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570 Study Guide

Terms in this set (352)

Which of the following is b. Inspection, repair, alteration, and rerating of

covered by API 570? inservice piping.

a. New construction of piping.

b. Inspection, repair, alteration,

and rerating of inservice
piping.

c. Inspection of inservice
piping.

d. Repair and alteration of

piping.

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API 570 was developed for use d. All of the above.

by which of the following?

a. The petrochemical industries.

b. Where practical for any

piping system.

c. Organizations which have

access to an authorized
inspections agency, a repair
organization, and
technically qualified engineers

d. All of the above.

Is it permissible to substitute d. No.

the requirements of API 570 for
the construction code
requirements prior to the
piping
system being placed in
service?

a. Yes.

b. Yes, provided the

Engineering department
agrees.

c. Yes, with the inspectors

permission.

d. No.

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Which of the following services c. Water, steam, boiler feed water, and Category D
is not included under the fluid services as defined in ASME B31.3.
requirements of API 570?

a. Raw, intermediate or finished

petroleum of chemical
products.

b. Hazardous chemicals and

sour water above threshold
limits per jurisdictional
regulations.

c. Water, steam, boiler feed

water, and Category D fluid
services as defined in ASME
B31.3.

d. Hydrogen, natural gas, fuel

gas, and flare lines.

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Which of the following types of a. Catalyst lines.

services or classes of piping
are not optional or excluded
from coverage under the
requirements of API 570?

a. Catalyst lines.

b. Piping systems on moveable

structures.

c. Piping systems forming an

integral part of rotating
machinery.

d. Internal piping of heaters,

boilers or pressure vessels.

Who is responsible for meeting c. The Owner-User.

the requirements of API 570?

a. The Inspector.

b. The Engineer.

c. The Owner-User.

d. The Jurisdiction.

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To whom is the piping engineer b. The Owner-User.

responsible in regards to
design, engineering review or
analysis of piping systems?

a. The Inspector.

b. The Owner-User.

c. The Jurisdiction.

d. The API.

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Which of the following is not a c. Six years of experience in inspecting in service

requirement for being qualified piping systems.
as an API 570 Inspector

a. An engineering degree and

one year of experience in
design, construction, repair,
maintenance, or inspection of
piping systems.

b. A two year certificate in

engineering or technology and
two years of experience in the
design, construction,
repair, operation, or inspection
of piping systems.

c. Six years of experience in

inspecting in service piping
systems.

d. The equivalent of a high

school diploma and three
years of experience in the
design, construction, repair,
operation or inspection of
piping systems.

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Under the requirements of API c. Other personnel are responsible for making the
570, what responsibilities do Inspector and Engineer aware of any unusual
personnel other than the conditions.
Inspector, Engineer, and
Repair Organization have?

a. None.

b. All other personnel are

subject to the same
requirements as the Inspector.

c. Other personnel are

responsible for making the
Inspector and Engineer aware
of any unusual conditions.

d. They are responsible to the

jurisdiction for reporting any
Code violations.

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Which of the following is d. All of the above.

required prior to performing
any inspection work on a
piping system?

a. Appropriate safety
precautions should be taken
prior to opening any system for
internal inspection.

b. Permission from operations

personnel must be obtained.

c. PPE as required must be

worn and inspection
equipment must meet
requirements of the facility for
electrical
equipment, where applicable.

d. All of the above.

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Prior to making an inspection b. Review the past inspection results and repair
of a piping system, the history of the system.
inspector should:

a. Require a hydrostatic
pressure test of the system.

b. Review the past inspection

results and repair history of the
system.

c. Schedule a full UT survey of

the line.

d. All of the above.

Injection points, deadlegs, and b. Specific attention as determined from past

soil to air interfaces all require: inspections.

a. Annual UT surveys.

b. Specific attention as
determined from past
inspections.

c. Elimination by redesign of
the system.

d. Specific approval by the API

570 certified inspector.

