Attachment K.3- Tank 12186 Inspection Report.pdf

US Army Corps of Engineers

Omaha District

API 653 In-Service

Inspection Report

Joint Base Lewis-McChord, Washington

Facility 12186

Tank HT-3

US Army Corps of Engineers Center of Expertise for Petroleum, Oils and Lubricants

USACE POL-TCX

5 July 2017

API 653 In-Service Inspection Report Joint Base Lewis-McChord, Washington

Table of Contents

ACRONYMS AND ABBREVIATIONS

GENERAL SUMMARY

THIS INSPECTION

PREVIOUS INSPECTION DATES

RECOMMENDED FUTURE INSPECTION DATES

GENERAL TANK INFORMATION

A. GENERAL PROJECT INFORMATION

1. API 653 Inspection

2. Site Information

B. TANK INSPECTION COMMENTS

1. Tank Construction

2. Tank Foundation

3. Tank Shell

4. Tank Appurtenances

5. Tank Coating

6. Tank Piping System

7. Fire Protection System

8. Secondary Containment

C. FINDINGS AND RECOMMENDATIONS

1. Mandatory Repairs per API 653, UFC 3-460-01, or AW 78-24-27 Standards

2. Significant Findings per API 653, UFC 3-460-01, or AW 78-24-27 Standards

3. Repairs to Fully Comply with API 653, UFC 3-460-01, or AW 78-24-27 Standards

4. Recommended Repairs as Part of Regular Maintenance

APPENDIX A: ENGINEERING CALCULATIONS AND DRAWINGS

SHELL ROUNDNESS SURVEY & SETTLEMENT

SHELL SETTLEMENT SURVEY

SHELL THICKNESS CALCULATIONS

SHELL/ROOF ULTRASONIC THICKNESS MEASUREMENTS

TANK DRAWINGS

OSHA ACCESS STRUCTURE REPORT

APPENDIX B: API 653 CHECKLISTS FOR TANK INSPECTIONS

APPENDIX C: PHOTOGRAPHS

ACRONYMS AND ABBREVIATIONS

API American Petroleum Institute

ASME American Society of Mechanical Engineers

ASNT American Society of Non-Destructive Testing

ATG Automatic Tank Gauge

BBL Barrel

CFR Code of Federal Regulations

CP Cathodic Protection

DFT Dry Film Thickness

FAC Facility

HLA High Level Alarm

HLCV High Level Control Valve

HHLA High-High Level Alarm

LLA Low Level Alarm

LLLA Low-Low Level Alarm

MFL Magnetic Flux Leakage

MFE Magnetic Flux Exclusion

MT Magnetic Particle Testing

NA Not Applicable

NACE National Association of Corrosion Engineers

NDT Non-Destructive Testing

NFPA National Fire Protection Association

PSI Pounds per Square Inch

PT Penetrant Testing

P/V Pressure/Vacuum

RP Recommended Practice

PST Product Saver Tank

RT Radiography Testing

TML Thickness Measurement Location

TRV Thermal Relief Valve

UFC Unified Facilities Criteria

UFGS Unified Facilities Guide Specifications

UT Ultrasonic Testing

VT Visual Testing

GENERAL SUMMARY

Austin Brockenbrough & Associates, LLP (Brockenbrough) was retained by Omaha District USACE under Contract No. W9128F-12-D-0006 Delivery Order No. 0024 to perform API Standard 653 In-Service Inspections. As required by this task, Brockenbrough executed a tank inspection site visit to Joint Base Lewis-McChord, located in Tacoma, Washington. An API 653 In-Service (visual external) Inspection was conducted for Tank Facility 12186 (Tank HT-

3) on March 02, 2017. This inspection was performed in accordance with API Standard 653, “Tank Inspection, Repair, Alteration, and Reconstruction,” and the referenced contract. The confined space between the internal floating roof and the fixed roof was not entered during the inspection. All observations made during this in-service (visual external) inspection were made from the exterior of the tank.

Tank Facility 12186 is a 43-foot and 6-inch diameter by 42-foot and 3-inch tall, single wall, vertical, field erected tank with a nominal storage capacity of 10,000 barrels of jet fuel (F-24). The tank was fabricated by Morse Construction Group, Inc. in 2000 to API Standard 650, 9th Edition. Secondary containment is provided by a concrete containment area with sloped concrete dike walls. The tank is built on a buried reinforced concrete ringwall foundation. Since there are no as-built drawings of the tank available at this time, the presence of a release prevention barrier could not be confirmed. However, the four foundation drains suggest that the tank is at least equipped with a concrete slab that could act as a barrier. Also, the tank is equipped with a typical under tank galvanic cathodic protection system. Details of the tank construction and appurtenances are included in Section ‘B’.

There are no mandatory repairs noted that need immediate attention. Additional noted deficiencies are discussed in more detail in Section ‘C’, and should be addressed in a timely manner. Photographs of the tank are included in Appendix ‘C’.

The next API Standard 653 In-Service (visual external) Inspection should be performed by an API 653 Inspector by March 2022. The next ultrasonic thickness inspection of the shell should be performed by March 2032. A previous out-of-service inspection report indicates that the tank was inspected in November 2010. While the current version of UFC 3-460-03 requires the next out-of-service inspection occur after 10 years, an upcoming revision allows the frequency to be extended as determined by a certified API 653 tank inspector. The tank was last inspected in November 2010 and tank bottom thickness calculations from the previous out-of-service inspection report shows 20 years to next inspection. Therefore, we recommend that the next API Standard 653 Out-Of-Service (internal and external) Inspection should be performed by November 2030. This inspection should include an external and internal inspection and include an examination of the tank bottom by magnetic flux leakage (MFL or MFE) technology and an ultrasonic thickness inspection of the tank shell. This inspection should include a thorough code compliance evaluation as well.

THIS INSPECTION

API In-Service (External) Inspection Date: 02 March 2017 Equipment Used: Ultrasonic Thickness Gauge Manufacturer: NDT Systems Model Number: Nova TG110-DL Calibration Method: Calibration Block Inspector(s): Jeffrey W. King

Survey Equipment Automatic Level: Topcon AT-BS Calibration: June 2016

Robotic/Reflectorless Total Station: Topcon QS X-Trac 8 Calibrated: December 2015

Field Data Collector: Topcon FC-2500

PREVIOUS INSPECTION DATES

API Out-of-Service (Internal) Inspection Date: November 2010 API In-Service (External) Inspection Date: Not Available

RECOMMENDED FUTURE INSPECTION DATES

API Out-of-Service (Internal) Inspection Date: November 2030 API Ultrasonic Thickness Inspection of Shell Date: March 2032 API In-Service (External) Inspection Date: March 2022

It may be more cost effective to perform the internal inspection to coincide with the UT inspection. A reasonable compromise may be to perform both inspections, and the repairs recommended in the previous inspection report, in 2031.

