Amendment 0003 PPI Attachment 80B - PNSY A-102_PNSY-Kittery_IntExt-UT_InspectionRpt_2018-signed.pdf

TTI INSPECTIONS

A DIVISION OF TTI ENVIRONMENTAL, INC.

1253 NORTH CHURCH STREET

MOORESTOWN, NEW JERSEY 08057

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Prepared for:

NAVFAC MIDLANTIC – HAMPTON ROADS IPT

NAVAL STATION NORFOLK

9324 VIRGINIA AVENUE

NORFOLK, VIRGINIA 23511

Job Site/Location:

PORTSMOUTH NAVAL SHIPYARD, KITTERY, MAINE

TTI Project No. 17-926 October 23, 2018

Prepared by: Reviewed by:

Richard C. Clayton Scott W. Nowicki Project Coordinator Director of Inspection Services

TABLE OF CONTENTS

Page

1.0 INSPECTION OVERVIEW

2.0 TANK DESCRIPTION

3.0 FINDINGS

4.0 RECOMMENDATIONS

LIST OF TABLES AND APPENDICES

Table 1.0: Ultrasonic Thickness (UT) Data

Appendix A: Field Inspection Checklist Appendix B: Photo Documentation Appendix C: Tank Diagrams Appendix D: Ultrasonic Thickness Data Reports Appendix E: Settlement Survey Data Appendix F: Minimum Acceptable Shell Plate Thickness Equations Appendix G: Minimum Acceptable Bottom Plate Thickness Equations Appendix H: Inspection Methodology Appendix I: Inspector Certifications

Portsmouth Naval Shipyard

October 23, 2018

1.0 INSPECTION OVERVIEW

Tank ID: A-102

Tank Location: Portsmouth Naval Shipyard Kittery, Maine

Inspection Performed: Internal and External Visual Inspection Ultrasonic Thickness Testing Internal and External Settlement Survey Magnetic Flux Leakage Floor Scanning

Date(s) of Inspection: June 20, 2018

Inspector(s): Scott Nowicki API 653 Certification No. 23939 ASNT SNT-TC-1A Level II UT, PT, MT, VT

Matthew Cruz ASNT SNT-TC-1A Level II UT, PT, MT, VT

Reference Standards: API Standard 653 API Recommended Practice 575 ASME Sections V and IX

NFPA 30

2.0 TANK DESCRIPTION

Manufacture Date: Approximately 1977

Name of Manufacturer: Undetermined

Original Design Std: Undetermined

Product Stored: No. 2 Fuel Oil

Specific Gravity: 0.89

Nominal Capacity: 65,817 US Gallons

Working Capacity: 60,000 US Gallons

Material: Carbon Steel; Type Undetermined

Insulation System: Yes, Foamglas®

Configuration: Vertical, Cylindrical

Elevated: No

Construction: Height: 28 feet Diameter: 20 feet

Secondary Containment: Outdoor, Dike, Concrete Masonry Units, Reinforced Concrete

Length: 66 feet Width: 30 feet Height: ~6 feet (varies)

October 23, 2018

3.0 FINDINGS

Internal/External Visual Inspection

A comprehensive Internal and External Visual Inspection of the tank system was performed. The inspection checklist is presented in Appendix A and photo documentation is presented in Appendix B of this report.

Visual inspection revealed the following areas of concern specifically related to API 653 Suitability for Service requirements, and will require repair prior to placing the tank back in to service:

The seal between the tank chime and the concrete foundation is showing signs of minor degradation (API Standard 653 § 7.2.3).

Additionally, the following areas of concern were noted with respect to other related code requirements and repairs should be considered by the tank owner prior to placing the tank back in to service:

The tank is not properly labeled; missing HMIS or NFPA 704 Fire Diamond label

(NFPA 30 §21.7.2.1).

The containment area contains vegetation growth and combustible materials. Ground areas should be kept free of trash, weeds, and other unnecessary combustibles (NFPA 30 § 6.9.4).

The insulation system is saturated with water which has resulted in corrosion underneath insulation (CUI). Additionally, there is moss, lichen and vegetation growth in insulation jacket seams on the tank roof and shell.

The exterior coating on the piping system is exhibiting minor to moderate coating failure (API RP574 § 10.1.6)

Tank is equipped with mechanical level gauge, however the tape assembly is broken.

An 8‐inch gate valve at the tank shell is not seating properly and allowed for a significant amount of product to enter the tank following cleaning, and during the internal inspection. It is controlling product flow through a 40 foot long crossover pipe to the adjacent Tank A‐101, with another 8‐inch valve that does not appear to be seated well either.

Internal visual inspection and MFL floor scanning identified only minor internal corrosion occurring, with the deepest topside pit measuring 0.115" deep (0.313" bottom plate thickness).

October 23, 2018

3.0 FINDINGS (CONTINUED)

Ultrasonic Thickness Testing

Thickness measurements were recorded for the purpose of determining corrosion rates and remaining service life of the tank. Summary data is presented in Table 1.0, below:

Item Design

Thickness

Minimum

Allowable

Thickness

Minimum

Recorded

Thickness

Vessel Age

(years)

Corrosion Rate

(inches/year)

Remaining

Service Life

(years)

Roof 0.266 0.090 0.250 41 0.0004 >20 years

Shell Course 2‐3 0.187 0.100 0.194 41 0.0001 >20 years

Shell Course 1 0.250 0.100 0.262 41 0.0001 >20 years

Bottom 0.313 0.100 0.295 41 0.0004 >20 years

Table 1.0: Tank Ultrasonic Thickness (UT) Data

All thickness data is reported in inches

The location and data recorded at each thickness measurement location for the tank is shown on the diagrams in Appendix C and the UT data report is included in Appendix D.

October 23, 2018

4.0 RECOMMENDATIONS

Visual inspection revealed several areas of concern specifically related to API 653 Suitability for Service requirements, and the following repairs are required prior to placing the tank back in to service:

Maintain the sealant between the tank bottom and the concrete pedestal to prevent water from flowing under the tank bottom (API 653 § 7.2.3).

Additionally, numerous other areas of concern were noted with respect to other related code requirements and the following repairs should be considered by the tank owner prior to placing the tank back in to service:

Properly label the tank with the appropriate NFPA 704 Diamond Label, or another approved system. The label shall be located and sized so that it can be easily seen by emergency responders (NFPA 30§ 21.7.2.1).

Regularly perform housekeeping and maintenance within the containment dike area in accordance with NFPA 30 and/or local, state and federal requirements (NFPA 30 § 6.9.4).

The condition of the insulation is contributing to accelerated exterior corrosion of the tank system. Corrosion Under Insulation (CUI) was identified on the tank shell and roof plates at test port locations. Insulation was originally installed when these tanks were heated and storing No. 6 Fuel Oil. Insulation is not required for tanks storing No.