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Injection point circuits should The greater of 12" or three pipe diameters.
extend how far upstream?

a. 12".

b. Three pipe diameters.

c. The greater of 12" or three

pipe diameters.

d. The lessor of three pipe

diameters or 12".

How far downstream should an d. The lessor of a and b.

injection point circuit extend?

a. To the second change in

flow direction.

b. 25 feet beyond the first

change in flow direction.

c. The greater of a and b.

d. The lessor of a and b.

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Where should TML's be d. All of the above.

established on injection point
circuits?

a. At the upstream and

downstream limits of the
injection point circuit.

b. At the point of impingement

of the injected fluid and on
appropriate fittings within the
injection point circuit.

c. At intermediate locations
along longer straight runs.

d. All of the above.

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Why are injection points more a. Due to accelerated or localized corrosion due to
of a concern than other areas normal or abnormal operating conditions.
of the piping system?

a. Due to accelerated or
localized corrosion due to
normal or abnormal operating
conditions.

b. Because all injection points

are subject to higher than
normal temperature due to
reactions with the injected
fluid.

c. Due to stresses produced in

the piping system from the
installation of the injection
point.

d. Because of jurisdictional
requirements for handling the
toxic injection fluids.

To whom is the Inspector b. The Owner-User.

responsible under the
requirements of API 570?

a. The API.

b. The Owner-User.

c. The Jurisdiction.

d. The Engineer.
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Is it permissible to treat an a. Yes.

injection point as a separate
circuit from the piping system
in which it is installed?

a. Yes.

b. Yes, provided the jurisdiction

approves.

c. Yes, with the approval of the

API 570 Inspector.

d. No.

Which of the following are the b. RT or UT to establish the minimum thickness.

preferred methods for
inspecting injection point
TML's?

a. Visual Inspection.

b. RT or UT to establish the
minimum thickness.

c. Hammer Testing.

d. Internal Inspection.

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To whom is the repair b. The Owner-User.

organization responsible?

a. The Inspector.

b. The Owner-User.

c. The Jurisdiction.

d. The API.

During periodic scheduled a. Extensive inspection of the area 12" above and 10
inspections, which of the pipe diameters downstream of the injection point in
following is recommended by
API

a. Extensive inspection of the

area 12" above and 10 pipe
diameters downstream of the
injection point in
addition to thickness readings
at all TML's.

b. Recording thickness
readings at established TML's
only, unless further
investigation is required.

c. Full UT or RT inspection of
the entire injection point circuit.

d. Take one thickness reading

at each TML

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The corrosion rate in deadlegs d. Different from the adjacent active piping.
is normally:

a. Higher than in the adjacent

active piping.

b. Lower than in the adjacent

active piping.

c. Very low due to low flow

conditions.

d. Different from the adjacent

active piping.

When taking thickness readings d. Along the entire length of the deadleg.
on deadlegs, thickness
readings should be taken at:

a. The stagnant end.

b. The end connected to the

adjacent active line.

c. In the center.

d. Along the entire length of

the deadleg.

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Corrosion may occur at high b. Convective currents.

points in deadlegs in hot
systems due to:

a. Trapping corrosive vapors at

the high points.

b. Convective currents.

c. Steam accumulation.

d. All of the above.

External inspection of insulated d. All of the above.

piping systems susceptible to
CUI should include which of
the following?

a. The integrity of the insulation

system.

b. Signs of CUI.

c. Sources of moisture.

d. All of the above.

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Which of the following are the b. Localized corrosion of carbon steels and stress
most common forms of corrosion cracking of austenitic stainless steels.
corrosion under insulation?

a. Stress corrosion cracking of

carbon and austenitic stainless
steels.

b. Localized corrosion of
carbon steels and stress
corrosion cracking of austenitic
stainless steels.

c. Oxygen pitting of carbon

and stainless steels.

d. Intergranular corrosion of
stainless steels and pitting of
carbon steels.

