a. The monthly throughput of natural gas and the daily and monthly throughput of distillate oil for boiler B-107. The annual throughput shall be calculated as the sum of each consecutive twelve (12) month period.

b. All fuel supplier certifications.

c. DEQ-approved emission factors and equations used to calculate emissions from the boilers.

These records shall be available on site for inspection by the DEQ and shall be current for the most recent five (5) years.

(9 VAC 5-80-110, Condition 13 of 11/4/98 Permit, as amended on 1/24/2001 and 40 CFR Part 60 Subpart Dc)

March 21, 2003

3. The permittee shall maintain records of the required training including a statement of time, place, and nature of training provided. The permittee shall have available good written operating procedures and a maintenance schedule for the boiler. These procedures shall be based on the manufacturer's recommendations, at minimum. A record of completed service and maintenance work on the boiler shall be maintained on file by the permittee for the most current five (5) year period. All records required by this condition shall be kept on site and made available for inspection by the DEQ.

(9 VAC 5-80-110 and Condition 12 of 11/4/98 Permit, as amended on 1/24/2001)

4. Visible emission observations shall be used by the permittee to assist in determining whether the emission units are operating properly. The boiler, emission unit B-107, shall be observed during each calendar week it operates for normal visible emissions exhaust from the stack, excluding condensed water vapor. The results of the observations shall be recorded and records kept on site, available for review and be current for the most recent five years.

(9 VAC 5-80-110)

5. Whenever any emission unit appears to be exceeding the normal visible emissions, the permittee shall check the emission unit operating parameters, and if the parameters are not within normal range, then

a. Corrective action shall be taken to return the emission unit to proper operation.

b. The visible emission observation shall be repeated to confirm proper operation.

c. A record of observations and the corrective actions shall be retained on site, available for review and be current for the most recent five years.

(9 VAC 5-80-110)

6. If initial corrective action does not appear to adequately reduce visible emissions, then a visible emissions evaluation shall be conducted by certified personnel for at least 60 minutes in accordance with EPA Reference Method 9 (40 CFR Part 60, Appendix A) to demonstrate compliance with the opacity limit. If exceedance of the opacity limit is determined by the evaluation, then the permittee shall proceed as following:

a. Remove the emission unit from service and make necessary repairs and

b. Document the maintenance and repairs performed on the unit.

March 21, 2003

c. Repeat the visible emissions evaluation to demonstrate compliance with the opacity limit before the emission unit is returned to service.

d. In the event that the emission unit still cannot meet the opacity standard in the permit, appropriate action will be agreed upon and implemented by U.S. Army Fort Belvoir and DEQ before the emission unit can be returned to service.

The results of the visible emissions evaluation for the emission unit(s) shall be available on site for inspection by the DEQ and be current for the most recent five years.

(9 VAC 5-80-110)

C. Testing

1. The permitted facility shall be constructed so as to allow for emissions testing at any time using appropriate methods. Test ports will be provided at the appropriate locations.

(9 VAC 5-80-110 and Condition 9 of 11/4/98 Permit, as amended on 1/24/2001)

2. If testing is conducted in addition to the monitoring specified in this permit, the permittee shall use the following methods in accordance with procedures approved by the DEQ as follows:

Pollutant Test Method (40 CFR Part 60, Appendix A)

VOC EPA Methods 18, 25, 25a NOx EPA Method 7, 7E SO2 EPA Method 6, 6C CO EPA Method 10

PM/PM-10 EPA Method 5, 17, 201a Visible Emissions EPA Method 9

(9 VAC 5-80-110)

D. Reporting

1. The permittee shall submit fuel quality reports to the Air Compliance Manager, Northern Virginia Regional Office, within 30 days after the end of each semi-annual period. If no shipments of distillate oil were received during the semi-annual period, the semi-annual report shall consist of the dates included in the semi-annual period and a statement that no oil was received during the semi-annual period. If distillate oil was received during the semi-annual period, the report shall include:

March 21, 2003

a. The dates included in the semi-annual period;

b. A copy of all fuel supplier certifications for all shipments of distillate oil received during the semi-annual period or a semi-annual summary from each fuel supplier that includes the information specified in Condition V.B.1 for each shipment of distillate oil; and,

c. A signed statement from the owner or operator of the facility that the fuel supplier certifications or summaries of fuel supplier certifications represent all of the distillate oil burned or received at the facility.

