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API 510 Study Guide - (Referenced)

Terms in this set (445)

Pressure-relieving devices shall be tested and repaired by a repair organization that is:
API 510 6.6.1
Qualified and Experienced
What two items must a pressure-relieving device repair organization maintain?
API 510 6.6.2.1 & 6.6.2.2
A fully documented QA process
A fully documented training program
Pressure -relieving devices shall be tested and inspected at intervals:
API 510 6.6.3.1
Frequent enough to verify the devices perform reliably in the particular service conditions.
Who can set the inspection interval for pressure-relieving devices?
API 510 6.6.3.1
An inspector, engineer or other qualified individual
What is the maximum relief device interval?
API 510 6.6.3.2
Typical: 5 years
Clean, non-corrosive, non-fouling: 10 years
Repairs to pressure-relieving devices should be in accordance with:
API 510 8.1.1
API 576 and the approved relief valve QA manual
Every vessel should have at least one relief device set at:
ASME VIII UG-134.a
MAWP
Safety valves are normally used in what services?
API 576 4.2.2
Compressible fluids (general air, gas and steam)
Relief valves are normally used in what services?
API 576 4.2.3
Incompressible fluids
How should pressure-relief valves be shipped?
API 576 5.9.2
Braced and shipped in an upright position.
What position should pressure-relief valves be installed?
API 576 5.9.4
In a vertical position, unless designed for satisfactory performance in other position.
A pressure vessel is rated at 2000 psig at 450 °F. The height of the vessel is 26 feet and the outside diameter (OD) is 6.625". The wall thickness is 0.432". The vessel material is carbon steel SA-106. Is this vessel covered by ASME section VIII?
No.

Reference: U-1 (c)(2)(i)

I.D is less than 6.0", since 6.625 - (2 x .432) = 5.716"
What is the minimum thickness allowed by the code for the shell of a new vessel that will be in hydrocarbon service?
0.0625".

Reference: UG - 16(b)
A cylindrical vessel has an outside diameter of 48" and a height of 16'. The vessel is in corrosive hydrocarbon service. What is the minimum allowed size of manhole?
16" circular.

Reference: UG-46(a), UG-46(f)(3), UG-46(g)(1)
Provide the section VIII definitions of "lethal substances".
Poisonous gases of liquids.

Reference: UW-2
A vessel is made of SA-516 gr. 60 ( carbon steel, a P-1 material). The shell is 3" thick and the heads are 1.750" thick. What is the holding time for the PWHT?
2 hours 15 minutes.

Reference: Table UCS-56
A vessel is stamped with the "UM" code stamp. The vessel has not been; designed for "special service", or radiographed, or post weld heat-treated. What markings must be on this vessel?
A. UM symbol
B. Manufacture's name
C. MAWP @ design temp
D. MDMT @ pressure
E. Manufacturer's serial #
F. Year built.

Reference: UG-116(a)
A vessel has been designed for "Spot Radiography". The vessel wall thickness is 1.000". What is the maximum allowed size for an isolated rounded indication?
Rounded indications are not a factor.

Reference: UW-52(c)(3)
A vessel has been designed for "Full Radiography". The vessel wall thickness is 2.000". What is the maximum allowed length for a zone of incomplete penetration?
None is allowed.

Reference: UW-51(b)(1)
A vessel is being fabricated using a SMAW process. The temperature is 10*F. What steps must be taken if the welding is going to be performed in this cold temperature?
Warm weld area to 60*F

Reference: UW-30
A manufacturer is building and selling pressure vessels. The manufacturer could use an authorized inspector from what organizations?
A. Jurisdiction
B. Insurance company
C. No answer
Note: The manufacturer's inspector is not allowed to be the AI, because these vessels will be sold.

Reference: UG-91
List 3 acceptable methods for tracing material identification during the fabrication of a high alloy vessel.
A. Transfer of original markings
B. Use of coded markings using key
C. Sketches or tabulations

Reference: UG-77(a)
What is the maximum allowed mill under-tolerance for a plate?
Smaller of 0.010" or 6% of the plate thickness

Reference: UG-16(c)
Determine the maximum amount of under-tolerance for the following plates.
A. 0.125"
B. 0.500"
A. Plate thickness is 0.125"
Max. undertolerance: 0.0075"
Min. new thickness: 0.1175"

B. Plate thickness is 0.500"
Max. undertolerance: 0.010"
Min. new thickness: 0.490"
A relief device is set for 250 psig. The set pressure tolerance shall be plus or minus:
7.5 psi

Reference: UG-126(d)
What are the qualifications requirements for those who performs the following NDE examinations?
A. MT - Vision/Competent - Reference: 6-2(a/b)
B. PT - Vision/Competent - Reference: 8-2(a/b)
C. RT - ASNT-SNT-TC-1A - Reference: UW-54(a)
D. ASNT-SNT-TC-1A - Reference: 12-2
A vessel is too long for the post-weld heat-treating furnace, so multiple heats will be required to completely post-weld heat-treat the vessel. The minimum overlap of heat treatment during each heat is:
60"

Reference: UW-40(a)(2)
When welding 2 components that differ in thickness by more than 1/8", describe the required transition.
3:1 taper

Reference: UW-9(c) or UW-33
When the welder uses a stamp to mark the welds, the welder shall stamp the weld at least every:
3 feet

Reference: UW-37(f)(1)
When impact tests are required, each set shall consist of:
3 bars

Reference: UG-84(c)(1)
The manufacture is preparing to hydrotest a vessel at 600 psi. When selecting the pressure gauge, the maximum pressure on the gauge should not be greater than:
2400 psi

Reference: UG-102(b)
A 1.000" plate is rolled and welded when making a pressure vessel. The maximum height of the weld cap is:
3/32"

Reference: UW-35(d)
Plate used in the pressure boundary of a new vessel must comply with:
ASME section II

Reference: UG-4
API 579
Fitness for service (FFS)

510: 1.3, 7.5
API 580
Risk based inspection

510: 1.3, 5.2.1
API 660
API design for fabrication of exchangers

572: 4.6
API 2201
Welding on in-service equipment containing flammables

510: 8.1.7.1
ASME sect V
NDE procedure guidelines

510: 5.7.1.1a
ASME sect 8, Div 2
Alternative evaluation for pits and LTA's

510: 7.4.4.1
ASME sect IX
Welder & weld procedure qualification

510: 8.1.7.2.1
ASNT SNT-TC-1A
NDE personnel qualification (RT & UT flaw detection)

510: 4.5.2
AIRR
API 510 scope (Alteration, Inspection, Repair, Rerate)

510: 1.1.1
JUIC
API 510 AI's employer (Jurisdiction, User, Insurance company, Contractor)

510: 3.1.4
A JOC
API 510 repair organization (ASME stamp holder, authorized by jurisdiction, Owner, Contractor)

510: 3.1.62
SPEC
How to determine corrosion rate for new service or change in service (Same or similar service, Published data, Exam w/in 3-6 month, or Corrosion specialist)