Jeffrey W. King, PE Mechanical Engineer API 653 Inspector No. 54102

GENERAL TANK INFORMATION

ITEM DESCRIPTION

Owner U.S. Air Force

Location Joint Base Lewis-McChord

Facility Number Facility 12186

Tank Number Tank HT-3

State / Country Washington / U.S.A.

City Tacoma

Inspection Date March 02, 2017

Tank Manufacturer Morse Construction Group, Inc.

Design Standard API Std 650 9th Edition

Date of Construction 2000

Tank Contents Jet Fuel (F-24)

Tank Serial Number 2425-M-6225-01

Tank Diameter 43’ – 6”

Shell Height 42’ – 3”

Product Height 38’ – 0” (Safe Fill Height)

Tank Capacity 10,000 barrels (Nominal Capacity)

Foundation Buried Reinforced Concrete Ringwall

Construction

Bottom Lap-welded cone down (Per previous inspection report)

Shell (5) butt-welded shell courses

Floating Roof Aluminum Honeycomb Pan

Fixed Roof Self-supported, Lap-welded cone up

Material

Bottom Carbon steel

Shell A36 Carbon steel (Per tank data plate)

Floating Roof Aluminum

Fixed Roof Carbon steel

Cathodic Protection Galvanic Cathodic Protection System

Interior Coating System Epoxy-Epoxy-Epoxy (assumed)

Exterior Coating System Epoxy-Epoxy-Polyurethane (assumed)

Level Gauging Varec Tape Level Gauge; Enraf Automatic Tank Gauge (ATG)

Overfill Protection High Level Control Valve; Independent High-high, High, & Low Level Alarm

Piping Receipt 8” Stainless Steel

Issue 12” Stainless Steel

Low Suction 4” Stainless Steel

AFFF N/A N/A

Water Draw-Off 3/4” Stainless Steel

Level Alarms Independent High-high, High, & Low Level Alarms

Type of Internal Floating Roof Aluminum Honeycomb Pan

A. GENERAL PROJECT INFORMATION

1. API 653 Inspection

This project will perform API 653 Inspections of various tanks at facilities throughout the United States.

Additional consideration is given to federal, state, and local regulations as well as applicable military criteria and general industry standards.

For Tank Facility 12186, an API Standard 653 In‐service (visual external) Inspection was performed.

This inspection also included an ultrasonic inspection of the shell and roof plates, a foundation settlement survey, and a shell roundness assessment.

2. Site Information

On March 02, 2017 Brockenbrough performed an API 653 In‐Service (visual external) Inspection of

Tank Facility 12186 located at Joint Base Lewis-McChord. Joint Base Lewis-McChord is a U.S. military installation home to I Corps and 62nd Airlift Wing located 9.1 miles (14.6 km) south-southwest of

Tacoma, Washington under the jurisdiction of the United States Army Joint Base Headquarters, Joint

Base Lewis–McChord. The facility is an amalgamation of the United States Army's Fort Lewis and the

United States Air Force's McChord Air Force Base. Joint Base Lewis–McChord is a training and mobilization center for all services and is the only Army power projection base west of the Rocky

Mountains. The strategic location of the base provides Air Force units with the ability to conduct combat and humanitarian airlift with the C-17 Globemaster III.

B. TANK INSPECTION COMMENTS

1. Tank Construction

Tank Facility 12186 is a nominal 10,000 barrel, 43-foot and 6-inch diameter by 42-foot and 3-inch tall, F-24, aboveground vertical storage tank. Per the information on the tank data plate, the tank was constructed by Morse Construction Group, Inc. to API 650 design standard in 2000.

2. Tank Foundation

The tank rests on a buried reinforced concrete ringwall foundation. Since there are no as-built drawings of the tank available at this time, the presence of a release prevention barrier could not be confirmed. However, the four foundation drains suggest that the tank is at least equipped with a concrete slab that could act as a barrier. The foundation was visually evaluated during the inspection for broken concrete, spalling, cracks, and vegetation against the bottom of the tank. The non-shrink grout underneath the tank appears to have failed and some spalling was observed. Mold and algae growth were found primarily on the tank bottom extension and on the grout. Also, minor vegetation was observed growing against the tank bottom. A shell settlement survey was performed during the inspection in accordance with Appendix B of API Standard 653 and was found to be acceptable.

Settlement results are listed in Appendix A.

3. Tank Shell

The vertical and cylindrical shell consists of five butt‐welded courses. The exterior of the shell was visually inspected and evaluated for plumbness, roundness, peaking and banding. The coating was also evaluated for deterioration.

a. Shell Plumbness, Roundness, Peaking, and Banding

The exterior of the shell was visually inspected and evaluated for plumbness, roundness, peaking and banding.

1) API 650, section 7.5.2 allows a maximum out of plumb of the top of the shell relative to the tank bottom of 1/200 the height of the shell, a difference of 2-1/2 inches for this 42-foot and 3-inch tall tank. The maximum measured out-of-plumbness was 1-3/16 inches away from the center of the tank measured on the north east. The out-of-plumbness of the shell is within the tolerance that is allowed by API 650.

2) The shape of the shell appears to exceed the allowable API Standard 650 tolerance of plus or minus 3/4-inch of shell radius, as measured using laser surveying methods. Based on the circumference of the shell measured near the bottom, the radius of the shell should be 21 feet and 9 inches. However, the measured radius of the shell varies at the bottom from 21 feet and

9-13/16 inches in the north to 21 feet and 8-5/16 inches in the west. Also, the measured radii of the shell, varies near the top from 21 feet and 9-15/16 inches in the northeast and to 21 feet and 8-1/2 inches in northwest. The bottom and top of the shell are only slightly out of tolerance for a new tank. Since the shell did not appear to be significantly distorted and the out-of-roundness does not appear to be detrimental to the structural integrity of the tank, no action is required or recommended at this time.

3) While some minor peaking and banding of the butt-welded shell seams was observed, the peaking and banding appear to be within limits allowed by API 650.

b. Shell Coatings

Minor coating failure and corrosion were observed on the tank bottom extension and on tank anchor bolts. Mold and algae growth were also found primarily on the tank bottom extension, the grout, and upper shell courses. However, the exterior shell coating shows no signs of significant deterioration. As the tank is used to store oil and the interior is coated with epoxy, deterioration of the interior of the shell since the previous inspection was performed is extremely unlikely.

c. Shell Ultrasonic Thickness Measurements

The ultrasonic thickness measurements of the shell indicate the shell has more than 30 years of remaining life. API 653 recommends ultrasonic thickness measurements of the shell be taken at least every 15 years.