(9 VAC 5-80-110 and Condition 14 of 11/4/98 Permit, as amended on 1/24/2001 and 40 CFR Part 60 Subpart Dc)

VI. Fuel Burning Equipment Requirements – (Other small No. 2 oil or No. 2 oil/gas-fired boilers)

A. Limitations

1. Emissions from the operation of each of the small No. 2 oil or gas/No. 2 oil-fired boilers shall not exceed the limits specified below:

Total Suspended Particulate/PM-10 0.3 lbs/106 Btu (9 VAC 5-40-900 A. 2.)

Sulfur Dioxide 1.06 lbs/106 Btu (9 VAC 5-40-930 A. 2.)

(9 VAC 5-80-110)

2. Visible emissions from each of the boiler stacks shall not exceed twenty percent opacity, except for one six-minute period in any one hour of not more than thirty percent opacity. Failure to meet the requirements of this condition because of the presence of water vapor shall not be a violation of this condition.

(9 VAC 5-50-80)

3. No owner or other person shall cause or permit to be discharged from any affected facility any nitrogen oxide emissions in excess of that resultant from using reasonably available control technology (RACT).

(9 VAC 5-40-310 and 9 VAC 5-80-110)

4. The addition or routine replacement of natural gas or fossil fuel-fired boilers, between 1 to 10 million Btu/hour heat input, may not require an air permit but is subject to registration update and the limits stated in Conditions VI.B.1 and 2.

(9 VAC 5-80-11, 9 VAC 5-20-160, 9 VAC 5-40-900 and 9 VAC 5-40-930)

March 21, 2003

B. Monitoring and Recordkeeping

1. For the small oil-fired boilers, application of RACT for NOX shall be the operation and maintenance of the unit in accordance with manufacturer’s specifications and good air pollution control practices. A copy of all relevant operation, maintenance, and specification documentation as provided by the manufacturer for each unit and device shall be maintained on the premises of the facility. Each unit shall be operated and maintained in adherence with that documentation to the degree appropriate and practicable with the intention of minimizing NOX emissions.

(9 VAC 5-80-110 and Condition 6 of the 5/16/2000 Permit)

2. The permittee shall maintain records of all emission data and operating parameters necessary to demonstrate compliance with this permit. For the boilers, a record shall be maintained on the fuel shipments, including fuel type and sulfur content as provided by the supplier. These records shall be available on site for inspection by the DEQ and shall be current for the most recent five (5) years.

(9 VAC 5-40-50 and 9 VAC 5-20-160)

3. Visible emission observations shall be used by the permittee to assist in determining whether certain emission units are operating properly. Specifically, the emission units to be observed are boilers B-6 and B-7, each with heat input capacity greater than 10 million Btu/hour. Each emission unit shall be observed during each calendar week it operates for normal visible emissions exhaust from the stack, excluding condensed water vapor. The results of the observations shall be recorded and records kept on site, available for review and be current for the most recent five years.

(9 VAC 5-80-110)

4. Whenever any emission unit appears to be exceeding the normal visible emissions, the permittee shall check the emission unit operating parameters, and if the parameters are not within normal range, then

a. Corrective action shall be taken to return the emission unit to proper operation.

b. The visible emission observation shall be repeated to confirm proper operation.

c. A record of observations and the corrective actions shall be retained on site, available for review and be current for the most recent five years.