510: 7.1.2
TIRE
Primary responsibilities of API 510 AI (Testing, Inspection, Repairs, Examinations)

510: 4.4
Alteration
Physical change

510: 3.1.1
Repair
Restore to suitable condition

510: 3.1.61
RBI's two primary factors
Probability & Consequence

510: 5.2.1
Requirements for relief device repair organization
Qualified & Experienced

510: 6.6.1
How relief device intervals are determined
Performance

510: 6.6.3.1
Maximum length of crack, incomplete penetration or incomplete fusion allowed on a new weld
0"

VIII: UW-51.b.1 & 52.c.1
Smoothness of relief device seating surfaces
3 light beads/bands

576: 5.2.1
Maximum allowed mill tolerance of a plate
Lesser: 0.010" or 6% of T"

VIII: UG-16.c
Maximum allowed size of open discontinuity in a bend test
1/8"

IX: QW-163
NDE - Typical thickness range for RT using Iridium 192
0.25 - 3.0

577: 9.8.4
Minimum distance beyond the area to be examined to clean a part when performing a MT examination
1"

V: T-741.1.b
Minimum distance beyond the area to be examined to clean a part when performing a PT examination
1"

V: T-642.b
Minimum radius of insert patch
1"

510: 8.1.6.2.2.c
Evaluate LTA - Distance from the weld in for: E = 1.0
Greater of: 1" or 2T

510: 7.4.5
NDE - Typical thickness range for RT using Cobalt 60
1.5 - 7.0"

577: 9.8.4
Wall thickness of CS shell that requires PWHT
> 1-1/2"

VIII: Table UCS-56, Note 2.a
Wall thickness of CS shell that requires full RT
> 1-1/2"

VIII: UW-11.a.2
Maximum diameter of an examination point
2"

572: 3.1.18
Maximum length of pits allowed in 8" line
2"

510: 7.4.3.c
Vessel inside diameters that are excluded from the scope of section VIII
<6"

VIII: U-1.c.2.i
510: App A b.9
Weld qualify - Minimum weld length when qualifying a welder with RT/UT using a coupon or 1st production weld
6"

IX: QW-302.2/304.1
Weld qualify - Minimum weld length when qualifying a welding operator with RT/UT of a test coupon
6"

IX: QW-302.2
Minimum length of spot RT
6"

VIII: UW-52.c
NDE - Distance of eye-to-part to count as a visual exam
6-24"

577: 9.3.1.e
Maximum distance on weld between welder's stamp
3'

VIII: UW-37.f.1
Weld qualify - Minimum weld length when qualifying a welding operator with RT/UT of first production weld
3'

IX: QW-305.1
Minimum overlap for vessel PWHT when using multiple heats
5'

VIII: UW-40.a.2
Maximum length of weld represented by 1 spot RT
50'

VIII: UW-52.b.1
Minimum allowed wall thickness at pit
1/2 Tmin

510: 7.4.3.a
Welding - Base metal temp where welding is not recommended
<0°F

VIII: UW-30
Welding - Base metal temp, pre-heat to 60*F is recommended
0-32°F

VIII: UW-30
Corrosion - CUI affects carbon steel & alloy (temp range)
10-350°F

510: 5.5.6.1.a
UT calibration - Calibration block must be within what temperature of the part to be examined
25°F

577: 9.9.3.1
NDE - Standard temperature range for PT exam
40-125°F

V: T-652/653
Corrosion - Temperature where cooling water corrosion starts to significantly increase
140°F

571: 4.3.4.3.d
Corrosion - Temperature where chloride stress corrosion cracking becomes a concern
>140°F
Corrosion - CUI affects austentic SS (temp range)
140-350°F

510: 5.5.6.1.b
NDE - Special procedures are needed for UT thickness readings
≥150°F

510: 5.7.2.3
Corrosion - Temperature when high strength caustic causes serious corrosion in CS and 300 SS
>150°F

571: 4.3.10.6.c
Corrosion - Temperature swings that can cause thermal fatigue
+/- 200°F

571: 4.2.9.3.c
Corrosion - Most aggressive CUI temperature range
212-350°F

510: 4.3.3.3.b
Corrosion - CUI affects duplex SS (temp range)
280-350°F

510: 5.5.6.1.c
Welding - Minimum pre-heat temperature, when pre-heat is substituted for PWHT
300°F

510: 8.1.7.4.3.2.2.a
Welding - Minimum pre-heat temperature, when a local PWHT is used in lieu of full encirclement PWHT
300°F

510: 8.1.7.4.2.c
Corrosion - Starting temp for sulfidation on carbon steel
500°F

571: 4.4.2.3.c
Corrosion - Temper embrittlement for low chromes (range)
650-1100°F

510: 3.1.69
Corrosion - If operating temp is above this temp, check for creep in cat reformer equipment
>900°F

572: 9.3.9
NDE - Maximum temperature for UT readings
1000°F

V: SE-797 9.5
Materials - Carbon steel normal PWHT temperature
1100°F

VIII: Table UCS-56
Materials - Carbon steel temp of base metal to create HAZ
>1350°F

577: 10.2.4
Testing - Minimum base metal temp during hydro vessels ≤2" thick
MDMT + 10°F

510: 5.8.7.2
Testing - Minimum base metal temp during hydro vessels >2" thick
MDMT + 30°F

510: 5.8.7.2
NDE - Maximum temperature for magnetic particles
Manufacturer recommended

V:731.c
WPS
Weld procedures

IX: Various
PQR
Qualification record of a weld procedure

IX: Various
WPQ
Welder qualification record (welders paper)

IX: Various
Inspection plan
Document that must be prepared and maintained for each vessel and relief device

510: 5.1.1
QA Inspection / Repair manual
Manual that must be prepared and maintained by each Owner/User that uses API 510

510: 4.1.2
QA manual & training
Two documents that are needed by each repair organization that repairs relief devices

510: 6.6.2.1/2
Design pressures within scope of ASME sect VIII & API 510
≥15 psig

VIII: U-1.c.2.h.1
510: App a b.8
Minimum range of pressure gauge used during a test
1.5 x Ptest

VIII: UG-102.b
Preferred range of pressure gauge used during a test
2.0 x test

VIII: UG-102.b
Maximum range of pressure gauge used during a test
4.0 x Ptest

VIII: UG-102.b
Subject to temper embrittlement
Low chromes

510: 3.1.69
Subject to chloride stress-corrosion cracking
300 SS

571: 4.5.1.2.a
Subject to polytheonic acid stress-corrosion cracking
300 SS

572: 9.4.1
Common material with an endurance limit (fatigue cracking cannot occur below this stress level)
Carbon Steel

571: 4.2.16.3.b.1
Common material without an endurance limit
Aust. SS

571: 4.2.16.3.b.2
P-numbers allowed to use pre-heat in lieu of PWHT
P1 & P3

510: 8.1.7.4.3.2.1.a
P-numbers allowed to use CDW in lieu of PWHT
P1, P3, & P4

510: 8.1.7.4.3.3.b
P-numbers of base metal that should be examined for delayed cracking after repairs to SS cladding
P3, P4, & P5