4. Tank Appurtenances

a. Tank Roof

The tank is constructed with a self-supported lap-welded fixed cone roof with an internal honeycomb floating pan. The coating system on the tank roof and appurtenances was found to be in good condition.

b. Venting

This tank features a 48-inch diameter primary vent and is equipped with four roof-mounted perimeter vents/inspection hatches. These vent/hatches provide adequate venting capacity based on the size of the tank. However, the perimeter vents/hatches could not be inspected since the safety chain links were painted over the inspection hatch covers and also, the hatch covers were painted shut. The tank is also equipped with four overflow vents attached to the tank shell.

c. Gauging

The tank’s Enraf ATG is installed through an 8-inch nozzle mounted on the tank roof. The tank has a 6-inch manual gauging/sampling well installed through the 36-inch roof manhole. The tank also has a Varec tape level gauge whose reading aligns closely with the Enraf ATG reading. However, heavy condensation in the interior of the Varec sight glass had obscured the level gauge reading.

d. Level Alarms

The low and high level alarm chambers are mounted on the exterior of the tank shell. The tank is equipped with low, high and high-high level alarms independent of the tank gauging system.

e. Stairs and Platforms

The tank’s steel roof is accessible by a circumferential stairway mounted on the shell of the tank.

The coating system on the circumferential stairway appeared to be good condition overall with minor coating failure and corrosion observed on the stairway treads, handrails, and vertical supports. The width and rise of the stairway steps and the height of the handrails appear to be in general compliance with OSHA criteria.

f. Grounding and Bonding

There are four grounding cables connected to ground lugs welded to the tank shell.

5. Tank Coating

The interior coating system of the tank is assumed to be epoxy-epoxy-epoxy. The external coating system appeared to be a standard military coating system (epoxy-epoxy-polyurethane). Minor coating failure and corrosion were observed on the tank bottom extension, anchor bolts, shell manhole nuts and bolts, etc. There was some mold and algae growth observed on the tank bottom extension and upper shell courses.

6. Tank Piping System

Fuel is received through 8‐inch carbon steel piping from the bulk transfer line and local off-load station and is issued through a 12-inch stainless steel piping to the hydrant loop and adjacent truck fillstands.

7. Fire Protection System

There are two fire hydrants noted within 300 feet of this tank.

8. Secondary Containment

Secondary containment is provided by a concrete containment area with sloped concrete dike walls.

The secondary containment was visually evaluated during the inspection. The top of the earthen secondary containment berm has a flat section of two feet or more and is properly sloped in accordance with NFPA 30. The majority of the joint sealant in the containment area has been replaced recently.

However, due to shortage of funding and weather constraints, this project has been stalled. Organic growth was observed in several locations inside the secondary containment. The containment is of sufficient size to contain a total tank loss.

C. FINDINGS AND RECOMMENDATIONS

Tank Facility 12186 was found to be in generally good condition. The tank is fully serviceable. However, there were also several items observed that are not in full compliance with federal, state, and local codes or military criteria.

1. MANDATORY REPAIRS per API 653, UFC 3-460-01, or AW 78-24-27 Standards

Mandatory repairs represent items that require immediate attention, in order to prevent imminent risk to system operators, equipment integrity, or the adjacent environment. The tank should remain out of service until these repairs are completed. No mandatory repairs are required to be performed.

2. SIGNIFICANT FINDINGS per API 653, UFC 3-460-01, or AW 78-24-27 Standards

The following information identifies the significant findings found during the tank inspection.

a. Repair Coating System on Tank and Tank Appurtenances

OBSERVATION: Localized coating failure and corrosion was observed on the tank bottom extension, anchor bolts, shell manhole nuts and bolts, etc. Also, minor coating failure and corrosion observed on the stairway treads, handrails, and vertical supports.

CODE REFERENCE: UFC 3-460-03, Section 8-3.10, requires the exterior of fuel storage tanks and appurtenances to be coated.

RECOMMENDATION: Remove corrosion from all the isolated areas of deterioration. Clean and prep all the areas that require coating repairs and apply a compatible coating system that meets military criteria. The nuts and bolts should be removed and replaced with corrosion resistant nuts and bolts.

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Sticky Note POL-MCX: Perform as part of regular maintenance.

b. Replace the Grout under the Tank Bottom Extension

OBSERVATION: The non-shrink grout underneath the tank bottom extension is severely deteriorated and has failed. This grout has cracked and spalled in several locations around the perimeter of the tank.

CODE REFERENCE: UFC 3-460-03, Section 8-4.10 B, requires the seal to be maintained in good working order to prevent corrosion of the underside of the tank bottom.

RECOMMENDATION: Replace the non-shrink grout underneath the tank bottom extension to comply with DoD Standard Design AW 78-24-27 Tank Standards for anchored tank bottom-to-foundation grouting.

c. Replace Joint Sealant within the Containment Area

OBSERVATION: The expansion joint seals within the containment area have deteriorated and failed.

There is a project already in place to replace all the expansion joint sealant within the containment area. The majority of the expansion joint sealant between dike concrete wall slabs have already been replaced as part of this project. However, due to shortage of funding and weather constraints, this project has been stalled.

CODE REFERENCE: UFC 3-460-01, 8-14.5 requires reinforced concrete dikes to resist and contain the full hydrostatic load when filled to capacity. Failed joint sealant, cracking and spalls may prevent the full capacity from being contained.

RECOMMENDATION: If the existing project to replace all the expansion joint sealant in the containment area does not move forward, replace all the remaining joint sealant within the dike containment area. Remove and repair the cracked and spalling concrete areas.

POL-MCX: Can be performed as part of regular maintenance.

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d. Upgrade Thermal Relief Piping

OBSERVATION: The existing thermal relief valve piping on the tank receipt and issue piping do not have testing tees and include sight flow indicators.

CODE REFERENCE: AW 78-24-27 requires the thermal relief piping to be equipped with isolation valves and testing tees. UFC 3-460-01, Section 9-3.5.1 does not allow sight flow indicators in thermal relief piping.

RECOMMENDATION: Provide testing tees and remove sight flow indicators from thermal relief piping on the tank issue and receipt piping.

e. Replace/Remove Wire Mesh Screens from Center Vent and Perimeter Vents

OBSERVATION: The tank center vent and the four roof-mounted perimeter vents/inspection hatches have wire mesh screens. The perimeter vents have these screens in addition to the larger bird screens. Some of the wire mesh screens have become clogged with debris, especially during recoating operations. This can reduce the tank venting capacity.

CODE REFERENCE: UFC 3-460-01, paragraph 8-8.3 b) and Table 8-1, item m) requires open atmospheric vents with bird screens. API 650, H.5.2.2 requires the screens to have 1/2-inch openings.

RECOMMENDATION: Replace the screen on the roof center vent with corrosion resistant screen with

1/2 -inch openings. Remove the fine mesh screens from roof-mounted perimeter vents/inspection hatches and leave the larger bird screens in place.