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Which of the following c. Carbon steel piping systems operating over 350
examples of piping systems degrees F.
would be the least susceptible
to CUI

a. Systems exposed to cooling

water tower mist, steam vents,
or deluge systems.

b. Systems subject to process

spills, acid vapors, and ingress
of moisture.

c. Carbon steel piping systems

operating over 350 degrees F.

d. Austenitic stainless steel

piping operating between 150
and 400 degrees F.

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While inspecting a piping b. Moisture could enter the insulation and cause
system, you notice that the corrosion of the piping system.
insulation jacketing is damaged
and that the caulking at the
joints is damaged and the
insulation is damp. What would
you be concerned about

a. Nothing, insulation is not a

pressure part.

b. Moisture could enter the

insulation and cause corrosion
of the piping system.

c. Product leakage.

d. None of the above.

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Which of the following would d. All of the above.

be susceptible to CUI on a
carbon steel line operating at
300 degrees F?

a. Areas of the system which

are in intermittent service

b. Areas where deadlegs and

attachments operate at lower
temperatures that the rest of
the system.

c. Areas of the line which may

have steam tracing.

d. All of the above.

Which of the following c. The Owner-User.

exercises control over the
piping inspection program and
inspection frequencies in
accordance with API 570?

a. The Inspector.

b. The Piping Engineer.

c. The Owner-User.

d. The Jurisdiction.

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What would you suspect if b. Corrosion products have built up, thus bulging
while inspecting an insulated the insulation.
line you notice a bulged area?

a. A product leak has occurred.

b. Corrosion products have

built up, thus bulging the
insulation.

c. A stream tracing line has

ruptured.

d. The insulation had been

removed and replaced at some
point.

When completing an UT c. Reinstalled and sealed immediately.

thickness measurement on an
insulated piping system, the
plugs should be:

a. Left out if the next inspection

will be made within 6 months.

b. Reinstalled immediately.

c. Reinstalled and sealed

immediately.

d. Discarded.

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If significant corrosion is noted a. The line should be partially excavated to

on an air to soil interface, what determine if the corrosion is present only at the air
action should be taken soil interface
or is common to the entire system.
a. The line should be partially
excavated to determine if the
corrosion is present only at the
air soil interface
or is common to the entire
system.

b. The air to soil interface

should be sand blasted and
coated to prevent further
corrosion.

c. The air to soil interface

should be encased in concrete
to prevent further corrosion.

d. Weld build up of the

affected area should be
considered.

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Buried piping without c. Requires that all air to soil interfaces be included
adequate cathodic protection in the scheduled external inspections.
requires:

a. Installation of a cathodic
protection system in
accordance with the
requirements of API 570.

b. Periodic excavation for

inspection.

c. Requires that all air to soil

interfaces be included in the
scheduled external
inspections.

d. Installation of wrapping to
protect the pipe.

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When is it necessary to c. When there is evidence of coating or wrapping

excavate the air to soil damage.
interfaces on piping systems
with satisfactory cathodic
protection?

a. At each scheduled
inspection.

b. Every three years to comply

with API 570.

c. When there is evidence of

coating or wrapping damage.

d. Whenever the service

conditions change.

Who controls the maintenance c. The Owner-User.

activities related to repair,
alteration and rerating?

a. The inspector.

b. The Engineer.

c. The Owner-User.

d. The Repair Organization.

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While inspecting a 20 year old a. Excavate the area to inspect for corrosion before
piping system without cathodic resealing the joint.
protection, you notice that the
caulking around the
pipe at the concrete has
deteriorated. What actions
would you recommend?

a. Excavate the area to inspect

for corrosion before resealing
the joint.

b. Reseal the joint and examine

other air to concrete interfaces
in the area.

c. No action is required, the

caulking is not intended as a
weather seal.

d. Recommend replacement of
the underground line with an
aboveground line.

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When buried piping which is un d. 6 to 12 inches should be uncovered to look for

coated at the grade level is hidden damage.
discovered, how far should the
line be excavated?

a. No excavation is required if
there is no visible corrosion.

b. 6 to 12 feet should be
uncovered to look for hidden
damage.

c. 2 to 4 feet should be
uncovered to look for hidden
damage.

d. 6 to 12 inches should be
uncovered to look for hidden
damage.