510: 8.1.6.4.4
Maximum allowed corrosion rate when using an on-stream inspection in lieu of an internal (in ipy)
0.005ipy

510: 6.5.2.1.b.1
Ratio of endurance limit stress to ultimate tensile stress for carbon steel
0.4 - 0.5

571: 4.2.16.3.b.ii
Static head factor (psig per height of water in feet)
0.433 psig/ft

Body of knowledge
Design - Joint efficiency when using full RT on a type 1 joint
1.0

VIII: Tale UW-12
FFS - Joint efficiency when evaluating corroded area away from a weld by greater of: 1" or 2t
1.0

510: 7.4.5
NDE - The number of additional RTs required when a spot RT has a defect
2

VIII: UW-52.d.2
Weld qualification - Number of tension tests to qualify a WPS
2

IX: Tbl QW451.1
Weld qualification - Number of bend tests to qualify a welder or welding operator in welding position 1G-4G
2

IX: Table QW452.1.a
NDE - Minimum number of exposures to RT 360° of a weld using a double-wall technique, double-wall view (elliptical shot)
2

V: T-271.2.b.1
NDE - RT film density range - allowed for the weld & IQI when using a gamma ray source
2.0 - 4.0

V: T-271.2.a
NDE - Minimum number of exposures to RT 360° of a weld using a double-wall technique, single-wall view
3

V: T-271.2.a
Impact test - Number of test bars required in each number of impact test specimens
3

VIII: UG-84.c.1
NDE - When using a shim under a hole-type IQI, the number of sides of the IQI that must be seen in the RT image
3

V: T-277.3
Design - Current sfatey factor of ASME section VIII
3.5

510: 7.7.3
Design - Pre-200 saftey factor of ASME section VIII
4.0

Not in books
Weld qualification - Number of bend tests to qualify a WPS
4

IX: Tbl QW451.1
Weld qualification - Number of bend tests to qualify a welder or welding operator in welding position 5G & 6G
4

IX: Tbl QW452.1.a Note 1
Design - Recommended resistance of grounding systems
5 ohms

572: 9.3.10
Maximum area of pits allowed in an 8" circle
7in²

510: 7.4.3.b
NDE - Weight used to check magnetic strength of an AC yoke
10lb

V: T-762.b
Design - Maximum Resistance allowed of grounding systems
25 ohms

572: 9.3.10
NDE - Minimum angle of eye-to-part to count as a visual exam
30 degrees

577: 9.3.1.e
NDE - Weight used to check magnetic strength of a DC yoke or permanent magnet yoke
40 lb.

V: T-762.c
Testing - Maximum chloride content in hydrotest water when testing 300 series SS (ppm)
50 ppm

510: 5.8.5.2
NDE - Minimum light intensity when performing non-florescent MT or PT exams
100 ft candles

V: T-676.3
577: 9.3.2.2
NDE - Minimum light intensity when performing VT
100 ft candles

577: 9.3.2.2
NDE - Minimum black light intensity when performing MT or PT fluorescent exams
1000 mW/cm2

V: T-676.4.c & T-777.2.c
NDE - Limits of RT film density of welds as compared to IQI (Range)
-15 to +30%

V: T-282.2.a.1
Maximum percent of carbon allowed in new materials
0.35%

510: 8.1.5
AI - Amount of time inspector must be involved in inspection activities - required to maintain API 510 certification
20%

510: B.3.2.a
Materials - Amounts of nickel required for a material to be considered a nickel alloy
> 30%

571: 3.1.16
Maximum operational pressure of a conventional rupture disk (percentage of burst pressure)
70%

576: 4.10.2.1
Center portion of head when evaluating a LTA using the spherical formula
80%

510: 7.4.6.1.b
NDE - Minimum time an examiner should be in a darkened area prior to using a black light for MT & PT exams
5 minutes

V: T-676.4.b & T-777.2.b
NDE - Final interpretation of a PT exam after application of developer (time range)
10 - 60 minutes

V: T-676.1
Testing - Typical minimum duration for a pressure test
30 minutes

577: 9.11
NDE - Minimum time to wait to check for delayed cracking after repairs to SS cladding
24 hours

510: 8.1.6.4.4
NDE - Max calibrating interval - MT permanent magnet yoke
Daily

V: T-762.a
NDE - Max calibrating interval - RT densitometer
90 days

V: T-262.1
Welding - Maximum time a welder or welding operator maintains qualifications for a process without using that process
6 months

IX: QW322.1.a
NDE - Maximum interval for a visual examiners eye exam
1 year

577: 9.3.1.d
NDE - Maximum calibrating interval - Electromagnetic MT yoke
1 year

V: T-762.a
Inspection - Maximum interval for internal inspection if remaining life is less than 4 years
Lesser 2 years or full life

510: 6.5.1.1
Inspection - Maximum interval - External inspection
Lesser 5 years or internal

510: 6.4.1
Inspection - Maximum interval for relief devices in fouling or corrosive service
5 years

510: 6.6.3.2.a
Inspection - Maximum interval for internal or on-stream inspection
Lesser 10 years or half life

510: 6.5.1.1
Inspection - Maximum interval for relief devices in non-fouling or non corrosive service
10 years

510: 6.6.3.2.b
RBI - Maximum interval for the RBI reassessment
10 years

510: 6.3.2
Inspection - Minimum remaining life required when performing an on-stream inspection in lieu of an internal inspection
> 10 years

510: 6.5.2.1.b.2
NDE - Maximum calibrating interval - Check the light intensity of a black light used in a MT or PT exam
Before & after use

V: T-676.4.e & T-777.2.e
Define - Repair (key words)
Restore - suitable

510: 3.1.61
Define - Alteration (Key words)
Physical chnge

510: 3.1.1
Define - RBI's two primary factors
Probability & Consequence

510: 5.2.1
Define - Location on a vessel of vessel MAWP
Top

VIII: UG-98.a
510: 3.37
Define - Imperfection that exceeds the acceptance criteria
Imperfection

510: 3.1.27
Design - Joint category of a vessel longitudinal weld
A

VIII: Fig UW-3
Design - Joint category of a vessel circumferential weld
B

VIII: Fig UW-3
Design - RT factors representing full RT
RT - 1, RT - 2

VIII: UG-116.e.1&2
Design - RT factors representing spot RT
RT - 3

VIII: UG-116.e.3
Design - Weld type - Butt double welded
Type 1

VIII: Fig UW-12
Design - Weld type - Butt single welded with backing
Type 2

VIII: Fig UW-12
Design - Weld type - Butt single welded without backing
Type 3

VIII: Fig UW-12
Design - Vessel service that always requires Full RT
Lethal

VIII: UW-11.a.1
Design - Maximum set pressure for single relief devices on a vessel
MAWP

VIII: UG-134.a
Design - Marking on nameplate indicating vessel was PWHT
HT

VIII: UG-116.f.1
Design - Marking on nameplate indicating vessel is in lethal service
L