POL-MCX: Perform as part of regular maintenance.

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POL-MCX: Wait for next OOS.

f. Repair Roof Perimeter Vent/ Inspection Hatches

OBSERVATION The covers and latches on the four perimeter vents/inspection hatches have been painted shut and therefore, cannot be opened for inspection and maintenance. The safety chain links have been painted over and attached to the hatch covers. Also, the clasps for the safety chain links are corroded and inoperable. This further impedes the opening of the perimeter vents/inspection hatches.

CODE REFERENCE: UFC 3-460-01, Table 8-1 Item h and AW 78-24-27 require that the tank roof be provided with four roof inspection hatch/circulation vents.

RECOMMENDATION: Detach the coated safety chain links from the hatch covers. Replace the corroded safety chain link clasps with corrosion resistant clasps. Detach the painted hatch covers, so that the hatches can be opened for inspection and maintenance operations. Repair coating system wherever necessary.

g. Replace the Level Control Valve

OBSERVATION: The 8-inch level control valve is made of aluminum.

CODE REFERENCE: NFPA 30 paragraph 27.4.3 does not allow valves made of low melting point materials. UFC 3-460-01 paragraph 3-6.7 prohibits use of aluminum valves since it is not an API fire-safe valve.

RECOMMENDATION: Replace the 8-inch aluminum level control valve with a cast steel, cast stainless steel, or ductile iron level control valve per UFGS 33 52 43.14.

POL-MCX: Replacement will require draw-down of the pipeline upstream of the skin valve to the previous isolation valve outside the dike area. Does not require tank draw-down.

h. Remove Weep Hole Plugs on Shell Reinforcement Pads

OBSERVATION: The tell-tale holes on the shell reinforcement pads around the tank nozzles are plugged.

CODE REFERENCE: API 650, sections 5.7.5.1 and 5.7.6.1 require tell-tales on all shell reinforcement pads for leak detection around the nozzles to be open to the atmosphere.

RECOMMENDATION: Remove the plugs from the tell-tale holes in the reinforcement pads.

i. Provide Hold-Off Distances at ATG and Sampling/Gauging Hatch

OBSERVATION: There are no hold-off distances painted or stenciled on the ATG or sampling/gauging hatch.

CODE REFERENCE: API 653 In-Service Inspection Checklist, C.1.5.2b.

RECOMMENDATION: Provide stencil indicating the hold-off distances and markings adjacent to or directly on the ATG and sampling/gauging hatch nozzles. Ensure markings are clearly visible to storage tank operators.

POL-MCX: Perform as part of regular maintenance.

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j. Remove Condensation from Tape Level Gauge

OBSERVATION: There is heavy condensation on the interior of the Varec tape level gauge sight glass, making it difficult to read.

CODE REFERENCE: N/A

RECOMMENDATION: Remove condensation from the interior of the Varec tape level gauge reading window.

k. Repair Roof Manhole Grounding Strap

OBSERVATION: The grounding strap on the roof manhole is damaged.

CODE REFERENCE: N/A

RECOMMENDATION: Repair or replace the grounding strap on the roof manhole.

POL-MCX: Perform as part of regular maintenance.

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l. Provide Personnel Grounding Strap/Plate

OBSERVATION: The personnel grounding strap at the entrance of the circumferential stairway is missing.

CODE REFERENCE: UFC 3-460-03, paragraph 2-3.2.1, requires that all personnel shall periodically ground themselves while conducting petroleum fuel handling operations.

RECOMMENDATION: Provide a personnel grounding strap or a grounding plate at the entrance of the circumferential stairway.

3. REPAIRS to Fully Comply with API 653, UFC 3-460-01, or AW 78-24-27 Standards

These items represent repairs and/or upgrades that could be performed to bring the tank into full compliance with current standards, but that do not represent potential risks to system operators, equipment integrity, or the adjacent environment. Our recommendations to perform or not to perform these repairs and/or upgrades take into consideration the cost of the repair, the operational benefit of the repairs, the age of the tank/system, operator safety, environmental risks, and equipment integrity.

a. Provide Upper Shell Manhole, Access Stairway, and Access Platform

OBSERVATION: There is no upper shell manhole or associated stairway platform for accessing the top of the floating pan or the floating pan’s perimeter seals.

CODE REFERENCE: UFC 3-460-01, Table 8-1, Item c, and AW 78-24-27 require a shell manhole located above the internal floating pan’s high leg position to aid in venting the tank during cleaning and to provide access to the floating pan’s elastomeric wiper seal. AW 78-24-27 also requires a stairway and platform for accessing the upper shell manhole.

RECOMMENDATION: Provide a shell manhole above the internal floating pan’s high leg position.

Alter the circumferential stair to include a stairway and platform for access to the manhole.

b. Upgrade Water Draw-off Piping

OBSERVATION: The water draw-off piping consists of 3/4-inch pipe with a ball valve at the tank skin.

CODE REFERENCE: UFC 3-460-01, Table 8-1 z, requires water draw-off piping to include a 2-inch double block and bleed valve as the tank skin valve.

RECOMMENDATION: Upgrade the water draw-off piping to 2-inch and provide a 2-inch double block and bleed valve at the skin of the tank.

POL-MCX: Leave as is. Modify stairs at high level controls during next OOS.

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c. Provide Low-low Level Alarm

OBSERVATION: The tank is not provided with a low-low level alarm Independent of the Enraf ATG alarms.

CODE REFERENCE: UFC 3-460-01, Table 8-1, Item l requires independent high-high, high, low, and low-low level alarms.

RECOMMENDATION: Provide a low-low level alarm by making modifications to the existing low level alarm chamber.

d. Modify Stairway to Provide Intermediate Landing

OBSERVATION: The is no intermediate landing in the circumferential stairway for accessing the high and high-high level alarms and controls for maintenance and/or testing.

CODE REFERENCE: UFC 3-460-01 Table 8-1, Items k and l; and DoD AW 78-24-27 require an intermediate landing for maintenance and testing of the level alarms and controls.

RECOMMENDATION: Provide an intermediate landing in the circumferential stairway for accessing the level alarms and controls for maintenance and/or testing.

POL-MCX: Wait for next OOS.

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e. Relocate Overflow Vents

OBSERVATION: One of the overflow vents for the tank is located above the stairway and another vent is located above the receipt nozzle/valves.

CODE REFERENCE: DoD Standard Design AW 78-24-27 requires overflow vents to not be placed above stairways and tank receipt/issue nozzles.

RECOMMENDATION: Relocate the overflow vents for the tank in accordance with DoD Standard

Design AW 78-24-27 tank standards.

f. Provide Low Suction Hard Piping

OBSERVATION: The low suction is not hard piped to the main suction.