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Which of the following items is c. Continuous inspection of affected systems.

not critical to effective service
specific and localized
corrosion inspection?

a. An inspector with the

knowledge of the service and
where corrosion is likely to
occur.

b. Extensive use of NDE.

c. Continuous inspection of
affected systems.

d. Communication from
operations personnel when
process upsets occur.

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As an API 570 inspector,what c. The welds in the non post weld heat treated areas
action would you recommend should be inspected for cracking.
if you were inspecting a
carbon steel piping system in
which caustic could carry over
into non post weld heat
treated areas?

a. No special action is required

as TML's will have been
established in all areas of the
line.

b. The entire line should be

fully inspected.

c. The welds in the non post

weld heat treated areas
should be inspected for
cracking.

d. The non post weld heat

treated areas of the system
should be condemned due to
caustic cracking.

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Areas where the dew point a. Localized corrosion.

occurs, ammonium salts
condense in hydroprocess
streams, or mixed phase flow
or
turbulent areas in acids
systems can result in which of
the following?

a. Localized corrosion.

b. Embrittlement of the welds.

c. Decarburization of the base

metal.

d. All of the above.

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In crude oil services at or b. A 106 is a silicon killed steel which resists

above 450 degrees F corrosion better in this service.
containing sulfur in amounts
greater than .5% by weight, A
106
piping is preferred to A 53 or
API 5L piping for which of the
following reasons?

a. A 106 is 40% stronger at

higher temperatures.

b. A 106 is a silicon killed steel

which resists corrosion better
in this service.

c. A 106 has a finer grain

structure resulting in better
ductility at high temperatures.

d. A 106 has 3.5% nickel to give

it better strength and corrosion
resistance.

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As an inspector, to what area a. To any low flow areas where hot spots can
would you pay particular develop.
attention while inspecting a
carbon steel caustic system
with
steam tracing installed?

a. To any low flow areas where

hot spots can develop.

b. All along the steam tracing

UT readings should be
taken to look for localized
corrosion.

c. At all welds where the steam

tracing crosses due to the
possibility for caustic cracking
of the welds.

d. At all areas where the steam

tracing is not in close contact
with the pipe, causing cold
spots and condensation
corrosion.

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Erosion is defined as which of c. The removal of a material by the impact of solids,

the following? liquids, or gases.

a. An electrochemical action
which dissolves the metal.

b. The removal of metal by the

impact of solids.

c. The removal of a material by

the impact of solids, liquids, or
gases.

d. A combination of
electrochemical action and the
impact of solids.

In which of the following areas c. In turbulent areas.

is erosion most likely to occur?

a. Upstream of control valves

where flashing is taking place.

b. Upstream of pump
discharges.

c. In turbulent areas.

d. Upstream of orifices.

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Which of the following c. Upstream of control valves, pump discharges,

locations would you not and orifices.
expect to find an erosion
problem in a piping system?

a. At points of flow direction

change.

b. Downstream of control
valves, pump discharges, or
orifices.

c. Upstream of control valves,

pump discharges, and orifices.

d. In velocity sensitive systems

such as ammonium
hydrosulfide or sulfuric acid.

Which of the following c. Combination corrosion and erosion.

generally produces the highest
rates of metal loss?

a. Corrosion.

b. Erosion.

c. Combination corrosion and

erosion.

d. Metal loss rates for

corrosion, erosion, and
combination corrosion/erosion
are the same.

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When an area is suspected of b. UT scanning or profile RT of areas suspected of

having a localized corrosion having localized corrosion.
problem, which of the
following NDE methods is
most
appropriate?

a. Use of the existing TML's for

locating the localized
corrosion.

b. UT scanning or profile RT of
areas suspected of having
localized corrosion.

c. UT or RT of the entire system.

d. Disassembly of the system

for internal visual inspection.