2 Fuel Oil. It is recommended that the deteriorating insulation be removed, and the exterior of the tank recoated by a qualified NACE or SSPC coatings contractor. (API

RP 575 § 7.27).

Touch up areas of coating failure on piping as needed. Maintaining the exterior coating will appreciably increase the life of the piping (API RP 574 § 10.1.6).

The damaged and non‐functional mechanical level gauge device should be either serviced to restore proper functionality, replaced, or removed from the tank system if no longer in use. Product level is currently monitored in the control room using an electronic differential pressure level sensor. Although a procedure is in place to relay product levels to notify the filling operator of the pending completion of the tank fill operation at the fill connection, the ability to directly monitor product level at the tank system is recommended. (NFPA 30 § 21.7.1.6.1, Best Management Practice).

The 8‐inch gate valve associated with the 40 foot crossover pipe between the fuel tanks should be serviced or replaced (Best Management Practice).

Only minor internal corrosion was noted on the tank bottom and shell plates. No action is required at this time.

October 23, 2018

4.0 RECOMMENDATIONS (CONTINUED)

If extended use of this tank is being considered, the tank owner/operator should refer to the most recent publication of Unified Facilities Criteria (UFC) 3-460-01, Design: Petroleum Fuel Facilities, Chapter 12, Major Rehabilitation for specific guidance to meet current fuel quality standards, safety requirements, and environmental regulations.

Following completion of the required repairs, Tank A-102 is deemed suitable for continued service.

Based on the results of this inspection, TTI recommends the following maximum inspection interval(s):

An External Inspection is conducted by June 20, 2023. API 653 requires External Inspections be conducted at least every five (5) years or at the quarter corrosion rate life of the shell, whichever is sooner.

An Ultrasonic Thickness Inspection of the shell and roof is conducted by June 20, 2033. API 653 requires UT inspection be conducted at least every 15 years or at the half corrosion rate life of the shell, whichever is sooner.

An Internal Inspection is conducted by June 20, 2038. API 653 requires Internal Inspection be conducted at intervals not exceeding 20 years or at intervals to insure that the bottom plate minimum thickness at the next inspection are not less than the values of T-Minimum.

APPENDIX A:

FIELD INSPECTION CHECKLIST

TANK NO. A‐102

PREPARED FOR:

JOB SITE/LOCATION:

Portsmouth Naval Shipyard, Kittery, Maine

TTI PROJECT NUMBER: 17‐926

DATE: 6/20/2018

CERTIFICATION NO(S): API 653 CERTIFICATION NO. 23939

TTI INSPECTIONS – NAVFAC Mitlantic – Hampton Roads IPT ‐ TANK NO. A‐102 2018

AST FIELD INSPECTION CHECKLIST VERSION 07.24.2018

ABOVEGROUND STORAGE TANK FIELD INSPECTION CHECKLIST

PART A: GENERAL INFORMATION

TTI Job Number: 17‐926 Date of Inspection: 6/20/2018

Tank ID: TANK NO. A‐102

Tank Owner: NAVFAC Mitlantic – Hampton Roads IPT

Location: Portsmouth Naval Shipyard, Kittery, Maine

Alt. Location Name (ex: Bldg #): Building 72, Controlled Industrial Area

Inspection(s) Performed: Internal Visual Inspection

External Visual Inspection

Ultrasonic Thickness Testing

Barcol Hardness Testing

External Settlement Survey

Internal Settlement Survey

Static Head Testing

Magnetic Particle Testing

Liquid Penetrant Testing

Vacuum Box Testing

MFL Floor Scanning

Acoustic Emissions Testing

Point of Contact: Lisa Melvin POC Email Address: lisa.melvin@navy.mil

Inspector: Scott Nowicki Certification No: API 653 Certification No. 23939

Reference Standard(s): API 653/STI SP001/NPFA 30 2018/NFPA 77/API RP‐ 577/API Standard 2000 STI Category (if applicable): N/A NFPA Classification: Class II

PART B: TANK INFORMATION

Manufacturer: Undetermined

Mfg. Date: 1977 Install Date: 1977 Design Standard: Undetermined

Product Stored: No. 2 Fuel Oil Specific Gravity: 0.89

Nominal Capacity: 65,817 U.S. Gallons Calculated Marked Nameplate

Working Capacity: 60,000 U.S. Gallons Approx. Calculated Marked Nameplate

Max Operating Pressure Atmos. Max Design Pressure: Unknown

Max Operating Temp: Ambient Max Design Temp: Unknown

Tank Labeling (check if installed):

Tank ID Capacity Contents HMIS/NFPA Info

Missing Labels

PART C: TANK CONSTRUCTION

Length: ‐ ft. Width: ‐ ft. Height: 28 ft. Diameter: 20 ft.

Doublewall Singlewall

Elevated Flat Bottom

Cylindrical Rectangular

Horizontal Vertical

Carbon Steel Type: Undetermined

Stainless Steel Type:

Fiberglass Type:

HDPE / XLPE

UL‐2085 (Convault®,Fireguard®,etc.)

Other:

Point of Service:

Bulk Storage

Waste Storage

Generator

Fuel Dispenser

Heater/Burner

Other: Boilers

NOTES:

The tank is not properly labeled; missing HMIS or NFPA 704 Fire Diamond label (NFPA 30 § 21.7.2.1).

TTI INSPECTIONS – NAVFAC Mitlantic – Hampton Roads IPT ‐ TANK NO. A‐102 2018

PART D: PREVIOUS INSPECTION HISTORY

No Previous Inspection or Testing Records

Previous External Inspection Date: September 2015

Previous Internal Inspection Date: N/A

Previous UT Testing Date: September 2015

Are monthly inspections being performed by the tank owner’s inspector?

Yes No

NOTES:

PART E: SECONDARY CONTAINMENT SYSTEM

Length: 6 ft. Width: 30 ft. Depth: (Varies) ft. Diameter: ‐ ft.

Containment Capacity:

(Approximate)

0 US Gallons

Spill Containment Not Required

No Spill Containment Present

Check all that apply:

Doublewall Tank

Dike/Curbing

Earthen Berm

Remote Impoundment

Indoors Outdoors

Floor Drains

Sump

Concrete Masonry Units

Reinforced Concrete

Steel Box

Impermeable Liner

Rain Shields

Containment Drains

If yes, are provisions in place to prevent liquids from entering natural waterways and public sewers or drains?

Observations:

Cracks

Corrosion

Vegetation Growth

Standing Water

Debris

Open Penetrations

Inadequate Capacity

‐ gallons

If checked, please explain in notes

Does the interstitial leak gauge indicate the presence of water/product within the space?