CODE REFERENCE: UFC 3-460-01, 3-8, and Table 8-1, Item v, require the low suction to be hard piped to the main suction.

RECOMMENDATION: Hard pipe the low suction to the main suction.

POL-MCX: Wait for next OOS.

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4. RECOMMENDED REPAIRS as Part of Regular Maintenance

Recommended repairs represent items that should be addressed in a timely manner in order to prevent future potential risks to system operators, equipment integrity, or the adjacent environment.

a. Remove Mold and Algae

OBSERVATION: There is mold and algae growing on the tank shell, tank bottom extension area, circumferential stairway, etc. The mold and algae may cause degradation of the exterior coating system.

CODE REFERENCE: UFC 3-460-01, 8-3.10 requires the exterior of fuel storage tanks to be coated.

RECOMMENDATION: Power washing of the exterior of the tank and applying an algae and mold/algae inhibitor of the exterior of the tank is recommended. Application of mold/algae inhibitor should be repeated on a regular basis to prevent future mold and algae growth.

b. Remove Vegetation and Debris within the Dike Area

OBSERVATION: There are isolated plants growing out of the expansion joints in the dike area, which have caused further deterioration of the expansion joint seals. Also, some organic debris was observed lying within the dike area.

CODE REFERENCE: API 653 In-Service Inspection Checklist, C.1.5.2b. UFC 3-460-03, Section 8-10.1

RECOMMENDATION: Remove vegetation from the dike area. Apply an herbicide as needed to control the growth of vegetation. Keep the dike area free of debris on a regular basis.

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Sticky Note POL-MCX: Perform as part of regular maintenance.

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APPENDIX A: ENGINEERING CALCULATIONS AND DRAWINGS

SHELL ROUNDNESS SURVEY & SETTLEMENT

The shape of the shell appears to exceed the allowable API Standard 650 tolerance of plus or minus 3/4-inch of shell radius, as measured using laser surveying methods. Based on the circumference of the shell measured near the bottom, the radius of the shell should be 21 feet and 9 inches. However, the measured radius of the shell varies at the bottom from 21 feet and 9-13/16 inches in the north to 21 feet and 8-5/16 inches in the west. Also, the measured radii of the shell, varies near the top from 21 feet and 9-15/16 inches in the northeast and to 21 feet and

8-1/2 inches in northwest. The bottom and top of the shell are only slightly out of tolerance for a new tank. Since the shell did not appear to be significantly distorted and the out-of-roundness does not appear to be detrimental to the structural integrity of the tank, no action is required or recommended at this time.

Austin Brockenbrough & Associates, L.L.P. Job No. 16-095.03

Location: Tank HT-3 JB Lewis-McChord Date: 03/01/2017

Subject: Shell Radius Survey Page 1 of 4

Measured Circumference at Bottom = 136.66

Calculated Diameter = 43.50

Calculated Radius = 21.75

Distance

From Radial

Centerline Deviation Deviation (in)

South 21.72 -0.03 -0.36 0.199 S+N 0.01

21.76 0.01 0.14 3.2 0.76

21.76 0.01 0.14 6.199 0.80

21.76 0.01 0.07 9.2 0.80

21.78 0.03 0.36 12.194 1.12

21.80 0.05 0.65 15.184 1.06

21.80 0.05 0.59 18.182 0.84

21.81 0.06 0.74 21.173 1.30

21.79 0.04 0.52 24.177 1.45

21.79 0.04 0.44 27.179 1.67

21.80 0.05 0.54 30.17 1.64

21.78 0.03 0.32 33.182 1.55

21.78 0.03 0.41 36.172 1.52

21.78 0.03 0.34 39.369 1.48

21.76 0.01 0.11 42.057 0.94

Weld Elevation----> 109.91

Southeast 21.77 0.02 0.19 0.202 SE+NW -0.29

21.77 0.02 0.26 3.2 0.25

21.77 0.02 0.22 6.198 0.08

21.76 0.01 0.16 9.196 -0.11

21.78 0.02 0.30 12.19 0.08

21.76 0.01 0.12 15.195 0.13

21.74 -0.01 -0.11 18.206 -0.47

21.77 0.02 0.26 21.184 -0.02

21.78 0.02 0.30 24.18 0.13

21.76 0.01 0.13 27.19 -0.13

21.77 0.02 0.26 30.177 -0.01

21.78 0.02 0.30 33.17 -0.24

21.76 0.01 0.16 36.184 -0.12

21.74 -0.01 -0.13 39.216 -0.32

21.72 -0.03 -0.35 42.244 -0.84

Weld Elevation----> 109.93

Height

Above

Chime

Diameter

Deviation (in)

Subject: Shell Radius Survey Page 2 of 4

Distance

From Radial

Centerline Deviation Deviation (in)

East 21.76 0.01 0.11 0.203 E+W -0.14

21.76 0.01 0.07 3.201 -0.10

21.76 0.01 0.12 6.2 0.18

21.77 0.02 0.20 9.198 0.31

21.77 0.02 0.26 12.195 0.41

21.79 0.04 0.43 15.189 0.47

21.78 0.03 0.32 18.19 0.23

21.79 0.04 0.47 21.181 0.28

21.81 0.06 0.72 24.168 0.31

21.77 0.02 0.28 27.186 -0.22

21.77 0.02 0.26 30.185 -0.12

21.74 -0.01 -0.07 33.205 -0.49

21.77 0.02 0.29 36.18 -0.07

21.79 0.04 0.52 39.347 -0.14

21.77 0.02 0.20 42.183 -0.50

Weld Elevation----> 109.92

Northeast 21.83 0.08 0.92 0.204 NE+SW 1.28

21.82 0.07 0.78 3.2 0.91

21.80 0.05 0.56 6.194 0.72

21.81 0.06 0.70 9.186 0.84

21.80 0.05 0.62 12.181 0.79

21.81 0.06 0.68 15.172 1.01

21.78 0.02 0.30 18.184 0.52

21.77 0.02 0.18 21.19 0.30

21.76 0.01 0.13 24.191 0.64

21.76 0.01 0.08 27.194 0.47

21.76 0.01 0.13 30.188 0.67

21.76 0.01 0.13 33.189 0.46

21.78 0.03 0.35 36.163 0.97

21.77 0.02 0.25 39.17 0.84

21.73 -0.02 -0.29 42.24 -0.18

Weld Elevation----> 109.93

Height

Above

Chime

Diameter

Deviation (in)

Subject: Shell Radius Survey Page 3 of 4

Distance

From Radial

Centerline Deviation Deviation (in)