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Which of the following is not b. Cracking due to residual stress from fabrication.
classified as an environmental
cracking problem?

a. External chloride stress

corrosion cracking of stainless
steels due to moisture and
chlorides under insulation.

b. Cracking due to residual

stress from fabrication.

c. Hydrogen blistering and or

cracking.

d. Caustic, amine, or carbonate

cracking.

Polythionic acid causes which f b. Surface connected cracking.

the following in sensitized
stainless steels?

a. Embrittlement.

b. Surface connected cracking.

c. Corrosion and pitting.

d. Intergranular corrosion.

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What type of supplemental d. Any of the above.

inspections would you
recommend on piping spools
susceptible to environmental
cracking?

a. Liquid penetrant or magnetic

particle testing.

b. Ultrasonic flaw detection.

c. Remove and split selected

pipe spools.

d. Any of the above.

When is it necessary to remove a. When there is reason to suspect a deteriorated

internal or external coatings, condition behind them.
refractory linings, or corrosion
resistant linings from
piping for inspection

a. When there is reason to

suspect a deteriorated
condition behind them.

b. Each time an internal

inspection is performed.

c. Every three years in

accordance with API 570.

d. When any area of the

coating or lining is found to be
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Which of the following should d. All of the above.

be checked when inspecting a
corrosion resistant lining?

a. Separation or disbonding.

b. Holes or breaks.

c. Peeling or other failure.

d. All of the above.

What does separation or c. Corrosion of the base metal.

bulging of refractory usually
indicate?

a. Loose refractory.

b. Blistered base metal.

c. Corrosion of the base metal.

d. Pressure buildup behind the

refractory.

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If a bulged or separated area c. Remove the refractory to inspect the underlying

of refractory is found, what base metal.
action should be taken?

a. Replace the affected area.

b. Drive the refractory back in

place and install new anchors.

c. Remove the refractory to

inspect the underlying base
metal.

d. No action is necessary if the

refractory stays in place.

When operating deposits are d. Deposits should be removed in selected areas to

present on a pipe surface, what check for corrosion underneath.
action should be taken?

a. Deposits should be left in

place to protect the underlying
pipe.

b. Any deposits remaining on

the pipe should be removed to
permit a complete inspection.

c. Deposits are to be removed

at the direction of operations
personnel for process reasons.

d. Deposits should be removed

in selected areas to check for
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Which is the preferred method a. UT or RT of suspected corrosion areas.

for checking for corrosion
under deposits in smaller lines?

a. UT or RT of suspected
corrosion areas.

b. Hammer testing for thin

areas.

c. Splitting the lines to check

for corrosion visually.

d. Borescope inspections of
the line

Upon which of the following c. Large diameter systems such as catalyst lines and
types of lines is it sometimes transfer lines.
possible or practical to
perform internal inspections?

a. Deadlegs.

b. Injection points.

c. Large diameter systems such

as catalyst lines and transfer
lines.

d. Normal process piping.

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Which of the following are d. All of the above.

methods used to conduct
internal inspections of piping
systems?

a. Physically entering large

diameter lines.

b. Using remote visual

inspection techniques or
splitting piping too small to
enter.

c. Looking inside the piping

through disconnected flanges
and fittings.

d. All of the above.

When may thickness c. When the system is either in or out of service.

measurements be obtained on
piping systems?

a. When the system is out of

service.

b. When the system is in

service.

c. When the system is either in

or out of service.

d. When requested by
operations personnel.
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Who is required to take the a. The inspector or examiner.

thickness measurements on
piping systems per API 570?

a. The inspector or examiner.

b. Maintenance personnel.

c. Operations personnel.

d. Any of the above.

Which of the following cannot c. Fouling in the line.

be determined by external
visual inspection of a piping
system?

a. The condition of the piping

exterior.

b. The condition of the

insulation.

c. Fouling in the line.

d. The condition of the coating.