N/A No Yes

If Yes, what is the gauge reading?

inches

The containment area contains vegetation growth and combustible materials. Ground areas should be kept free of trash, weeds, and other unnecessary combustibles (NFPA 30 § 6.9.4).

TTI INSPECTIONS – NAVFAC Mitlantic – Hampton Roads IPT ‐ TANK NO. A‐102 2018

PART F: EXTERNAL INSPECTION

Is there a filling platform?

Not Required

Yes

No

If Yes, what is the distance between the top of the platform and the filling port/connection?

Less than four (4) feet Greater than four (4) feet

Is the tank system equipped with ladders, stairs or walking/working surfaces?

No

Yes, Ladders

Yes, Stairs

Yes, Walking/Working Surfaces

If yes, are there any areas of concern that may result in injury and/or promote product spills?

No Yes

If yes, please describe:

Is the tank located in an area that is vulnerable to vehicle traffic?

If Yes, is there sufficient vehicle protection?

If No, describe:

Does the AST have a protective exterior coating?

Not Required Yes No

Is the coating exhibiting deterioration that is resulting in exterior corrosion?

No significant coating failure Minor failure

Moderate/Severe Failure

Click all that apply and explain below:

Cracking

Peeling

Rust Blisters

UV degradation

Corrosion

Is the tank exterior damaged (dents, bulges, etc.)?

Visual Inspection Obstructed

If Yes, describe:

TTI INSPECTIONS – NAVFAC Mitlantic – Hampton Roads IPT ‐ TANK NO. A‐102 2018

PART F: EXTERNAL INSPECTION (CONTINUED)

Condition of Shell Welds:

Obstructed Satisfactory Unsatisfactory

If unsatisfactory, describe:

Reference API RP 577 Welding Inspection & Metallurgy

Condition of Roof/Heads Plate Welds:

Obstructed Satisfactory

Condition of Bottom Plate Welds:

Obstructed Satisfactory N/A Unsatisfactory

Is the tank located in an area that is safe from tampering and trespassing in accordance with NFPA30 Section 21.7.2.2?

N/A

If yes, check all that apply:

Controlled Area Indoors

Padlocks/Locking Mechanisms Fencing Other:

Is the tank insulated?

If Yes, insulation type:

Fiberglass Foamglas® Foam Other:

If yes, jacket type:

Metal Plastic Metal and Plastic Other:

Is the insulation saturated with water?

No Yes

If yes, is there apparent corrosion underneath insulation (CUI)?

The insulation system is saturated with water which has resulted in corrosion underneath insulation (CUI). Additionally, there is moss, lichen and vegetation growth in insulation jacket seams on tank roof and shell.

TTI INSPECTIONS – NAVFAC Mitlantic – Hampton Roads IPT ‐ TANK NO. A‐102 2018

PART G: TANK FOUNDATION INSPECTION

Type:

Concrete Pad

Concrete Pedestal

Gravel

Earthen

Asphalt

Is the foundation system exhibiting degradation?

Cracks

Un‐Level

Vegetation Growth

Erosion

Significant Settlement

Other:

If checked, please describe below

NOTES:

The seal between the tank chime and the concrete foundation is showing signs of minor degradation (API Standard 653 § 7.2.3).

PART H: TANK SUPPORT INSPECTION

N/A ‐ None

Saddles

Legs

Chime

QTY:

Concrete

Steel

Plastic

Wood

Other:

Are the supports anchored to prevent movement?

No

QTY:

of

Is the distance from the tank bottom to tank foundation greater than 12 inches?

N/A : No Flash Point

N/A : Class IIIB Liquid

If yes, are the supports protected by a fire resistant material or suppression systems? (NFPA 30 Section 22.5.2.4)

Yes Type:

Cracks

Corrosion

Weld Failure

Coating Failure

Combustible Material

Damaged (bent, dented, etc.)

If checked, please describe below

Is the tank located in an area that is subjected to possible flooding?

N/A Yes No Undetermined

If yes, are there provisions to prevent the tank from floating during a rise in water level (NFPA 30 22.5.2.5)?

TTI INSPECTIONS – NAVFAC Mitlantic – Hampton Roads IPT ‐ TANK NO. A‐102 2018

PART I: VENTING SYSTEMS INSPECTION

Normal Vent:

Not Applicable

Installed

Not installed

Type: Atmospheric Mushroom Vent w/screen Diameter: 6‐inch

Is the normal vent diameter equal to or greater than 1.25 inches?

Yes No

Is the normal vent equal to or greater than the largest piping inlet/outlet pipe diameter?

Yes No

If No, what is the Inlet/outlet pipe diameter:

Has the normal vent device been modified or obstructed?

No Yes

If Yes, describe:

Is the device free of rust, corrosion, debris and product build‐up that may inhibit operation?

Yes No

If No, describe:

Is the secondary space being normally vented?

Primary Emergency Vent:

Type: Weighted Manway Cover Diameter: 24‐inch

Is the emergency vent diameter equal to or greater than 3 inches?

Yes No

Is the vent gasket free of cracks, wear or deterioration that could result in a vapor leak?

Yes No

If No, describe:

Has the emergency vent device been modified or obstructed?

No Yes

If Yes, describe:

Is the device free of rust, corrosion, debris and product build‐up that may inhibit operation?

Yes No

If No, describe:

Does the device have free movement and functions as designed?

Yes No

TTI INSPECTIONS – NAVFAC Mitlantic – Hampton Roads IPT ‐ TANK NO. A‐102 2018

PART I: VENTING SYSTEMS INSPECTION (CONTINUED)

Secondary Emergency Vent (If applicable):

Type: Diameter:

Is the emergency vent diameter equal to or greater than 3 inches?

Yes No

Is the vent gasket free of cracks, wear or deterioration that could result in a vapor leak?

Yes No

If No, describe:

Has the emergency vent device been modified or obstructed?

No Yes

If Yes, describe:

Is the device free of rust, corrosion, debris and product build‐up that may inhibit operation?

Yes No

If No, describe:

Does the device have free movement and functions as designed?

TTI INSPECTIONS – NAVFAC Mitlantic – Hampton Roads IPT ‐ TANK NO. A‐102 2018

PART J: PIPING & ANCILLARY EQUIPMENT INSPECTION

Is the tank system equipped with a piping system? Yes No If NO, PROCEED TO PART: K

Type/Materials:

Carbon HDPE Stainless Copper

PVC

Other/Additional Info:

Is the piping properly supported?

Max. Distance between supports:

feet

If applicable, is the piping fire‐rated?

N/A, Product stored is not flammable/combustible

Are there any unprotected valves that may allow for inadvertent product spills?

(Example: missing pipe cap, plug or valve locking device)

Is there exterior corrosion on the piping?