VIII: UG-116.c
Design - ASME sect VIII stamp for routine vessels
U

VIII: UG-116.a.1.a
Design - ASME sect VIII stamp for miniature vessels
UM

VIII: UG-116.a.1.b
Design - ASME sect VIII stamp for relief devices
UV

VIII: UG-129.a.7
NDE - Number of CMLs to obtain thickness reading during inspection (key word)
Representative

510: 5.6.2.1
NDE - Number of nozzles to obtain thickness readings during inspection (key word)
Representative

510: 5.6.2.1
NDE - Lead letter used during RT to check for backscatter radiation
B

V:T-223
NDE - Lead letter used during RT to indicate a film-side IQI
F

V: T-277.b
NDE - Hole size that must be visible in RT when using a hole-type IQI
2T

V: Tbl T-276
NDE - Two primary gamma-ray RT sources
Ir 192, Co 60

577: 9.8.4
RV's - How relief devices should be transported
Upright

576: 5.8.4.2
RV's - How relief device intervals are determined (key word)
Performance

510: 6.6.3.1
Welding - Variables needed on WPS
Essential & Non-essential

IX: QW200.1.b
Welding - Variables needed on PQR
Essential

IX: QW200.2.b
Welding - Process to use when substituted preheat or controlled deposition welding for a required PWHT
SMAW, GMAW, GTAW

510: 8.1.7.4.3.2.1.b & 8.1.7.4.3.3.c
Welding - Minimum taper required for shell welds with mismatch
3 to 1

VII: UW 9.c
Weld Qualification - The "all-position" test coupon
6G

IX: QW-405.4 / QW461.9
Weld Qualification - Rejectable in RT when qualifying a welder
Crack, LoF, IP

IX: QW191.1.2.2.a.1
Weld Qualification - Which welding process can a welder NOT be qualified by RT
GMAW - SC

IX: QW-304
Weld Qualification - Maximum thickness qualified based on WPS coupon on WPS based on the plate thickness (T) of a PQR test coupon
2T

IX: Tbl QW451.1
The following activities is not included in the scope of API 510:
Performing vessel fabrication
Operating a vessel

510: Sect 1
The following equipment types is not covered by API 510:
Process heater (furnace)

510: Sect 1
API 510 can be used:
By petro-chemical facilities and any other industry

510: Sect 1
API 510 takes effect:
Once the vessel is placed in service

510: Sect 1
API 510 covers vessels constructed to which fabrication code(s)?
Any fabrication code

510: Sect 1
When does API 510 stop applying to vessels?
Retired and abandoned

510: Sect 1
During repairs & alterations most of the code requirements come from:
ASME section VIII or the construction code

510: Sect 1
During a vessel repair or alteration, if there is a conflict between the requirements of API 510 and the construction code which should be followed?
API 510

510: Sect 1
Companies that use API 510 must:
Either employ or have access to an authorized inspection agency

510: Sect 1
Who is responsible for responding to inspection results that require corrective action?
Owner / User

510: Sect 1
If there is a conflict between the requirements of API 510 and the legal jurisdiction, which should be followed?
The one with the more stringent requirements

510: Sect 1
Which of the following vessels, that may be exempted from API 510, should be considered for inclusion in the Owner / User's API 510 program?
Vacuum Flasher

510: Sect 1
Which code is used for fitness for service evaluations?
API 579

510: Sect 1
Which code is used for RBI assessment?
API 580

510: Sect 1
During an in-service internal inspection, a crack is discovered on a longitudinal weld. This crack can be evaluated to which industry document?
API 579_Fitness-For-Service

510: Sect 2
Which document provides requirements for hot tapping?
API 2201

510: Sect 2
Which document provides information on damage mechanisms in the refining industry?
API 571

510: Sect 2
Which document provides information on corrosion under insulation and fireproofing?
API 583

510: Sect 2
Which document provides information on repair of pressure equipment & piping?
ASME PCC-2

510: Sect 2
Which document provides information on integrity operating window?
API 584

510: Sect 2
Which document provides information on material identification of alloy materials?
API 578

510: Sect 2
Which document provides information on protecting austenitic alloys from polythionic acid stress corrosion cracking?
NACE SPO170

510: Sect 2
When performing controlled deposition welding, supporting technical information can be found in:
WRC Bulletin 412

510: Sect 2
Which of the following is considered a vessel alteration?
Replacement of a hemi-spherical head with a tori-spherical head

510: Sect 3
An alteration of a vessel is defined as:
A physical change with design implications.

510: Sect 3
An 8 NPS nozzel is going to be added to a 2-to-1 ellipsoidal vessel head. The vessel is rated for 350 psig at 500°F. The vessel has an inside diameter of 72". The largest existing nozzle on the vessel is 18 NPS. Which of the following is true?
This must be authorized by the inspector and approved by the engineer.

510: Sect 3
A 14 NPS nozzle is going to be added to vessel shell. The vessel is rated for 100 psig at 650°F and has an existing 10 NPS nozzle. Which of the following is true?
This work is considered an alteration

510: Sect 3
Which of the following inspection organizations is not considered an acceptable API 510 authorized inspection agency?
Holder of an appropriate ASME code symbol

510: Sect 3
Which of the following is considered an API 510 authorized inspection agency?
The inspection organization of the jurisdiction

510: Sect 3
A CML is:
Either a small spot on the vessel / nozzle or a plane through a nozzle section.

510: Sect 3
Fatigue damage comes from:
Cyclic loading

510: Sect 3
A defect is an:
Imperfection that exceeds the acceptance criteria.

510: Sect 3
What is the maximum diameter of an examination point?
3"

510: Sect 3
What is the term used to described based metal whose mechanical properties or microstructure has been altered by welding or thermal cutting?
Heat affected zone

510: Sect 3
An imperfection is a:
Flaw that may or may not exceed the acceptance criteria.

510: Sect 3
During a process outage, a vessel is considered:
In service.

510: Sect 3
Established limits for process variables that affect equipment integrity are called:
Integrity operating windows (IOW's)

510: Sect 3
Work that removes and replaces a major part of the pressure boundary (not including nozzles) is called a(n):
Major repair

510: Sect 3
A management of change (MOC) work process should be completed prior to:
Either physical or process changes

510: Sect 3
MAWP is defined as the maximum pressure:
At the top of the vessel

510: Sect 3
MDMT/MAT defined as the:
minimum design metal temperature/minimum allowable temperature

510: 3.1.45
Internal distributor piping is:
Considered a non-pressure boundary vessel component.

510: Sect 3
Vessel lining can be:
refractory, strip linings, plate linings, coatings

510: 5.5.2.3
API 510 also covers
unfired steam generators (boilers), and other vapor
generating vessels

510: 3.1.56
A pressure vessel engineer
by consulting with specialists, should be regarded as a COMPOSITE
of experts.