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When corrosion product a. Arrange to have the pipe lifted off the supports
buildup is noted at pipe for inspection.
supports, what action should
be recommended by the
inspector?

a. Arrange to have the pipe

lifted off the supports for
inspection.

b. Seal the pipe to the support

with caulking to prevent further
corrosion.

c. Have the support removed

to prevent the problem from
recurring.

d. Recommend replacement of
the deteriorated pipe spool.

Which of the following c. API 574 Appendix E.

documents provides an
external inspection checklist?

a. API 570 Appendix E.

b. ASME B 31.3.

c. API 574 Appendix E.

d. ASME B 16.5.

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Which of the following is not d. Determining the load applied by the piping to the
normally checked when hangers.
making and external inspection
of piping?

a. Cracked or broken hangers.

b. Spring supports which have

bottomed out.

c. Support shoes displaced

from support members.

d. Determining the load

applied by the piping to the
hangers.

Vertical and horizontal support d. All of the above.

dummy legs must be examined
for trapped moisture for which
of the following
reasons?

a. To check for corrosion of the

external surfaces of the
supported piping.

b. To check for corrosion of the

dummy leg.

c. To check for moisture traps

against the external surfaces of
the piping components.

d. All of the above.

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Bellows expansion joints are b. Visual inspection.

best inspected for
deformation, misalignment or
displacement in excess of the
design
by which of the following
methods?

a. The use of a surveyors transit.

b. Visual inspection.

c. Profile radiography.

d. No inspection for these

conditions is required as the
purpose of a bellows joint is to
account for such conditions.

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While externally inspecting d. Threaded fittings due to ease of replacement

piping systems, inspectors
must be watchful for items
unsuitable for long term usage
or
the service. Which of the
following types of components
requires particular attention
during examination?

a. Welded flanges due to

improper gaskets.

b. Temporary clamps due to

leakage.

c. Temporary flexible hoses

due to vibration.

d. Threaded fittings due to

ease of replacement.

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Which of the following may d. Any of the above.

conduct external inspections
of piping systems in
accordance with API 570?

a. The inspector.

b. Qualified maintenance
personnel.

c. Qualified operations
personnel.

d. Any of the above.

What qualifies maintenance or c. An appropriate amount of training.

operations personnel to make
external inspections of piping
systems in accordance
with API 570?

a. Passing the API 570

examination.

b. Written permission from the

inspector describing the scope
of the work they are allowed to
perform.

c. An appropriate amount of
training.

d. An engineering degree is
required.

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To whom should operations d. a or b.

personnel report vibrating or
swaying piping?

a. The inspector.

b. The engineering department.

c. the operations department.

d. a or b.

When significant line b. Notify the inspection or engineering

movements caused by liquid, departments.
hammer, liquid slugging, or
abnormal thermal expansion
occur,
what action should operations
personnel take?

a. No action as long as no
damage appears to have
occurred.

b. Notify the inspection or

engineering departments.

c. Flag the line for maintenance

next turn around.

d. Remove the line from

service immediately for
inspection.

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At junctions where vibrating b. The junction should be periodically magnetic

piping is restrained, what is particle or liquid penetrant tested to detect fatigue
recommended by API 570? cracks.

a. Periodic vibration monitoring

should be performed.

b. The junction should be

periodically magnetic particle
or liquid penetrant tested to
detect fatigue cracks.

c. The area should be

examined for fretting damage
at the support.

d. The area should be

thoroughly examined for leaks.

Which of the following a. Radiography or thermography.

inspection methods can be
used to determine if a line is
plugged while still in service?

a. Radiography or
thermography.

b. Radiography or visual
inspection.

c. Radiography or ultrasonic
testing.

d. Hammer testing and

radiography.
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Which of the following a. Thermography.

inspection methods is used to
detect hot spots on refractory
lined piping systems?

a. Thermography.

b. Wetting a line with water and

looking for areas of abnormally
high evaporation rates.

c. Using your hand to feel for

hot spots.

d. Acoustic emissions.