Were there any previous or active leaks identified?

No Yes

If yes,:

Minor

Moderate‐to‐Severe Please describe in notes section

If applicable, is the discharge piping equipped with isolation valve(s)?

Are all required ancillary devices installed (anti‐siphon valves, pressure relief valves, etc.)?

Is the tank filled from a remote location?

Yes No

If yes, is there a disconnectable coupling on the fill pipe (tanker/rail car unloading, quick connections, etc.)?

N/A Yes No

If yes, is there a check valve to prevent back flow during loading operations?

Yes No N/A:

NOTES:

The exterior coating on the piping system is exhibiting minor to moderate coating failure (API RP 574 § 10.1.6).

An 8‐inch gate valve at the tank shell is not seating properly and allowed for a significant amount of product to enter the tank following cleaning, and during the internal inspection. It is controlling product flow through a 40 foot long crossover pipe to the adjacent Tank A‐101, with another 8‐inch valve that does not appear to be seated well either.

TTI INSPECTIONS – NAVFAC Mitlantic – Hampton Roads IPT ‐ TANK NO. A‐102 2018

PART K: INVENTORY CONTROLS & OVERFILL PREVENTION SYSTEMS

Is the tank system equipped with a level gauge?

No

If yes, type (check all that apply):

Manual Gauging Port

Clock Face Float Gauge

Tape Float Gauge

Sight Glass

Automatic Tank Gauging System

Is the gauge readable from the filling area?

Are there controls for product spills during filling operations?

Spill Bucket

Direct Fill Connection

Containment Dike

Other:

Is the tank system equipped with an overfill prevention system?

Non‐Combustible or Non‐Flammable Liquid

N/A Combustible/Flammable liquid, but tank capacity is less than 1,320 gallons

If yes, type (check all that apply):

Shut‐off Valve

Visual/Audible Alarm Inside Ctrl Rm.

Standard Operating Procedure (SOP)

Are audible/visual alarms within line of sight and/or hearing of the filling area?

N/A Yes No

When were the overfill devices last inspected?

N/A:

Date:

No Previous History Greater than 1 year Undetermined

Does the tank store a flammable or combustible product Yes No If NO, PROCEED TO PART L

Are there any apparent electrical hazards associated with this tank system?

Is the tank located indoors and contains a Class I or II Flammable/Combustible Liquid?

If yes, are there fire safety valves installed each liquid transfer pipe?

N/A Yes No

If no, are there pneumatic, electric or solenoid valves that could allow for automatic shut‐off?

Yes No

Is the tank grounded to prevent the accumulation of static electricity?

N/A Yes No

Tank is equipped with mechanical level gauge, however the tape assembly is broken.

TTI INSPECTIONS – NAVFAC Mitlantic – Hampton Roads IPT ‐ TANK NO. A‐102 2018

PART L: ULTRASONIC THICKNESS (UT) TESTING

Was UT Testing performed? Yes No IF NO, PROCEED TO PART: M

NDT Technician: Matthew Cruz

ASNT SNT‐TC‐1A Certification Level: Level I Level II Level III

Ultrasonic Thickness (UT) Gauge(s): Olympus 38DL Plus

GEIT DMS‐2

GEIT DMS Go

Dakota/NDT 815 MVX

Other:

Ultrasonic Transducer(s): Olympus D7906‐SM (5MHz) Olympus D790‐SM (5MHz)

GEIT TC‐560 (5MHz) GEIT FH2E (7.5MHz)

GEIT DA‐312 (10MHz) GEIT HT‐400A, Hi‐Temp (5MHz)

Dakota 0.25” HD (5MHz) Other: ( MHz)

Gauge Calibration Date: Factory: 2/15/2018 Field: 6/20/2018

Test Material: Carbon Steel Type: Undetermined

Stainless Steel Type:

Other: Type:

Ultrasonic Couplant: UltraSonix Medium Viscosity

UltraSonix High Viscosity

SonoTech Ultragel II

SonoTech 600

SonoTech 900

Other:

Test Material Temperature (Range): Ambient °F

UT Test Areas and Datalogger Filenames: Area Filename

Top/Roof PSNY A102 TOP

Bottom PSNY A102 BOT

Shell

Shell 1st Course PSNY A102 SHELL 1COR

Shell Ladder/Stairs PSNY A102 LAD

Other:

Other:

TTI INSPECTIONS – NAVFAC Mitlantic – Hampton Roads IPT ‐ TANK NO. A‐102 2018

PART M: INTERIOR INSPECTION

Was the tank inspected internally? Yes No IF NO, PROCEED TO PART: N

Do the interior tank plates have a protective coating or liner?

If Yes, please describe:

Shell: Type: Thickness: mil

Roof/Heads: Type: Thickness: mil

Bottom: Type: Thickness: mil

Is the coating/liner exhibiting deterioration?

No significant coating failure Minor failure Moderate/Severe Failure

Click all that apply:

Cracking Delaminating Peeling Wrinkles Bubbles/Pimples

Is the tank interior damaged (dents, bulges, etc.)?

Are there any apparent concerns that may prevent the inventory and high/low level alarm floats from working properly?

If Yes, describe:

Internal level float tape is damaged and no longer functional

Is there any damage and/or concerns with the columns, reinforcing pads or roof girders/rafters that may jeopardize the structural integrity of the tank?

Not Applicable

Condition of Shell Welds:

Satisfactory

Condition of Roof/Heads Plate Welds:

Satisfactory

Condition of Bottom Plate Welds:

Satisfactory N/A

Internal visual inspection and MFL floor scanning identified only minor internal corrosion occurring, with the deepest topside pit measuring 0.115" deep (0.313" bottom plate thickness).

TTI INSPECTIONS – NAVFAC Mitlantic – Hampton Roads IPT ‐ TANK NO. A‐102 2018

PART N: ADDITIONAL COMMENTS, FINDINGS AND OBSERVATIONS

1) The tank is not properly labeled; missing HMIS or NFPA 704 Fire Diamond label (NFPA 30 §

21.7.2.1).

2) The containment area contains vegetation growth and combustible materials. Ground areas should be kept free of trash, weeds, and other unnecessary combustibles (NFPA 30 § 6.9.4).

3) The insulation system is saturated with water which has resulted in corrosion underneath insulation (CUI). Additionally, there is moss, lichen and vegetation growth in insulation jacket seams on the tank roof and shell.

4) The seal between the tank chime and the concrete foundation is showing signs of minor degradation (API Standard 653 § 7.2.3).

5) The exterior coating on the piping system is exhibiting minor to moderate coating failure (API RP 574 § 10.1.6)

6) Tank is equipped with mechanical level gauge, however the tape assembly is broken.