510: 3.1.57
The physical activities that are conducted to check conformance with specifications are called:
Quality control

510: Sect 3
A repair on a vessel is defined as:
work necessary to restore a vessel to a suitable safe condition

510: 3.1.61
A vessel's hemi-spherical head has corroded and is going to be replaced in-kind at the next outage. The vessel is rated for 150 psig at 700°F. The vessel has 60 ID.
This work is considered a repair

510: 3.1.61
Which of the following is not considered an acceptable API 510 repair organization?
an individual or organization that is authorized by the legal jurisdiction to repair pressure vessels or service relief devices

510: 3.1.62
In a RBI assessment, the two primary factors of risk are the:
Consequence of failure & Probability or failure

510: Sect 3
What is the difference between plate lining and strip lining?
Plate lining is wider than strip lining

510: Sect 3
Temper embrittlement occurs in certain material when:
The process temperatures exceed 650°F

510: Sect 3
Low chrome materials are subject to temper embrittlement. These materials are:
Brittle at low temperatures due to metallurgical changes that occur during high temperature operation

510: Sect 3
A pressure test used after maintenance work to assure that the equipment is leak free:
Is called a tightness test

510: Sect 3
Who is responsible to ensure that all API 510 requirements are met?
Owner / User

510: Sect 4
Who is responsible to ensure that the authorized inspection agency functions in accordance with the requirements of API 510?
Owner / User

510: Sect 4
Each owner / user that uses API 510 must:
Maintain a quality assurance inspection / repair management system

510: Sect 4
Which of the following is required to be in the owner / user's quality assurance inspection / repair management system?
Training requirements for inspection personnel

510: Sect 4
Who is responsible for implementing an effective management of change process?
Owner / user

510: Sect 4
A MOC system should be used to review and control changes made to:
Either the process or the hardware

510: Sect 4
Who is responsible for implementing an effective program for established integrity operating windows (IOW's)?
Owner / user

510: Sect 4
Who should be made aware of deviations outside the IOW's?
Inspection / Engineering personnel

510: Sect 4
When repairs and alterations are being conducted, which individuals and organizations is responsible for quality control?
Repair Organization

510: Sect 4
When repairs and alterations are being conducted, which individuals and organizations is responsible for validating that the materials meet the requirements of API 510?
Repair Organization

510: Sect 4
During a vessel's repair, all examination results must be accepted by the:
Authorized inspector

510: Sect 4
Which of the following is a role for the API 510 inspector?
Evaluate and accept NDE results

510: Sect 4
Who is responsible to maintain certification records for NDE examiners?
Examiner's employer

510: Sect 4
Each owner / user's organization should be audited:
Periodically

510: Sect 4
When an audit of the owner / user's organization is being conducted, the team members should be:
Third party auditors or employed at another owner / user site

510: Sect 4.7
The owner / user's should:
Establish a tracking mechanism for non-conformance found by the audit team

510: Sect 4
All in-service pressure vessels & pressure relief devices in the petrochemical industry must:
Have an inspection plan

510: Sect 5
The inspection plan for a pressure vessel should be developed by:
Either the inspector or the engineer

510: Sect 5
The inspection plan should be developed by:
Either the inspector or the engineer

510: Sect 5
When developing a vessel's inspection plan, who should help, when needed, to identify specific damage mechanisms and their locations?
Corrosion specialist

510: Sect 5
A significant factor in developing an inspection plan is to determine the:
Potential damage mechanisms

510: Sect 5
What is the most important factor when selecting the NDE to use in a future inspection?
Ability of the method to find the anticipated damage mechanisms

510: Sect 5
Which of the following is not a factor in determining the interval for examinations in a vessel's inspection plan?
Cost of equipment outage

510: Sect 5
Which of the following is not required to be included in a vessel's inspection plan?
Name of individual that will perform the inspection

510: Sect 5
Which of the following is not required in a vessel's inspection plan?
Lighting requirements

510: Sect 5
What "optional item" should really be part of a vessel's inspection plan?
Types of damage expected in the vessel

510: Sect 5
In the RBI process, what are the two primary factors used to determine risk?
Probability and Consequence of failure

510: Sect 5
Who is responsible to decide whether an RBI assessment will be used to determine inspection intervals for a pressure vessel?
Owner / User

510: Sect 5
RBI assessment should be done in accordance with:
API 580

510: Sect 5
Which of the following is not significant factor in an RBI assessment of a pressure vessel?
Vessel construction code

510: Sect 5
During a risk assessment, which of the following is not a significant factor in the probability of failure?
Amount of process fluid

510: Sect 5
During an RBI assessment of a pressure vessel, what are the two biggest factors of consequence of failure?
Product Type and Amount

510: Sect 5
During a RBI assessment, which of the following is not a significant factor in the consequence of failure?
Public image

510: Sect 5
All RBI assessments must be:
Thoroughly documented

510: Sect 5
The RBI shall be updated each time
significant process or hardware changes, and anytime an unanticipated failure occurs.

510: 5.2.5
Prior to performing an inspection the inspector should:
Familiarize themselves with prior history

510: Sect 5
Prior to performing an inspection, which of the following is not a requirement for the inspector?
Familiarize themselves with past inspection plans

510: Sect 5
Which of the following damage mechanisms creates either general or localized corrosion?
Naphthenic acid

510: Sect 5
Which damage mechanisms creates sub-surface cracking?
Wet hydrogen sulfide cracking

510: Sect 5
Which damage mechanisms creates micro-fissuring which leads to macro-cracking?
Creep

510: Sect 5
Vessels in cyclic services should be inspected for:
Fatigue

510: Sect 5
Which of the following vessels is most likely to be affected by thermal fatigue?
Coke drum

510: Sect 5
Deviations from an inspection plan should be approved by the:
Engineer or inspector

510: Sect 5
Who is responsible to perform the internal inspection on a pressure vessel?
Authorized inspector

510: Sect 5
An NDE examiner can:
Assist in the internal inspection when approved by the inspector

510: Sect 5
When may inspections from parts be substituted for the internal inspection?
Only if the vessel is too small to enter or all internal surfaces of the vessel can be clearly seen from the port

510: Sect 5
Prior to the internal inspection:
Some removable internals and some process deposits may not need to be removed

510: Sect 5
Who is responsible to determine whether process deposits should be removed prior to the internal inspection?
Inspector and the corrosion specialist

510: Sect 5
Which of the following describes the needed surface preparation before performing an internal inspection?
The amount to clean and the degree of cleanliness is based on expected type of degradation mechanism(s)?

510: Sect 5
Which of the following is true about the need to remove process deposits prior to internal inspection?
Amount to remove is based on whether deposits actually protect the shell or cause corrosion

510: Sect 5
Internal inspection is conducted on a refractory-lined vessel. How much refractory should be removed to check the condition of the vessel's internal surface?
Removal of refractory is not required unless there is a reason to suspect that corrosion under the refractory

510: Sect 5
Who is responsible to perform a vessel on-stream inspection?
Inspector or an examiner

510: Sect 5
All on-stream work performed by an examiner must be approved by the:
Inspector

510: Sect 5
On-stream inspections:
Can be performed while the vessel is pressurized or depressurized

510: Sect 5
Who is responsible to perform the external inspection on a pressure vessel?
Inspector or other qualified personnel

510: Sect 5
Personnel performing the external inspection must:
Be qualified by appropriate training

510: Sect 5
During the external inspection extra attention should be given to:
Attachment welds

510: Sect 5
Weep-holes in repads should:
should remain open to provide visual evidence of leakage & prevent pressure buildup behind the reinforcing plate.