North 21.78 0.03 0.37 0.204

21.80 0.05 0.61 3.2

21.81 0.05 0.66 6.195

21.81 0.06 0.73 9.19

21.81 0.06 0.76 12.185

21.78 0.03 0.41 15.189

21.77 0.02 0.25 18.192

21.80 0.05 0.55 21.179

21.83 0.08 0.94 24.159

21.85 0.10 1.22 27.137

21.84 0.09 1.10 30.137

21.85 0.10 1.22 33.12

21.84 0.09 1.12 36.122

21.85 0.09 1.14 39.461

21.82 0.07 0.83 42.13

Weld Elevation----> 109.93

Northwest 21.71 -0.04 -0.48 0.196

21.75 0.00 -0.01 3.2

21.74 -0.01 -0.13 6.202

21.73 -0.02 -0.26 9.206

21.73 -0.02 -0.22 12.208

21.75 0.00 0.01 15.199

21.72 -0.03 -0.36 18.219

21.73 -0.02 -0.29 21.219

21.74 -0.01 -0.17 24.214

21.73 -0.02 -0.26 27.224

21.73 -0.02 -0.28 30.228

21.71 -0.05 -0.54 33.258

21.73 -0.02 -0.28 36.232

21.73 -0.02 -0.19 39.228

21.71 -0.04 -0.49 42.27

Weld Elevation----> 109.94

Height

Above

Chime

Subject: Shell Radius Survey Page 4 of 4

Distance

From Radial

Centerline Deviation Deviation (in)

West 21.73 -0.02 -0.25 0.222

21.74 -0.01 -0.17 3.2

21.76 0.00 0.06 6.2

21.76 0.01 0.11 9.199

21.76 0.01 0.14 12.198

21.75 0.00 0.04 15.199

21.74 -0.01 -0.10 18.203

21.73 -0.02 -0.19 21.208

21.72 -0.03 -0.41 24.219

21.71 -0.04 -0.49 27.226

21.72 -0.03 -0.38 30.222

21.72 -0.04 -0.42 33.227

21.72 -0.03 -0.36 36.225

21.70 -0.05 -0.66 39.424

21.69 -0.06 -0.71 41.204

Weld Elevation----> 109.95

Southwest 21.78 0.03 0.36 0.203

21.76 0.01 0.13 3.206

21.76 0.01 0.16 6.198

21.76 0.01 0.14 9.197

21.76 0.01 0.17 12.195

21.78 0.03 0.32 15.187

21.77 0.02 0.22 18.189

21.76 0.01 0.12 21.193

21.79 0.04 0.50 24.361

21.78 0.03 0.38 27.171

21.80 0.05 0.54 30.151

21.78 0.03 0.32 33.169

21.80 0.05 0.62 36.132

21.80 0.05 0.59 39.127

21.76 0.01 0.11 42.188

Weld Elevation----> 109.92

Height

Above

Chime

SHELL SETTLEMENT SURVEY

Austin Brockenbrough & Associates, L.L.P.

Job No. 16-095.03 Location: Joint Base Lewis-McChord

Date: 05/31/2017 Subject: Tank Facility 12186 Shell Settlement Evaluation By: Jeffrey W. King

API 653 Appendix B Optimum cosine curve, B 2.2.4.e)

Z = a + b x cos(theta + c)

Diameter (D) = 43.50 (ft)

Number of equally spaced data points (ft)= 8 L = Arc length between measurement points (ft) = 17.08 Tank Height (H) = 42.25 (ft)

Survey Height of

Position Weld * Z U S 0 1 109.91 0.00 0.01 0.01 0.01 1 2 109.93 0.02 0.01 -0.01 -0.02 2 3 109.92 0.01 0.02 0.01 0.01 3 4 109.93 0.02 0.03 0.01 0.00 4 5 109.93 0.02 0.03 0.01 0.01 5 6 109.94 0.03 0.03 0.00 0.00 6 7 109.95 0.04 0.02 -0.02 -0.02 7 8 109.92 0.01 0.01 0.00 0.01 8 1 109.91 0.00 0.01 0.01 0.00

Maximum out-of-plane deflection = 0.02

* = measured elevation

*HI (Height of Instrument) Z = calculated rigid body tilt (in)

U = out-of-plane settlement = S = out-of-plane deflection = z-y

Y = yield strength of shell material (PSI) = 30,000 E = Youngs modulus of elasticity (lbf/in2) = 2.90E+07 S allowable (in) (API 653 B.3.2.1) = (L^2*Y*11)/(2EH)*12 = 0.47 in

R^2 =(Syy - SSE)/Syy = 0.38 not >=0.9 therefore cosine curve is invalid.

Evaluation by the Arc Length Method described in API 653 B.2.2.5.1 is required.

Austin Brockenbrough & Associates, L.L.P.

Job No. 16-095.03 Location: Joint Base Lewis-McChord

Date: 05/31/2017 Subject: Tank Facility 12186 Shell Settlement Evaluation By: Jeffrey W. King

API 653 B.2.2.5.1 Evaluation by Settlement Arc Length Method

Per B.3.2.2, K = 10.5

Settlement arc length (ft), Sarc

Out of plate settlement at Point i (Si)

Allowable settlement at point i (Smax) = MIN[K*Sarc*(D/H)*(Y/E), 4]

Point Sarc (ft) Si (in) Smax

0 51.2 0.027 0.57 Si < Smax → OK

2 34.2 0.010 0.38 Si < Smax → OK

4 51.2 0.007 0.57 Si < Smax → OK

Evaluation of the settlement by the arc length method indicates the settlement is within acceptable limits.

0.00

0.01

0.02

0.03

0.04

0.05

0 2 4 6 8 10

Measured Elevation (in)

Si2 Si4 Si0

SHELL THICKNESS CALCULATIONS

It is noted that because of the way technology has evolved, and as the exact location of the measurements vary, the measured minimum thickness of some of the shell plate may be less than, or even greater than, the previous measured thickness. Additionally, in some cases the measured thickness is greater than the nominal thickness due to steel plate tolerances, which allow plus or minus 30 thousandths of an inch. However, this may not indicate a corrosion rate, unless there is significant coating failure and corrosion, which is unlikely with oil storage. Thinning of coated steel is due to abrasive blasting and not deterioration. Therefore, since the interior and exterior of the shell are coated and the current measurements indicate the same nominal thickness as the previous measurements with no significant deviation, the current corrosion rate is zero. Also, since the remaining thickness is greater than the required thickness, the expected service life is greater than 30 years. Therefore, per API 653 the next ultrasonic thickness inspection of the shell should be performed in 15 years.