(9 VAC 5-80-110)

March 21, 2003

5. If initial corrective action does not appear to adequately reduce visible emissions, then a visible emissions evaluation shall be conducted by certified personnel for at least 60 minutes in accordance with EPA Reference Method 9 (40 CFR Part 60, Appendix A) to demonstrate compliance with the opacity limit. If exceedance of the opacity limit is determined by the evaluation, then the permittee shall proceed as following:

a. Remove the emission unit from service and make necessary repairs and adjustments to bring the operation into compliance with the permit limit.

b. Document the maintenance and repairs performed on the unit.

c. Repeat the visible emissions evaluation to demonstrate compliance with the opacity limit before the emission unit is returned to service.

d. In the event that the emission unit still cannot meet the opacity standard in the permit, appropriate action will be agreed upon and implemented by U.S. Army Fort Belvoir and DEQ before the emission unit can be returned to service.

The results of the visible emissions evaluation for the emission unit(s) shall be available on site for inspection by the DEQ and be current for the most recent five years.

(9 VAC 5-80-110)

VII. Process Equipment Requirements - (emission units ID #EG13 - EG22, and EG70 – EG73) - Generators

A. Limitations

1. The use of the electric generating equipment shall be limited to the production of electricity for emergency purposes only. Specifically, the electrical generators are limited to providing power at the location during interruption of service from the normal power supplier, periodic maintenance, testing, and operational training.

(9 VAC 5-80-110 and Condition 3 of 7/1/2002 Permit)

2. Nitrogen Oxides emissions from the ten Caterpillar model 3516 diesel engine-driven emergency generators (EG13-22) shall be controlled by fuel injection set at 4 degrees retarded timing. The permittee shall keep records on site to provide certification that the injection timing for each engine has been properly set. All engines shall be provided with adequate access for inspection.

(9 VAC 5-80-110 and Condition 4 of 7/1/2002 Permit)

March 21, 2003

3. The four Caterpillar model 3516B or equivalent diesel engine-driven emergency generators and ten Caterpillar model 3516 diesel engine-driven emergency generators (EG70-73 and EG13-22) shall not operate more than 1,400 hours/yr, calculated monthly as the sum of each consecutive 12 month period.

(9 VAC 5-80-110 and Condition 5 of 7/1/2002 Permit)

4. The approved fuel for the four Caterpillar model 3516B or equivalent diesel engine-driven emergency generators and ten Caterpillar model 3516 diesel engine-driven emergency generators (EG70-73 and EG13-22) is diesel fuel oil.

A change in the fuel may require a permit to modify and operate.

(9 VAC 5-80-110 and Condition 6 of 7/1/2002 Permit)

5. The fuel shall meet the American Society for Testing and Materials (ASTM) specifications for numbers 1 or 2 diesel fuel oil. The maximum sulfur content per shipment of fuel shall not exceed 0.5% by weight.

(9 VAC 5-80-110 and Condition 7 of 7/1/2002 Permit)

6. Hourly emissions from the operation of each of the ten Caterpillar model 3516 diesel engine-driven emergency generators (EG13-22) shall not exceed the limits specified below:

Nitrogen Oxides (as NO2) 51.2 lbs/hr Sulfur Dioxide 8.8 lbs/hr Carbon Monoxide 12.4 lbs/hr Volatile Organic Compounds 1.5 lbs/hr Particulate Matter 1.7 lbs/hr

The emission limits are derived from manufacturer guaranteed (“not to exceed”) emission rates. Compliance may be determined as stated in Condition VII.A.10 or by stack testing, upon request of the Department and using EPA-approved test methods as specified in Conditions VII.C.2 and 3.

(9 VAC 5-80-110 and Condition 9 of 7/1/2002 Permit)

7. Hourly emissions from the operation of each of the four Caterpillar model 3516B or equivalent diesel engine-driven emergency generators (EG70-73) shall not exceed the limits specified below:

Nitrogen Oxides (as NO2) 34.2 lbs/hr Sulfur Dioxide 9.6 lbs/hr Carbon Monoxide 2.9 lbs/hr Volatile Organic Compounds 1.2 lbs/hr Particulate Matter 0.8 lbs/hr

The emission limits are derived from manufacturer guaranteed (“not to exceed”) emission rates. Compliance may be determined as stated in Condition VII.A.10

March 21, 2003 or by stack testing, upon request of the Department and using EPA-approved test methods as specified in Conditions VII.C.2 and 3.