510: Sect 5
The inspection interval for buried vessels is based on the:
assessment of the cathodic protection system and on corrosion rate

510: 5.5.4.2
Thickness measurements are taken to verify the:
Thickness of the vessel component

510: Sect 5
The inspector should consult with a corrosion specialist when:
The short-term corrosion rate changes significantly

510: Sect 5
Who must assure that personnel performing thickness readings are trained and qualified?
Owner / User

510: Sect 5
CUI Susceptible Temperature Range:
- 10° to 350°F CS & low alloy
- 140° to 350°F austenitic SS
- 280° to 350°F duplex SS
- 500°F for insulated vessels in intermittent service

510: 5.5.6.1
CUI of austenitic and duplex stainless steel vessels:
Normally appears as stress corrosion cracking

510: Sect 5
CUI damage:
Can be very unpredictable

510: Sect 5
External inspection is planned for an insulated vessel. How much insulation should be removed to check the conditions of the external surface?
Insulation removal is not required unless there is a reason to suspect that corrosion is occurring under the insulation

510: Sect 5
Which type of insulation is most likely to absorb and hold water?
Calcium silicate

510: Sect 5
A CML is a spot for:
Checking for various damage types, (wall loss, cracking, or HTHA)

510: Sect 5
Each pressure vessel shall be monitored by
a representative number of CML on heads, shell and nozzles.

510: 5.6.2.1
Which CML must always be included in the next planned inspection?
the highest corrosion rate and the lowest remaining life.

510: 5.6.2.1
Fewer CMLs can be selected for pressure vessels with
a) low safety/environmental emergency if it leaks.
b) noncorrosive contents,
c) generally uniform corrosion rates.

510: 5.6.3.1
UT thickness readings will be taken on a vessel. Which of the following best describes the process for taking readings at a specific examination point?
Take multiple readings and record the lowest reading or average of the set

510: Sect 5
CMLs should always:
Permanently marked on a drawing and/or on the vessel

510: Sect 5
Who should be consulted about placement and number of CMLs for vessels with suspected localized corrosion?
Corrosion specialist

510: Sect 5
Who should be consulted, if CMLs on a vessel are reduced/eliminated?
Corrosion specialist

510: 5.6.3.2
The NDE method called alternating current flux leakage is useful in finding:
Surface-breaking cracks

510: 5.7.1.1
The NDE method called advanced ultrasonic backscatter technique is useful for detecting:
high-temp hydrogen attack

510: Sect 5
Examiners performing UT flaw detection on welds on in-service vessel should be qualified to:
API QUTE/QUSE or equivalent

510: Sect 5
Which of the following form of degradation is most easily missed when performing a visual examination?
Uniform corrosion

510: 5.7.2.1
What is the preferred examination technique for determining the vessel wall thickness of a 60" I.D. vessel that has localized thinning?
UT scanning

510: Sect 5
What is a good technique for determining the nozzle wall thickness of an insulated 6 NPS nozzle that has localized thinning?
Profile RT

510: Sect 5
Thickness readings are taken using UT. At what temperature should special procedures be used in order to ensure accurate readings?
Above 150°F

510: 5.7.2.3
A pressure test is normally conducted:
after an alteration or major repair

510: 5.8.2.1
A pressure test shall be conducted after:
Repairs (other than major repairs) when the inspector believes on is necessary

510: 5.8.2.1
A nozzle has been added to the vessel. Instead of pressure testing the entire vessel, just the nozzle will be pressure tested (temporary cap welded on the inside of the vessel). This requires the approval of:
the engineer

510: 5.8.2.2
An alteration has been made on a vessel that was built to ASME section VIII, 1990 edition. A hydrotest will be conducted. What is the recommended test pressure?
150% of MAWP corrected for temperature

510: 5.8.3.1
An alteration has been made on a vessel that was built to ASME section VIII, 2004 edition. A hydrotest will be conducted. What is the recommended test pressure?
130% of MAWP corrected for temperature

510: 5.8.3.1
A major repair has been completed on a vessel that was built to ASME sect. VII, 1990 edition. In 2007 the vessel was rerated to the 2007 edition of sect. VIII. A hydrotest will be conducted. What is the recommended test pressure?
130% of MAWP corrected for temperature

510: 5.8.3.1
A hydrotest is conducted on an exchanger shell to check for roll leaks. What is the recommended test pressure?
At a pressure specified by the owner / user

510: 5.8.3.2
When a tightness test is performed on a vessel, the test pressure is:
Specified by the owner / user

510: 5.8.3.2
During pressure test, a close visual inspection should be conducted:
at or below the vessel MAWP

510: 5.8.4.1
An alternative to removing/blinding PRDs during hydrotest is to use test clamps to hold down the valve disks.
Applying an additional load to the valve spring by turning the compression screw is prohibited.

510: Sect 5
To min. risk of vessel brittle/fracture during Hydrotest, metal temperature should be at least:
- 30°F above MDMT/MAT for vessels > 2"Thick.
- 10°F above MDMT/MAT for vessels </= 2 in.
- test temperature need not exceed 120°F needed.

510: 5.8.7.2
When hydrotesting solid or clad austenitic stainless steel, the water temperature should not exceed
120 °F to prevent possible chloride stress corrosion cracking.

510: 5.8.7.3
A hydrotest is conducted on an austenitic SS vessel. What is the maximum allowed content of chloride in the hydrotest water?
50 ppm

510: Sect 5
Which of the following is not a good reason for substituting a pneumatic test for a hydrotest?
Less expensive

510: Sect 5
Which of the following is true when pneumatic testing is performed after a major repair on a vessel that has a shell that is 0.375" thick?
An engineer should develop a specific procedure

510: Sect 5
Brittle fracture usually have occurred:
During the first hydrotest or overload

510: Sect 5
Which of the following materials is most prone to temper embrittlement
Low chromes

510: Sect 5
A hydrotest is performed on an existing vessel following the replacement of a shell plate. The vessel is 1-1/2" thick. What is the minimum allowed metal temperature during the test?
10°F above the vessel's MDMT

510: Sect 5
A hydrotest is performed on a vessel following the replacement of a 2.5" thick head. What is the minimum allowed metal temperature during the test?
30°F above the vessel's MDMT

510: Sect 5
A hydrotest is performed on a vessel with austenitic SS cladding. What is the maximum allowed water temperature?
120°F

510: Sect 5
NDE is substituted for a pressure test after a major repair on an in-service vessel. Who must approve this substitution?
The inspector AND the engineer

510: Sect 5
Per API 510, during repairs and alterations, the inspector shall verify that the new materials being used are correct. What is the minimum amount of verification that inspector shall perform?
A sampling of all metallurgy's