Which of the following d. All of the above.

inspection methods can be
used for remote leak
detection?

a. Thermography.

b. Acoustic leak detection.

c. Acoustic emissions.

d. All of the above.

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What is a TML? b. A specific area on the piping system where

inspections are to be made.
a. A specific point where a
single thickness reading is to
be obtained.

b. A specific area on the piping

system where inspections are
to be made.

c. A thermal monitoring
location at which a
thermocouple is installed.

d. TML stands for Total Metal

Loss.

Which of the following lines d. All of the above.

would tend to have more TML's
than usual?

a. Piping circuits with severe

failure consequences.

b. Piping circuits with high

corrosion rates.

c. Piping circuits with localized

corrosion problems.

d. All of the above.

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Under what circumstances is it c. TML's may be eliminated in clean non corrosive

permissible to reduce the services.
number of TML's on a piping
circuit?

a. TML's are generally never

eliminated in order to prevent a
loss of historical data.

b. TML's may be eliminated on

systems with high rates of
corrosion and short
replacement intervals.

c. TML's may be eliminated in

clean non corrosive services.

d. TML's may be eliminated only

on high alloy piping used for
product purity.

Who should be consulted c. A person knowledgeable in corrosion.

when TML's are to be
substantially reduced or
eliminated?

a. The inspector.

b. The operations department.

c. A person knowledgeable in
corrosion.

d. The jurisdiction.
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By what methods does API 570 a. Radiography or ultrasonic testing.

suggest the minimum thickness
of a TML be established?

a. Radiography or ultrasonic
testing.

b. Drilling holes and making

physical measurements.

c. By the used of eddy current

testing.

d. Any of the above.

Is it permissible under the d. Yes, provided that radiography or ultrasonics are

requirements of API 570 to use used to determine the minimum thickness at the
techniques other than TML.
radiography or ultrasonics to
locate
thin areas?

a. No.

b. Yes.

c. Yes, provided that ultrasonics

are used to determine the
minimum thickness at the TML.

d. Yes, provided that

radiography or ultrasonics are
used to determine the
minimum thickness at the TML.

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When ultrasonics are used to c. By using either the thinnest reading or the
make minimum thickness average of the readings obtained.
determinations at TML's, how is
the minimum thickness
determined?

a. By using the thinnest

reading.

b. By using an average of the

readings obtained.

c. By using either the thinnest

reading or the average of the
readings obtained.

d. By averaging the five lowest

readings

In addition to establishing d. All of the above.

TML's in areas of general
corrosion, they should also be
established at which of the
following?

a. Areas with continuing CUI.

b. At soil to air interfaces.

c. Areas where localized

corrosion is expected.

d. All of the above.

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Why should TML's be marked a. To allow repetitive measurements at the same

on inspection drawings? TML's.

a. To allow repetitive
measurements at the same
TML's.

b. To allow changing the

locations of readings regularly
for a better overview.

c. To allow audit by operations

personnel.

d. To demonstrate compliance
with OSHA CFR 1910.119.

What determines the number c. The past experience and corrosion patterns.
and locations of TML's?

a. API 570 requirements.

b. ASME B31.3.

c. The past experience and

corrosion patterns.

d. The jurisdiction.

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High temperature sulfur b. Uniform and constant corrosion.

corrosion and sour water
corrosion typically cause which
type of corrosion in non
turbulent
systems?

a. Corrosion under insulation.

b. Uniform and constant

corrosion.

c. Localized corrosion.

d. Heavy isolated pitting.

Circuits with localized b. Tend to have more TML's.

corrosion:

a. Tend to have less frequent

inspections.

b. Tend to have more TML's.

c. Are extremely rare in refinery

service.

d. Require full scanning every

three years.

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The TML selection for each d. The nature of the corrosion expected.
system is determined by:

a. API 570.

b. The owner's engineering

guidelines.

c. Jurisdictional requirements.

d. The nature of the corrosion

expected.