Job No.: 16-095.03

Job Title: JB Lewis-McChord

Subject: Tank HT-3 Shell Thickness Evaluation

By: Jeffrey W. King Date:

API 653

SHELL CALCULATIONS

Diameter 43.5 feet

Shell Height 42.25 feet

Freeboard 0 feet

Design Fill Height 42.25 feet

Specific Gravity 1.00 API 650

0.84 API 653

Joint Efficiency 0.85 API 650 Appendix A 7th Edition Assumed

Material unknown

Yield Strength 30,000 psi (assumed)

Tensile Strength 55,000 psi (assumed)

Original Design Corrosion Allowance

0.000 in (0 mm)

Required thickness:

Lower Upper

Two

Courses Courses

23,600 26,000

Height Product Required Thickness

Course (feet) Depth 1/4" min

5 8.00 8.25

4 8.00 16.25

3 8.00 24.25

2 8.00 32.25

1 10.00 42.25 min 2016 Corrosion Estimated UTM current net 1954 Rate Service Life Inspection

Course UTM thickness thickness * in/yr yrs. Interval

5 0.240 0.240 0.243 0.00005 >30 15

4 0.241 0.241 0.243 0.00004 >30 15

3 0.242 0.242 0.245 0.00005 >30 15

2 0.240 0.240 0.244 0.00006 >30 15

1 0.249 0.249 0.254 0.00008 >30 15

* The original thicknesses are assumed based on required design thicknessess, overtolerance, and the range of the UTMs.

0.043

0.090

0.100

0.100

0.231

0.175

0.041

0.085

0.195

0.148

SE

2.6(H-1)D 2.6HDG

0.244

0.185

Design

Original

Hydro

5/16/2017

Visual

Inspection

Interval

SE

2.6(H-1)DG

Allowable Stress (psi)

API-650 API-653

0.130 0.137 0.100

SE

20000 22500

Original

SHELL/ROOF ULTRASONIC THICKNESS MEASUREMENTS

Brockenbrough personnel recorded the ultrasonic thickness measurements, shown on the following page, on 02

March 2017. Refer to the tank drawings by others, which are included for reference in the pages that follow, for location of the shell plate measurements and layout of the tank. The values are in thousandths of an inch.

Job No.: 16-095.03

Job Title: Fort Lewis

Subject: Tank HT-3 Shell Thickness Evaluation

By: Jeffrey W. King Date:

SHELL UTM DATA (0.001 inches)

DFT = 0.000 inches

Course 5 244 245 240 at Stairs

Course 4 242 247 241 at Stairs

Course 3 242 248 245 at Stairs

Course 2 245 246 240 at Stairs

UTM's include 0 inch DFT coating.

1 4 7

2 5 8

3 6 9

Typical Shell Plate UTMs.

Course 1 1 2 3 4 5 6 7 8 9

1-1 253 256 252 255 257 253 253 249 253

1-2 251 256 252 258 252 251 254 255 253

1-3 254 257 252 252 255 251 254 255 253

1-4 255 256 252 253 255 251 254 257 252

1-5 255 256 252 255 257 253 253 255 253

Roof 244 250 246 247 251 248 253 244 249 249 256

UTs 255 249 243 250 250 254 255 248 245 251 251

5/16/2017

TANK DRAWINGS

The following tank drawings are taken from a previous API 653 Out-of-Service Inspection Report prepared by

Environmental Technology, Inc. in October, 2006. This data is included as a reference and should be used for informational purposes only.

PPPOOOWWWEEERRRSSS

PO BOX 1928

BENICIA, CA 94510

TEL 707 334 3400

FAX 707 922 2284

MCCHORD AIR FORCE BASE

API 653 INTERNAL INSPECTION

TACOMA, WA

ENGINEERING & INSPECTION, INC www.powersei.com Tank HT-3

API653 Internal McChord AFB TkNoHT-3 2010 rev1 © 2010 PE&I Inc.

Page 8 of 13 Date Printed: 11/10/10 4:33 PM

SHELL ROLL-OUT

PPPOOOWWWEEERRRSSS

PO BOX 1928

BENICIA, CA 94510

TEL 707 334 3400

FAX 707 922 2284

MCCHORD AIR FORCE BASE

API 653 INTERNAL INSPECTION

TACOMA, WA

ENGINEERING & INSPECTION, INC www.powersei.com Tank HT-3

API653 Internal McChord AFB TkNoHT-3 2010 rev1 © 2010 PE&I Inc.

Page 9 of 13 Date Printed: 11/10/10 4:33 PM

CONE ROOF

OSHA ACCESS STRUCTURE REPORT

OSHA Stairway Data

Handrail Actual

(in)

OSHA Rq’d min (in) max (in)

Handrail Height 36 30 34 Step Width 32 22 NA Step Rise 9 NA NA

Bottom Step Rise 9 6.5 9.5

APPENDIX B: API 653 CHECKLISTS FOR TANK INSPECTIONS

UL SWRI

API Other

Protected

43'-6" diameter by 42'-3" tall

Type: Type:

Size: Date Installed:

CS End Conn: Size: 8" Material: SS End Conn: Size: 12"

Issue To:

Release Prevention Barrier

Overfill Protection / Level Alarms:

Independent High-high, High, Low Level Alarm & ATG Alarms High Level Control Valve (HLCV)

Receipt Piping Configuration Issue Piping Configuration

Tank Piping

Secondary Containment

November 2010

Tank Specifications

Previous Tank Inspection Date:

Continuous Release Detection Monitoring

Type:

Date Installed:

Current Product: N/A

Inspection Date:

Design Std

Tank Inspector Name:

Inspector Certification Number:

Tank Construction and Configuration

Insulated

Coated

Plastic / Fiberglass

Other:

Jet Fuel (F-24)

10,000 BBL

Unknown

Welded

Overfill Protection:

NA

NA

NA

Useable Capacity:

Receipt From: Bulk/Truck Off-Load

54102

Horizontal Single Wall

Welded

Hydrant Loop/ Truck Fillstand

Unknown

API 653 EXTERNAL INSPECTION CHECKLIST

JB Lewis-McChord, WAProject Site:Project Name:

Project Location:

Brockenbrough Job No.:

SPCC Mandated AST Inspections - Group 19

Various Locations

General Inspection Information

16-095.03

Submitted to:

Contract No.:

USACE - Omaha

W9128F-12-D-0006

Tank Facility No.:

Local Tank ID No.:

March 2, 2017

Facility 12186

Tank Manufacturer:

Tank Construction Date:

Tank HT-3 Jeffrey W. King

Vertical

Rectangular

Double Wall

Fire Resistant

Closed Top Dike

Change of Service:

Last Repair:

Tank Coatings:

Exterior Coating:

Epoxy/Epoxy/Polyurethane

Epoxy (assumed)

Interior Coating:

Double Bottom

Morse Construction Group

Concrete Dike

110' X 110' X 8'

Level Alarms:

Material:

Tank Outside Dimensions:

Nominal Capacity:

Secondary Containment, Overfill, and CRDM

Open Type Dike

November 2010

API 653 EXTERNAL INSPECTION CHECKLIST

JB Lewis-McChord, WAProject Site:Project Name: SPCC Mandated AST Inspections - Group 19

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

C.1.1.4 Rock c)

TASK

Check for:

Tank Settlement

C.1.1.1 Concrete Ring

Settlement around perimeter of tank

Check for:

d)

Cavities under foundation; vegetation against bottom of tank

Broken concrete, spalling, and cracks, especially under backup bars used in welding butt-welded annular rings under the shell

Indications of bottom leakage at drain openings in ring, back of water-draw basins, and top surface of ring

ITEM

C.1.1 Foundation

Measure foundation levelness and bottom elevations (See Annex B) See survey data.