510: Sect 5
During repairs and alterations, who determines the percentage of new materials to check for conformance to specifications?
Inspector or Owner / user

510: Sect 5
Who should perform PMI?
Examiner or inspector

510: Sect 5
What document provides additional guidance about materials verification?
API 578

510: Sect 5
An existing vessel component fails. Analysis of the failure determines that an incorrect material was inadvertently substituted during fabrication. Who should determine whether other components should be checked for correct metallurgy?
Inspector

510: 5.10.3
Crack-like flaws and environmental cracking shall be assessed by:
an engineer and/or corrosion specialist

510: Sect 5
During an in-service inspection, preferential corrosion was discovered in a weld. This imperfection shall be evaluated:
By an inspector

510: Sect 5
Flange leaks in certain fluids can cause:
Bolts to crack or corrode

510: Sect 5
A leaking flange was repaired by a leak sealing company that pumped sealant in the gasket area. Later the flange leaks again. What should be done?
Examine bolts with UT prior to repumping

510: Sect 5
Flange bolts are unacceptable if the lack of engagement exceeds:
1 thread

510: Sect 5
Additional guidance on the inspection and repair of flanged joints can be found in:
ASME PCC-1

510: Sect 5
A new vessel is installed. An API 510 inspector shall inspect the vessel at the time of installation. Which of the following is not required during this inspection?
Verify internal components meet design requirements.

510: Sect 6
The internal inspection interval must be reviewed whenever changes occur that could affect the degradation of the vessel. In which of the following situations does a review of the internal interval not need to be conducted?
Operating pressure decreases

510: Sect 6
When must both an internal and external inspection always be performed?
Whenever the vessel's ownership and location change.

510: 6.2.2.2
Internal and External inspection interval based on an RBI assessment can:
Exceed 10 years.

510: Sect 6
RBI based internal inspection interval must be reviewed and approved by the:
engineer and inspector not exceeding 10 years. More often if warranted by service/changes etc.

510: 6.3.2
An RBI assessment extends the internal interval beyond the 10 year limit. When reassessment is done, it must be reviewed and approved by:
Both the authorized inspector and the pressure vessel engineer

510: Sect 6
The maximum External Inspection interval is the :
LESSER of 5yrs, OR next Internal inspection interval

510: 6.4.1
The remaining life of a vessel is 12 years. What is the maximum interval for the external inspection?
5 years

510: Sect 6
The remaining life of a vessel is 8 years. What is the maximum interval for the external inspection?
4 years

510: Sect 6
The remaining life of a vessel is 3 years. What is the maximum interval for the external inspection?
2 years
(if < four years, interval may be the full remaining life up to a maximum of two years)

510: 6.5.1.1
Vessel retired in place:
Need external inspections only if deterioration of vessel could be hazardous to personnel.

510: Sect 6
Who establishes the interval for the internal & external inspection?
Either the inspector or the engineer

510: Sect 6
What is the maximum inspection interval for the internal inspection? ( no RBI analysis has been performed)
Lesser of 10 years or half life

510: Sect 6
When the remaining life of a vessel is 3 years, what is the maximum inspection interval for the internal inspection?
2 years
(if < four years, interval may be the full remaining life up to a maximum of two years)

510: 6.5.1.1
The remaining life of a vessel is 8 years. What is the maximum interval for the internal inspection?
4 years

510: Sect 6
The remaining life of a vessel is 12 years. What is the maximum interval for the internal inspection?
6 years
(interval shall be the LESSER of 1/2 life or 10years)

510: 6.5.1.1
The remaining life of a vessel is 24 years. What is the maximum interval for the internal inspection?
10 years

510: Sect 6
Who establishes the interval for the internal or on stream inspections?
Either the inspector of the engineer

510: Sect 6
An internal inspection interval for a vessel in intermittent service is 8 years. The vessel will be out of service 50% of the time. When out of service, the vessel will be drained and protected from internal process corrosion. The next internal inspection should be conducted in:
8 years of service (16 calendar years)
(This answer based on 1/2 life)

510: Sect 6
A vessel is in non continuous service. Internal inspection interval is based on "years of service" vs. "calendar years" when out of service the vessel is:
- Isolated from the process
- Not exposed to corrosive environment

510: 6.5.1.2
An on stream inspection may be substituted for the internal inspection provided this substitution is approved by:
The inspector

510: Sect 6
On stream inspection may be substituted for an internal inspection (without doing an RBI assessment) when:
a) Entry not possible
b) Entry is possible and:
- Corrosion rate is less then 0.005 ipy
- remaining life > 10yrs
- 5yrs corrosive rate by similar/same service is known
- external inspection is good
- ops temps does not exceed lower temps for creep
- vessel not subjected to hydrogen/envir cracking
- no nonintegrally bonded liner (ie strip/plate lining)


510: 6.5.2.1
Unless an RBI assessment was performed, an on stream inspection cannot be substituted for an internal inspection unless the remaining life exceeds:
10 years

510: 6.5.2.1
Unless an RBI assessment was performed, when can an on stream inspection not be substituted for an internal inspection?
Vessel was previously repaired with strip lining or is subject to environmental cracking

510: Sect 6
Which of the following is not allowed by API 510?
Apply inspection data from one Owner / User to similar service vessel for another Owner / User

510: Sect 6
A large vessel has a lower clad section which is experiencing no corrosion. The upper section is not clad and has a remaining life of 12 years. Which of the following best describes the required interval for the internal inspection?
The upper section must be inspected in 6 years, and the lower section must be inspected in 10 years.

510: Sect 6
Which of the following is not a requirement for the organization that repairs relief devices?
Maintain a contract with a 3rd party inspection company

510: Sect 6
Per API 510, a relief device repair organization must:
Have a fully documented quality assurance process and training program.

510: Sect 6
Who establishes the interval for the inspections interval for relief devices?
Either the inspector or engineer or qualified others

510: Sect 6
Relief device intervals are based on:
by either the inspector, engineer, or other qualified individual per the owner/user's QA system.

510: 6.6.3.1
The inspection intervals for pressure-relieving devices in typical process services should not exceed:
a) 5 years for typical process services, and
b) 10 years for clean (nonfouling) and noncorrosive services.

510: 6.6.3.2
The maximum inspection interval for a pressure relief device in clean, non corrosive and non fouling service is:
Based on the performance of the device with a maximum interval of 10 years

510: Sect 6
Pressure relief devices inspection interval can be:
deferred if risk assessment supports the deferral

510: Sect 6
Which of the following is not a requirement for deferring intervals?
The engineer and Owner / User must approve the deferred interval

510: Sect 6
An inspection interval is being deferred for 16 months. Who must concur with this interval deferral?
Both the inspector and Owner / User management

510: Sect 6
Pressure Relief Device servicing interval may be deferred by inspector as the sole approver when:
deferred interval is lesser of 6 months or 10% of the existing interval

510: 6.7
PRD inspection interval deferrals should:
Only be an occasional exception not a frequent occurrence.