7) An 8‐inch gate valve at the tank shell is not seating properly and allowed for a significant amount of product to enter the tank following cleaning, and during the internal inspection. It is controlling product flow through a 40 foot long crossover pipe to the adjacent Tank A‐101, with another 8‐ inch valve that does not appear to be seated well either.

8) Internal visual inspection and MFL floor scanning identified only minor internal corrosion occurring, with the deepest topside pit measuring 0.115" deep (0.313" bottom plate thickness).

TTI INSPECTIONS – NAVFAC Mitlantic – Hampton Roads IPT ‐ TANK NO. A‐102 2018

PART O: RECOMMENDATIONS & EVALUATIONS

1) Properly label the tank with the appropriate NFPA 704 Diamond Label, or another approved system.

The label shall be located and sized so that it can be easily seen by emergency responders (NFPA 30 § 21.7.2.1).

2) Regularly perform housekeeping and maintenance within the containment dike area in accordance with NFPA 30 and/or local, state and federal requirements (NFPA 30 § 6.9.4).

3) The condition of the insulation is contributing to accelerated exterior corrosion of the tank system.

Corrosion Under Insulation (CUI) was identified on the tank shell and roof plates at test port locations. Insulation was originally installed when these tanks were heated and storing No. 6 Fuel Oil. Insulation is not required for tanks storing No. 2 Fuel Oil. It is recommended that the deteriorating insulation be removed, and the exterior of the tank recoated by a qualified NACE or SSPC coatings contractor. (API RP 575 § 7.27).

4) Maintain the sealant between the tank bottom and the concrete pedestal to prevent water from flowing under the tank bottom (API 653 § 7.2.3).

5) Touch up areas of coating failure on piping as needed. Maintaining the exterior coating will appreciably increase the life of the piping (API RP 574 § 10.1.6).

6) The damaged and non‐functional mechanical level gauge device should be either serviced to restore proper functionality, replaced, or removed from the tank system if no longer in use. Product level is currently monitored in the control room using an electronic differential pressure level sensor.

Although a procedure is in place to relay product levels to notify the filling operator of the pending completion of the tank fill operation at the fill connection, the ability to directly monitor product level at the tank system is recommended. (NFPA 30 § 21.7.1.6.1, Best Management Practice).

7) The 8‐inch gate valve associated with the 40 foot crossover pipe between the fuel tanks should be serviced or replaced (Best Management Practice).

8) Only minor internal corrosion was noted on the tank bottom and shell plates. No action is required at this time.

TTI INSPECTIONS – NAVFAC Mitlantic – Hampton Roads IPT ‐ TANK NO. A‐102 2018

PART P: INSPECTION INTERVALS

IN FOLLOWING (CHECK ALL THAT APPLY):

Previously Determined Inspection Intervals

API Standard 653, Tank Inspection, Repair, Alteration, and Reconstruction

API Standard 510, Pressure Vessel Inspection Code:In‐Service Inspection, Rating, Repair and Alteration

STI Standard SP001, Standard for the Inspection of Aboveground Storage Tanks

CATEGORY 1: CATEGORY 2: CATEGORY 3:

Other (1):

Other (2):

PERIODIC/MONTHLY INSPECTIONS:

Routine In‐Service Inspections are to be conducted by the tank owner’s inspector on a monthly basis.

EXTERNAL INSPECTION:

External Inspections are to be conducted by a Certified Inspector every 5 years (by 6/20/2023).

ULTRASONIC THICKNESS (UT) TESTING:

N/A:

Previously Determined Inspection Interval Date:

UT Testing is to be conducted by a Certified UT Technician every 15 years (by 6/20/2033).

INTERNAL INSPECTION:

N/A:

An internal inspection of this tank system should be performed at the tank owners' earliest convienience. An initial internal inspection should be conducted within ten (10) years from the date of initial service.

Previously Determined Inspection Interval Date:

Internal Inspections are to be conducted by a Certified Inspector every 20 years (by 6/20/2038).

ADDITIONAL INSPECTION REQUIREMENTS:

APPENDIX B:

PHOTO DOCUMENTATION

17-926 Portsmouth Naval Shipyard - Tank A-102 20 June 2018

TANK A-102 EXTERIOR VIEW FROM NORTH

SOUTHWEST EXTERIOR; NOTE MOSS & LICHEN GROWTH ON INSULATION JACKET

8-INCH VALVE (NOT SEATING) & CROSSOVER PIPING TO A-101

(RECOMMEND SERVICE, REPLACEMENT OR REMOVAL)

3’ X 4’ REPAIR INSERT PATCH; FORMER HEATED SUCTION LOCATION

CORROSION UNDER INSULATION AT BASE OF SHELL

TOP HEAD INSULATION IN POOR CONDITION

Photographs of the tank interior and key internal areas of concern were taken on 20 June 2018 by

TTI inspectors using a NAVFAC‐owned camera and were retained by Portsmouth Naval Shipyard for review and vetting by the security, environmental and safety departments. These photos could not be located following the inspection and are consequently not included in this report.

APPENDIX C:

TANK DIAGRAMS

0° (A)

270° (B)

180° (C)

90° (D)

30" X 24" PLATFORM

24" WEIGHTED MANWAY COVER

EMERGENCY RELIEF VENT

6" ATMOSPHERIC MUSHROOM

VENT WITH SCREEN

VAREC LEVEL GAUGE ASSEMBLY

(OUT-OF-SERVICE)

8" FLG-LEVEL SENSOR

24" MANWAY

Ø20'

Top

Scale:

" = 1'-0"

DRAWING TITLE: PROJECT LOCATION:

INSPECTOR:

SCALE:

REVIEWED BY:DRAWN BY:

INSPECTION DATES:

TTI PROJECT NO:

DATE:

FILE:

1253 North Church Street

Moorestown, NJ 08057

(856) 840-8800

(856) 840-8815 Fax www.ttienv.com

NOTES:

A-102

PNS4-BLDG 72

Diagram 1 of 3

Ultrasonic Thickness Data Diagram

9-14-2018

Portsmouth Naval Shipyard

Portsmouth, Maine

\\ttiserver00\Public\TTI\SDC Group\AST Info - PWD-Maine\A-102

6-24-2018

SAN

17-926

AS NOTED

SWN

Ø20'

0° (A)

270° (B)

180° (C)

90° (D)

24" MANWAY

PLATE 2

PLATE 1

PLATE 3

PLATE 4

A

D

D

B

B

E

E

A

C

C

C

C

B

E

A

A

D

B

0.115" PIT

VAREC FLOAT LEVEL

ASSEMBLY WIRES & FLOAT

2" X 2" EXISTING LAP PATCH

D

E

MODERATE GENERAL CORROSION &

PITTING-CORROSION PRODUCT

GENERAL MINOR CORROSION

Bottom

Scale:

" = 1'-0"

DRAWING TITLE: PROJECT LOCATION:

INSPECTOR:

SCALE:

REVIEWED BY:DRAWN BY:

INSPECTION DATES:

TTI PROJECT NO:

DATE:

FILE:

1253 North Church Street

Moorestown, NJ 08057

(856) 840-8800

(856) 840-8815 Fax www.ttienv.com

NOTES:

A-102

PNS4-BLDG 72

Diagram 2 of 3

Ultrasonic Thickness Data Diagram

9-14-2018

Portsmouth Naval Shipyard

Portsmouth, Maine

\\ttiserver00\Public\TTI\SDC Group\AST Info - PWD-Maine\A-102

6-24-2018

SAN

17-926

AS NOTED

SWN

B = CRITICAL MONITORING LOCATION

0° (A) 270° (B) 180° (C) 90° (D)

24" HATCH MANWAY

62'-10"

28'

A

B

D

E

C

PLATE 2

A

B

D

E

C

PLATE 3

A

B

D

E

C

PLATE 1

1" THERMOWELL

48" X 36" INSERT PATCH

(NOZZLE REMOVED)

2" CPL-PLUG

3" FLG-RE-CIRCULATION (OUT-OF-SERVICE)

8" FLG-EQUALIZER/FILL (OUT-OF-SERVICE)

3" FLG-FILL FROM TRUCK OFFLOADING

2" WATER DRAW OFF

2" CPL-PLUG

4" FLG-HI-LEVEL SENSOR

8" FLG-4" AFFF FIRE SUPPRESSION

6"FLG-3" FUEL TRANSFER/SUCTION

& LEVEL SENSOR

EXTERNAL

FIXED

STAIRS

INTERNAL

FIXED

LADDER

Bottom

Scale:

" = 1'-0"

DRAWING TITLE: PROJECT LOCATION:

INSPECTOR:

SCALE:

REVIEWED BY:DRAWN BY:

INSPECTION DATES:

TTI PROJECT NO:

DATE:

FILE:

1253 North Church Street

Moorestown, NJ 08057

(856) 840-8800

(856) 840-8815 Fax www.ttienv.com

NOTES:

A-102

PNSY-BLDG 72

Diagram 3 of 3

Ultrasonic Thickness Data Diagram

B = CRITICAL MONITORING LOCATION

9-14-2018

Portsmouth Naval Shipyard

Kittery, Maine

\\ttiserver00\Public\TTI\SDC Group\AST Info - PWD-Maine\A-102

06-20-2018

SAN

17-926

AS NOTED

APPENDIX D:

ULTRASONIC THICKNESS DATA REPORTS

SURVEY MEASUREMENTS

Survey Name PSNY A102 SHELL 1 COR

Survey Type 2D GRID Survey Mode THICKNESS

Survey Date 6/20/2018 2:32:00 PM Erase Protection OFF

Survey Description

Location Note

Inspector ID

Point

ID

Thickness Units Flags Setup Notes Modified

1A 0.263 IN M----F 0002 False

1B 0.265 IN M----F 0002 False

1C 0.273 IN M----F 0002 False

1D 0.292 IN M----F 0002 False

1E 0.284 IN M----F 0002 False

2A 0.274 IN M----F 0002 False

2B 0.272 IN M----F 0002 False

2C 0.273 IN M----F 0002 False

2D 0.284 IN M----F 0002 False

2E 0.284 IN M----F 0002 False

3A 0.264 IN M----F 0002 False

3B 0.264 IN M----F 0002 False

3C 0.262 IN M----F 0002 False

3D 0.266 IN M----F 0002 False

3E 0.268 IN M----F 0002 False

Report Date: 7/6/2018 Page: 1 of 1

Survey Name PSNY A102 LAD

Survey Type SEQUENTIAL Survey Mode THICKNESS

Survey Date 6/20/2018 2:37:00 PM Erase Protection OFF

Survey Description

Location Note

Inspector ID

Point

ID

Thickness Units Flags Setup Notes Modified

01 0.194 IN E----F 0002 False

02 0.209 IN E----F 0002 False

03 0.208 IN E----F 0002 False

04 0.201 IN E----F 0002 False

05 0.201 IN E----F 0002 False

06 0.204 IN E----F 0002 False

07 0.213 IN E----F 0002 False

08 0.205 IN E----F 0002 False

09 0.198 IN E----F 0002 False

10 0.000 IN a----T 0001 False

11 0.000 IN a----T 0001 False

12 0.000 IN l----F 0002 False

Survey Name PSNY A102 BOT

Survey Type 2D GRID Survey Mode THICKNESS

Survey Date 6/20/2018 2:07:00 PM Erase Protection OFF

Survey Description

Location Note

Inspector ID

Point

ID

Thickness Units Flags Setup Notes Modified

A1 0.348 IN M----F 0002 False

B1 0.353 IN M----F 0002 False

C1 0.351 IN M----F 0002 False

D1 0.373 IN M----F 0002 False

E1 0.374 IN M----F 0002 False

A2 0.343 IN M----F 0002 False

B2 0.363 IN M----F 0002 False

C2 0.341 IN M----F 0002 False

D2 0.335 IN M----F 0002 False

E2 0.342 IN M----F 0002 False

A3 0.331 IN M----F 0002 False

B3 0.307 IN M----F 0002 False

C3 0.333 IN M----F 0002 False

D3 0.315 IN M----F 0002 False

E3 0.335 IN M----F 0002 False

A4 0.333 IN M----F 0002 False

B4 0.295 IN M----F 0002 False

C4 0.344 IN M----F 0002 False

D4 0.344 IN M----F 0002 False

E4 0.343 IN M----F 0002 False

Survey Name PSNY A102 TOP

Survey Type SEQUENTIAL Survey Mode THICKNESS

Survey Date 6/20/2018 3:32:00 PM Erase Protection OFF

Survey Description

Location Note

Inspector ID

Point

ID

Thickness Units Flags Setup Notes Modified

1 0.270 IN E----F 0002 False

2 0.269 IN E----F 0002 False

3 0.262 IN E--G-F 0003 False

4 0.256 IN E--G-F 0003 False

5 0.264 IN E--G-F 0003 False

6 0.250 IN E--G-F 0004 False

APPENDIX E:

SETTLEMENT SURVEY DATA

ACTUAL RADIAL DISPLACEMENT DUE TO SHELL SETTLEMENT VS. PERMISSIBLE LIMITS ALLOWED PER API 653

Column No. 1 2 3 4 5 6 7 8 9 10 11 12

Description

Settlement readings (ft.)