(9 VAC 5-80-110 and Condition 10 of 7/1/2002 Permit)

8. Total emissions from the diesel engine-driven emergency generators at facility shall not exceed the limits specified below:

Nitrogen Oxides (as NO2) 32.4 tons/yr Sulfur Dioxide 6.3 tons/yr Carbon Monoxide 6.8 tons/yr Volatile Organic Compounds 1.0 tons/yr Particulate Matter 1.0 tons/yr

These emissions are derived from the estimated overall emission contribution from operating limits. Exceedance of the operating limits shall be considered credible evidence of the exceedance of emission limits. Compliance with these emission limits may be determined as stated in Condition numbers VII.A.3 and VII.B.2. Also, records of DEQ-approved emission factors, equations and throughput data shall be maintained to calculate annual emissions for each consecutive 12 month period.

(9 VAC 5-80-110 and Condition 11 of 7/1/2002 Permit)

9. Visible emissions from the four Caterpillar model 3516B or equivalent diesel engine-driven emergency generators and ten Caterpillar model 3516 diesel engine-driven emergency generators (EG70-73 and EG13-22) shall not exceed twenty percent opacity except during one six-minute period in any one hour in which visible emissions shall not exceed thirty percent opacity as determined by EPA Method 9 (reference 40 CFR Part 60, Appendix A).

(9 VAC 5-80-110 and Condition 12 of 7/1/2002 Permit)

10. Diesel engine emissions shall be controlled by proper operation and maintenance. Operators shall be trained in the proper operation of all such equipment. Training shall consist of a review and familiarization of the manufacturer's operating instructions, at minimum.

(9 VAC 5-80-110, and Condition 22 of 7/1/2002 Permit)

B. Monitoring and Recordkeeping

1. The permittee shall obtain a certification from the fuel supplier with each shipment of diesel fuel oil. Each fuel supplier certification shall include the following:

a. The name of the fuel supplier;

March 21, 2003

b. The date on which the fuel was received;

c. The volume of fuel delivered in the shipment;

d. A statement that the fuel complies with the American Society for Testing and Materials (ASTM) specifications for numbers 1 or 2 diesel fuel oil,

e. The sulfur content of the diesel fuel oil.

(9 VAC 5-80-110 and Condition 8 of 7/1/2002 Permit)

2. The permittee shall maintain records of emission data and operating parameters as necessary to demonstrate compliance with this permit. The content and format of such records shall be arranged with the Air Compliance Manager, Northern Virginia Regional Office. These records shall include, but are not limited to:

a. Annual hours of operation of each diesel engine generator set, calculated monthly as the sum of each consecutive 12 month period.

b. All fuel supplier certifications.

c. Scheduled and unscheduled maintenance, and operator training.

d. DEQ-approved emission factors and equations used to calculate emissions from the engines.

These records shall be available for inspection by the DEQ and shall be current for the most recent five years.

(9 VAC 5-80-110 and Condition 15 of 7/1/2002 Permit)

3. The permittee shall maintain records of the required training including a statement of time, place and nature of training provided. The permittee shall have available good written operating procedures and a maintenance schedule for the engines. These procedures shall be based on the manufacturer's recommendations, at minimum. All records required by this condition shall be kept on site and made available for inspection by the DEQ.

(9 VAC 5-80-110 and Condition 22 of 7/1/2002 Permit)

4. Visible emission observations shall be used by the permittee to assist in determining whether the emission units are operating properly. Each diesel engine-driven generator, EG13 - EG20, EG64 - EG65, and EG70 - EG73, shall be observed during its scheduled maintenance/test run for normal visible emissions exhaust from the stack, excluding condensed water vapor. The

March 21, 2003 results of the observations shall be recorded and records…