510: Sect 6
Per API 510, overdue inspection intervals are:
Not allowed

510: Sect 6
Inspection repair recommendations that are deferred beyond the specific due date, requires the concurrence of:
Both the inspector and inspection supervisor

510: Sect 6
Pressure-relieving Devices, overdue inspection recommendations are:
Not allowed

510: Sect 6
Inspection recommendations can be changed or deleted after a review by:
The pressure vessel engineer or inspection supervisor

510: Sect 6
During remaining life calculations, selecting whether to use short term or long term corrosion rates is determined by the:
Inspector

510: Sect 7
A vessel was installed in 1986 in a hydrocarbon service. Base line thickness readings were taken. In 2005 the vessel was moved to a chemical service. Thickness readings were again taken. When determining the long term corrosion rate, which reading should be considered the "initial thickness"?
2005 readings

510: Sect 7
When the short term and long term corrosion rates differ, who should determine which rate to use in the remaining life calculation?
Both the authorized inspector and the corrosion specialist

510: Sect 7
A vessel's service has changed. The inspector must obtain a probable corrosion rate for the new operation. Which of the following is not an acceptable way to establish the corrosion rate for the new service?
Per owner's QA manual

510: Sect 7
A vessel's service has changed. The inspector must obtain a probable corrosion rate for the new operation. Which of the following is the preferred way to establish the corrosion rate for the new service?
Similar service

510: Sect 7
A vessel's service has changed. The inspector must obtain a probable corrosion rate for the new operation. Which of the following is the least desirable way to establish the corrosion rate for the new service?
Inspect after 3-6 months

510: Sect 7
Which of the following is true concerning using a statistical analysis of thickness data to determine the vessel's controlling corrosion rate and remaining life?
May not be applicable if corrosion is random, localized and deep.

510: Sect 7
Max.Allow.WorkingPressure Determination
In corrosive service, the wall thickness used in these computations shall be
the actual thickness minus twice the estimated corrosion loss before the date of the next inspection

510: 7.3.3
Evaluating of Locally Thinned Area
Corrosion readings averaging can be used when:
— no notches in corr area (relatively smooth contour)
— equipment does not operates in creep range,
— equipment not in cyclic service,
— a min. 15 thickness readings should be used
— lowest reading must be used.
— lowest reading > 50 % of trequired.

510: 7.4.2.2
Evaluation of Locally Thinned Areas
Corroded area may be averaged over a length not exceeding the following:
— 1/2 vessel dia. or 20" for vessels 60" ID or less.
— 1/3 vessel dia. or 40" for vessels > 60" ID.

510: 7.4.2.1
Corrosion averaging is being done to evaluate a corroded area per API 510. What is the minimum number of thickness measurements needed in the data set?
15 readings

510: Sect 7
The API 510 corrosion averaging process can be used to evaluate a locally thinned area provided that there is no area that has a thickness less than:
50% Tmin

510: Sect 7
Corrosion averaging is used to evaluate a corroded area on a 96" diameter vertical vessel that is 32' in height. Per API 510, how should the corrosion averaging lines be drawn?
Longitudinally

510: Sect 7
Corrosion averaging is being done to evaluate a corroded area per API 510. When drawing the lines for averaging they should not cross:
Into the limits of reinforcement near a nozzle

510: Sect 7
An inspector is evaluating a corroded area on a vessel per API 510. The area is marked off in a grid with five longitudinal lines. Eight thickness readings are taken on each longitudinal line. When performing corrosion rate calculations for this area, the reading to use as the "current thickness" in the remaining life calculation is the:
Averaging thickness of the longitudinal line with the lowest averages.

510: Sect 7
A widely scattered pitting on a vessel can be ignored provided the:
Remaining thickness at pit not less than 1/2 tRequirded

510: Sect 7
Scattered pitting deeper than corrosion allowance can be ignored provided area of the pitting does not exceed:
7 in² in an 8 inch circle

510: Sect 7
Aligned pits are rejectable when the sum of their dimensions deeper than the corrosion allowance exceeds:
2" in an 8" line

510: Sect 7
Which of the following codes cannot be used to evaluate a corroded area?
ASME B&PV code section XI

510: Sect 7
An engineer is evaluating a pitted area using ASME section VIII-Division 2. The original design stress is less than 2/3 of the yield stress of the material. What stress value should the engineer use in the Section VIII-Div 2 calculations?
Original design stress

510: Sect 7
An engineer is evaluating a pitted area using ASME section VIII-Division 2. The original design stress is greater than 2/3 of the yield stress of the material. What stress value should the engineer use in the Section VIII-Div 2 calculations?
2/3 of the yield stress

510: Sect 7
A vessel has a shell that was designed using a joint efficiency of 0.85. There is a corroded area in the vessel that needs evaluating. When calculating the minimum required thickness for this corroded area, what joint efficiency should be used?
May use an "E" of 1.0 if the corroded area is far from a weld

510: Sect 7
When calculating the required thickness for a corroded area, an E of 1.0 can be used provided the corroded area is:
Away from all welds by the greater of 1" or twice the metal thickness

510: Sect 7
An engineer is calculating the minimum required thickness in a corroded area in the knuckle of an ellipsoidal head. What formula should be used?
Rating code elliptical head formula

510: Sect 7
An engineer is calculating the minimum required thickness in a corroded area on an ellipsoidal head. What formula should be used if the corroded area is in the center portion of the head?
Rating code hemi-head formula

510: Sect 7
A corroded area is in the central portion of an elliptical head. The minimum required thickness can be calculated using the rating code's hemi-head formula and making some adjustments to the radius. API 510 defines the central portion of the head as the center:
80% of the head

510: Sect 7
A corroded area is in the central portion of a 2:1 elliptical head. When calculating the minimum required thickness, what "K factor" should be used? (Note! "KxD" is used to replace "Radius" in the formula)
0.90

510: Sect 7
Which code should be used to evaluate whether a cracked weld is acceptable for continued service?
API 579

510: Sect 7
If an in service vessel does not have fabrication records, the minimum required thickness of the components should be calculated. When determining the allowable stress, do not select an allowable stress based on:
A 3.5 safety factor

510: Sect 7
If an in service vessel does not have a nameplate or adequate fabrication records, the minimum required thickness should be calculated. If the joint efficiency is unknown, what joint efficiency should be uses to calculate a shell made with plate that has double welded butt welds?
0.70

510: Sect 7
If an in service vessel does not have a nameplate or adequate fabrication records, the minimum required thickness should be calculated. If the joint efficiency is unknown, what joint efficiency can be used to calculate the required thickness of a seamless head?
0.85

510: Sect 7
If an in service carbon steel vessel does not have a nameplate or adequate fabrication records, the minimum required thickness should be calculated. If the exact material is unknown, the allowable stress should be based on what material?
SA-281 - Grade C

510: Sect 7
Who is responsible to maintain records for vessels and relief devices?
Owner / User

510: Sect 7
API 510 requires which of the following names to be documented in the equipment records?
Name of person performing NDE examinations on in service vessel

510: Sect 7
THIS SET IS OFTEN IN FOLDERS WITH...