Relative settlement

Angle of point from origin

Cosine of angle

Sine of angle

Planar tilt best-fit cosine curve

DIFFERENTIAL

SETTLEMENT

Finite difference in (ft.)

Distance around tank

Location is within the permissible limits of API 653

Appendix B Variable Si si 0i cos 0i sin 0i Si cos 0i Si sin 0i a1 cos 0i + b1 sin 0i ui ui - (ui+1 + ui-1)/2 cos(3) sin(3) (1) x (4) (1) x (5) a1 x (4) + b1 x (5) (2) - (8)

0.00

A 3.35 0.00 0.00 1 0 3.35 0.00 0.00 0.00 0.00 0.0 TRUE

B 3.35 0.00 0.79 0.71 0.71 2.37 2.37 0.00 0.00 0.00 7.9 TRUE

C 3.35 0.00 1.57 0.00 1.00 0.00 3.35 0.00 0.00 0.00 15.7 TRUE

D 3.35 0.00 2.36 -0.71 0.71 -2.37 2.37 0.00 0.00 0.00 23.6 TRUE

E 3.35 0.00 3.14 -1.00 0.00 -3.35 0.00 0.00 0.00 -0.01 31.4 TRUE

F 3.36 0.01 3.93 -0.71 -0.71 -2.38 -2.38 0.00 0.01 0.01 39.3 TRUE

G 3.35 0.00 4.71 0.00 -1.00 0.00 -3.35 0.00 0.00 -0.01 47.1 TRUE

H 3.35 0.00 5.50 0.71 -0.71 2.37 -2.37 0.00 0.00 0.00 55.0 TRUE

0.00 column sum 26.81 0.00 21.99 0 0 -0.01 -0.01 ao= 3.35 a1= 0.00 b1= 0.0

N= 8 Sum of Si = 26.81

D= 20

S = MAXIMUM PERMISSIBLE DEFLECTION, IN FEET (OUT-OF PLANE DISTORTION)

L = ARC LENGTH BETWEEN MEASUREMENT POINTS IN FEET

Y = YIELD STRENGTH, IN PSI (USE 30,000, IF UNKNOWN)

E = YOUNG'S MODULUS, IN PSI (29,000,000)

H = TANK HEIGHT IN FEET

L2= 7.85 S= (11)(L2)(Y) S= 0.0125 Feet Y= 30,000 (2)(E)(H) or E= 29,000,000 S= 0.15 Inches H= 28 or

S= 0.38 Centimeters

External Shell Settlement Plot

Tank Location: Portsmouth Naval Shipyard, Kittery, ME Tank No.: Tank A-102

Tank Diameter (ft.): 20 Tank Circumference (ft.): 62.83

DATA POINT A (Manway) B C D E F G H A (Manway) Distance around Shell (ft.) 0.00 7.85 15.71 23.56 31.42 39.27 47.12 54.98 62.83 Normalized Settlement Data (in.) 0.00 0.00 0.00 0.00 0.00 -0.12 0.00 0.00 0.00

-0.14

-0.12

-0.10

-0.08

-0.06

-0.04

-0.02

0.00

0.02

0.00 7.85 15.71 23.56 31.42 39.27 47.12 54.98 62.83

Se ttl em en t ( In

Distance Around Shell (Ft.)

12/18/2018 TTI Inspections, A Division of TTI Environmental, Inc.

Ø20'

3.29'

A

3.35'

3.35'

B

C

D

E

3.35'

3.35'

F

G

H

Settlement Survey

Scale:

" = 1'-0"

DRAWING TITLE: PROJECT LOCATION:

INSPECTOR:

SCALE:

REVIEWED BY:DRAWN BY:

INSPECTION DATES:

TTI PROJECT NO:

DATE:

FILE:

1253 North Church Street

Moorestown, NJ 08057

(856) 840-8800

(856) 840-8815 Fax www.ttienv.com

NOTES:

9-14-2018

A-102

PNS4-BLDG 72

Settlement Survey Data Diagram

Portsmouth Naval Shipyard

Portsmouth, Maine

\\ttiserver00\Public\TTI\SDC Group\AST Info - PWD-Maine\A-102

6-24-2018

SAN

17-926

AS NOTED

APPENDIX F:

MINIMUM ACCEPTABLE SHELL PLATE THICKNESS EQUATIONS

Minimum Acceptable Shell Plate Thickness Equation

API 653 Section 4.3.3.1

a) Minimum acceptable thickness for an entire shell course

G = 0.89 specific gravity of stored product

E = 0.85 joint efficiency SL = 23600 lbf/in.2

SU = 26000 lbf/in.2

D = 20.0 ft tank diameter (max. 200 ft.)

Hl = 28.00 ft maximum design liquid level

Shell Course Height (ft) Bottom Ht. (H) tmin (in.)

1 (Bottom) 9.33 28.00 0.062

2 9.33 18.67 0.041 3 9.33 9.34 0.017 4 0.00 0.01 N/A 5 0.00 0.01 N/A 6 0.00 0.01 N/A tmin =

2.6 (H-1)DG

SE

1st & 2nd course maximum allowable stress (23,600 if unknown) upper courses maximum allowable stress (26,000 if unknown)

Reference: API 653 Section 4.3.3.1 1 of 1

APPENDIX G:

MINIMUM ACCEPTABLE BOTTOM PLATE THICKNESS EQUATIONS

Minimum Acceptable Thickness for Tank Bottom Plate Equation (Outside of the Critical Zone)

Or = 20.0 years Original Plate Thickness = 0.313 inches

RTbc = 0.295 inches Age of Tank = 41 years

RTip = 0.198 inches Maximum Pit Depth Allowed = 0.115 inches

StPr = 0.0028 inches/year .

UPr = 0.0004 inches/year

MRT = 0.133 inches

0.10

0.05

0.05

Tank bottom/foundation design with no means for detection and containment of a bottom leak.

Tank bottom/foundation design with means to provide detection and containment of a bottom leak.

Applied tank bottom reinforced lining, >0.05 in. thick, in accordance with API RP 652.

Minimum Bottom Plate Thickness at Next Inspection (in.) Tank Bottom/Foundation Design

API 653 Table 4.4 - Bottom Plate Minimum Thickness

Note: MRT must meet the requirements of Table 4.4 below.

MRT = (Minimum of RTbc or Rtip) - Or(StPr + Upr)

Or = in-service interval of operation (years to next internal inspection) not to exceed 20 years

RTbc = minimum remaining thickness from bottom side corrosion after repairs

RTip = minimum remaining thickness from internal corrosion after repairs

UPr = maximum rate of corrosion on the bottom side. To calculate the corrosion rate, use the minimum remaining thickness after repairs. UPr = 0 for areas that have effective cathodic protection.