STATUS COMMENTS

a) b)

C.1.1.6 Housekeeping

Build-up of trash, vegetation, and other inflammables

Leaching of oil which has left rock filler exposed indicating hydrocarbon leakage

Tank settlement into asphalt base

Site drainage away from the tank, associated piping, and manifolds

Check for:

Presence of crushed rock under the steel bottom which usually results in severe underside corrosion.

Check for :C.1.1.3 Oiled Dirt or Sand

Review cathodic protection potential readings

Check for:

e) a) b)

Run-off rainwater from shell draining away from the tank

Check for:

b)

Settlements into the base

C.1.1.5 Site Drainage

Proper operation of dike drains

C.1.1.2 Asphalt

Organic plant growth and debris were found in the dike area.

C.1.1.7 Cathodic Protection a)

Majority of dike sealant on dike wall has been replaced. There is a project in place to finish replacing dike joint sealants. It is awaiting funding as well as appropriate weather conditions.

Galvanic Cathodic Protection System.

The non-shrink grout around tank bottom has failed. Spalling and cracking was observed.

C.1.2.1 External Visual Inspection

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

C.1.2.3 Riveted Shell Inspection

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

C.1.2.4 Wind Girder (Floating Roof

Tanks) a)

Rivet and seam leaks on external surface

Check for:

Full fillet lap-welded vertical seams to increase joint efficiency b) c) c) b)

Reinforcing pads welded to shell at supports

Leaks and identify the location by sketch or photo

Check for:

Check for:

Broken welds and corrosion damage

(paint failure, pitting, corrosion, product build-up), especially where it occurs at tack-welded junction

c) Bottom-to-Foundation Seal

e) Drawings of riveted seams if available. Otherwise, dimension and sketch (or photograph) the rivet pattern: no. of rows, rivet size, pitch length, butt-riveted or lap-riveted joints a)

Grooving, corrosion, pitting, and coating failures

Corrosion loss and wear on the rivets a) b) d)

Corrosion and thinning on plate and weld after cleaning the bottom angle area

Paint failures, pitting, and corrosion Minor paint failure and corrosion on tank bottom extension and on tank anchor bolts. Coating failure/minor corrosion on manhole bolts. Grout around tank bottom to foundation has failed - no mastic/sealant. Mold and algae growth on tank shell, primarily on tank bottom extension and upper shell courses.

No access.

C.1.2. Shells

Check for:

C.1.2.2 Internal (Floating Roof

Tank)

Pitting on support welds to shell, especially on shell plates

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

ITEM TASK

a) Leaks at piping manifolds, flanges, and valves

Shell plate dimpling around nozzles, caused by excessive pipe deflection c)

Check for:

C.1.3.3 Autogauge System Check for:

b)

COMMENTS

Cracks or signs of leakage on weld joint at nozzles, manholes, and reinforcing plates

Fire fighting system componentsb) c) d) e) f) g)

Anchored piping which would be hazardous to the tank shell or bottom connections during earth movement

Adequate thermal pressure relief of piping to the tank

Proper operation of regulators for tanks with purge gas systems

Leaks at sample connections and proper valve operation

Damage and test the accuracy of temperature indicators h)

C.1.3.1 Manholes and Nozzles

C.1.3.2 Tank Piping Manifolds

C.1.3 Shell Appurtenances

Damage on welds on shell-mounted davit clips above valves 6 inches and larger

Sealing of insulation around manholes and nozzles a)

e) Adequate manholes flange and cover thickness on mixer manholes

Sight flow indicators are present in thermal relief piping.

d)

STATUS

There was heavy condensation on interior of sight glass of the tape level gauge.

a) Leaks on autogauge tape guide and lower sheave housing (floating swings)

b) Damage on autogauge head

Check for:

Flange leaks and leaks around bolting

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

c) Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A i)

h) Condition of board and legibility of board-type autogauges

Freedom of movement of marker and float

Varec = 32'-5 1/2" , Enraf ATG= 32'-6 5/16"

C.1.3.3 Autogauge System c) d)

C.1.3.4 Shell-mounted Sample

Station a)

Check for:

Function of valves and plugging in sample lines, including drain or return-to-tank line

Leaks in circulation pump and operating problems

Inspect condensate drain for presence of oil indicating leakage

C.1.3.5 Heater (Shell Manhole

Mounted)

C.1.3.6 Mixer Check for:

c) Condition of power lines and connections to mixer b) b)

Proper mounting flange and support

Leakage

No access.

a) e) f) g)

Proper movement of tape by bumping the checker on autogauge head

Size and construction material of the autogauge tape guide and make note

(floating roof tanks)

Proper movement of tape. Ask the operator if the tape tends to hang up during tank roof movement (floating roof tanks).

Actual product level compared to the reading on the autogauge. Make note. (max. variation is 2 in.)

No more than 2 feet of tape are exposed at the end of the tape guide when the roof is in lowest position

(floating roof tanks)

ITEM TASK STATUS COMMENTS

1 1/2"ø coated carbon steel.

Bracing and supports for sample lines and equipment

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

b) Pass Fail N/A

Pass Fail N/A

Pass Fail N/A

Target should indicate direction of swing opening (up or down) and height above bottom where suction will be lost with swing on bottom support

Floating: With tank half full or more, lower the swing line, then let out the cable and check if the swing has pulled cable tight, indicating that the winch is operating properly

ITEM

Non-floating: Raise, then lower the swing line with the winch and check for cable lightness to confirm the swing line lowered properly

COMMENTS

C.1.3.7 Swing Lines: Winch a)

Operation

Indicator: Check that the indicator moves in the proper direction.

Floating swing line indicators show a lower level as cable is wound up on the winch. Non-floating swing line indicators show the opposite b) c)

C.1.3.8 Swing Lines: External

Guide System

Check for leaks at threaded and flanged joints

C.1.3.9 Swing Lines: Identify

Ballast Varying Need

Check for significant difference in stock specific gravity

Check for:C.1.3.10 Swing Lines: Cable

Material and Condition a) Corrosion over entire length, for non-stainless steel cable

Wear or fraying on all types of cable

C.1.3.11 Swing…