StPr = maximum rate of corrosion not repaired on the top side. StPr = 0 for coated areas of the bottom. The expected life of the coating must equal or exceed Or to use StPr.

Note: For areas of a bottom that have been scanned by the magnetic flux leakage (or exclusion) process, and do not have effective cathodic protection, the thickness used for calculating UP r must be the lesser of the MFL threshold or the minimum thickness of corrosion areas that are not repaired. The MFL threshold is defined as the minimum remaining thickness to be detected in the areas inspected.

Areas of bottom side corrosion that are repaired should be evaluated with the corrosion rate for the repaired area unless the cause of corrosion has been removed. The evaluation is done by using the corrosion rate of the repaired area for UPr, and adding the patch plate (if used) thickness to the term "Minimum of RT bc or RTIP."

Reference: API 653 Section 4.4.5 and Table 4.4

Minimum Acceptable Thickness for Tank Bottom Plate Equation (Within the Critical Zone)

Or = 20.0 years Original Plate Thickness = 0.313 inches

RTbc = 0.295 inches Age of Tank = 41 years

RTip = 0.250 inches Maximum Pit Depth Allowed = 0.063 inches

StPr = 0.0015 inches

UPr = 0.0004 inches

MRT = 0.210 inches

4.4.5.4

1/2 the Original Bottom Plate Thickness = 0.157

Note: For areas of a bottom that have been scanned by the magnetic flux leakage (or exclusion) process, and do not have effective cathodic protection, the thickness used for calculating UP r must be the lesser of the MFL threshold or the minimum thickness of corrosion areas that are not repaired. The MFL threshold is defined as the minimum remaining thickness to be detected in the areas inspected.

Areas of bottom side corrosion that are repaired should be evaluated with the corrosion rate for the repaired area unless the cause of corrosion has been removed. The evaluation is done by using the corrosion rate of the repaired area for UPr, and adding the patch plate (if used) thickness to the term "Minimum of RT bc or RTIP."

Unless a stress analysis is performed, the minimum bottom plate thickness in the critical zone of the tank bottom defined in 9.10.1.2 shall be the smaller of one-half the original bottom plate thickness (not including the original corrosion allowance) or 50 % of tmin of the lower shell course per 4.3.3.1 but not less than 0.1 in. Isolated pitting will not appreciably affect the strength of the plate.

Note: MRT must meet the requirements of Section 4.4.7.4

MRT = (Minimum of RTbc or Rtip) - Or(StPr + Upr) MRT = minimum remaining thickness at the end of interval Or.

Or = in-service interval of operation (years to next internal inspection) not to exceed 20 years

RTbc = minimum remaining thickness from bottom side corrosion after repairs

RTip = minimum remaining thickness from internal corrosion after repairs

UPr = maximum rate of corrosion on the bottom side. To calculate the corrosion rate, use the minimum remaining thickness after repairs. UPr = 0 for areas that have effective cathodic protection.

StPr = maximum rate of corrosion not repaired on the top side. StPr = 0 for coated areas of the bottom. The expected life of the coating must equal or exceed Or to use StPr.

Reference: API 653 Section 4.4.7 and Table 6-1

APPENDIX H:

INSPECTION METHODOLOGY

Aboveground Storage Tank Testing Methodology Overview

The following methodologies were utilized by TTI personnel, as applicable, in the inspections performed under this contract:

Visual Inspection

A comprehensive visual inspection of the interior and exterior surface of the tank was performed consistent with API Standard 653, STI Standard SP001 and other applicable codes and standards. These inspections included evaluation system tightness, structural soundness, corrosion, wear, foundation weakness and operability. In addition to these requirements, visual inspections include an evaluation of the condition of the tank’s paint coatings, ancillary equipment and appurtenances.

Shell Settlement Survey

Settlement measurements will be obtained utilizing a tripod mounted CST/Berger model LMH-CU self-leveling, rotating laser level which has a beam accuracy of 3/32 inch at 100 feet. Data obtained from the Shell Settlement Survey will be utilized to determine if uniform settlement, rigid body tilting and/or out-of-plane settlement have occurred.

Internal Settlement Survey (depressions or bulges)

Settlement measurements of the bottom plates will be obtained utilizing a tripod mounted CST/Berger model LMH- CU self-leveling, rotating laser level which has a beam accuracy of 3/32 inch at 100 feet. Bulges and/or depressions will be measured in order to determine if they exceed permissible limits.

Ultrasonic Thickness Testing

Ultrasonic Thickness (UT) Testing was performed utilizing a handheld, advanced Ultrasonic Thickness gauge with a dual-element transducer appropriate for the material being tested, and capable of accurately reading through paint or surface coatings without their removal. A water-based ultrasonic couplant was used at each reading location.

Ultrasonic A-scans were referenced by the inspector at each thickness testing location to ensure thickness reading accuracy. Ultrasonic B-scans were acquired if deemed appropriate by the inspector. Prior to data acquisition, the gauge was calibrated to a certified reference block representative of the material being tested.

Ultrasonic thickness gauges are calibrated in accordance with the manufacturer recommendations at each of the following times:

Start of each new work day

Start of each 8 hour shift

Each time the probe is changed

Each time a new test area is being evaluated

In the event the operator believes the unit is not functioning properly

Calibration is performed on-site, and with test blocks at the same temperature as the test specimen in order to minimize errors due to temperature variations.

Shell Plates

Thickness measurements shall be taken where safely accessible from the lower shell, at a frequency of five (5) readings per plate along the first (bottom) shell course and three (3) readings per plate along the second course.

Higher courses will be accessed from the fixed stairs or ladder, at a frequency of four (4) readings per course. If internal corrosion is suspected, additional readings along upper courses may be specified by the inspector or tank owner/operator, and may require the use of an aerial manlift or scaffolding, not included in this proposal.

Roof Plates

Thickness measurements of the tank roof shall be taken at a frequency of two (2) per roof plate.

Bottom Plates

Thickness measurements of the tank bottom shall be taken at a frequency of five (5) per bottom plate.

There may be certain deviations from this protocol due to inaccessibility of specific areas of the tank.

Magnetic Flux Leakage Tank Floor Plate Scanning

A magnetic flux leakage (MFL) inspection will be performed by a qualified operator on 100% of the bottom plates utilizing a MFE MK II 2412 Tank Floor Scanner or equivalent. Prior to scanning, the system was calibrated utilizing a mild carbon steel test plate with known indications of 20%, 30%, 40%, 60% and 80% through holes. The unit was calibrated to identify indications of 30% loss or greater. The unit was moved over each plate in overlapping scans in order to achieve maximum coverage. All indications will be marked and confirmed using A-Scan or B-Scan Ultrasonic Thickness methods.

APPENDIX I:

INSPECTOR CERTIFICATIONS