Systems with a high potential c. More TML's.

for CUI and localized
corrosion, or which present
safety or environmental
hazards
usually require which of the
following?

a. No TML's the line must be

fully scanned per API 570.

b. Less TML'S.

c. More TML's.

d. 1 TML per pipe length or

fitting.

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Systems with long straight runs, b. Fewer TML's.

in non corrosive service, or
that present a low safety or
environmental hazard
require:

a. No TML's.

b. Fewer TML's.

c. More TML's than usual.

d. 1 TML for every 30 feet of

length.

May TML's be eliminated on a. Yes.

systems in non corrosive
service?

a. Yes.

b. No.

Which of the following b. Ultrasonics.

provides the most accurate of
determining thickness?

a. Radiography.

b. Ultrasonics.

c. Hammer Testing.

d. Eddy Current
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Why is it necessary to repair c. To prevent a CUI problem from developing.

the insulation and weather
coating following UT of piping
TML's?

a. To maintain the aesthetics of

the refinery.

b. To prevent heating or
cooling of the piping contents.

c. To prevent a CUI problem

from developing.

d. All of the above.

If for some reason the b. RT.

insulation cannot be disturbed
or replaced properly, what
inspection would be
advisable?

a. UT.

b. RT.

c. VT.

d. PT.

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Above what temperature a. 150 degrees F.

should special calibration
procedure and adjustments be
made to ensure accurate UT
readings?

a. 150 degrees F.

b. 250 degrees F.

c. 500 degrees F.

d. 650 degrees F.

Which of the following is not a d. Couplant viscosity.

factor in ultrasonic thickness
testing accuracy when taking
thickness readings?

a. Improper calibration.

b. Excessive surface roughness.

c. Small flaw detector screens.

d. Couplant viscosity.

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In order for the corrosion rate d. b or c.

determination to be valid,
which of the following is
critical?

a. Corrosion rates must be

based upon data from a single
TML.

b. Corrosion rates must be

determined from data
obtained from the same exact
location.

c. Corrosion rates must be

determined from averaging
readings at a test point.

d. b or c.

Calipers are most useful for b. Taking thickness measurements on castings,

which of the following? forgings, and valve bodies.

a. Taking thickness readings on

pipe.

b. Taking thickness
measurements on castings,
forgings, and valve bodies.

c. Measuring the OD of piping.

d. Measuring the ID of piping.

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Is it permissible to use pit a. Yes.

measurement devices to
determine the depth of
localized metal loss?

a. Yes.

b. No.

c. Only when UT or RT methods

are unavailable.

d. Yes, if calibrated.

Are pressure tests normally b. No.

applied as a part of a piping
inspection program?

a. Yes.

b. No.

When are pressure test usually d. All of the above.

required?

a. When required by the piping

engineer or inspector.

b. When required by the Coast

Guard for piping over water.

c. When required by the

jurisdiction.

d. All of the above.

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When required, to what Code c. ASME B31.3

are pressure test performed in
accordance with?

a. API 570.

b. API 574.

c. ASME B31.3

d. API 920.

When a test is performed at a The pressure is designated by the owner user

pressure lower that required tightness purposes.
for a pressure test, what Code
applies?

a. ASME B31.3

b. API 570.

c. The pressure is designated

by the owner user tightness
purposes.

d. Pressure test must be

performed at 1.5 times the
MAWP.

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Water is generally used as the d. All of the above.

test fluid in a pressure test
unless:

a. Freezing is a consideration.

b. The water available may

cause deterioration of the
piping.

c. The water would

contaminate the process.

d. All of the above.

If a flammable liquid is to be c. 120 degrees F.

used as the test fluid, the flash
point must be at least:

a. 70 degrees F.

b. 100 degrees F.

c. 120 degrees F.

d. 150 degrees F.

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When testing a piping system c. Potable water or steam condensate.

constructed of a 300 series
stainless steel, what should be
used as the test fluid in
accordance with API 570?

a. Diesel fuel.

b. Lubricating oil.

c. Potable water or steam

condensate.

d. Salt water.

Following the completion of a b. The line should be drained and dried.

pressure test on a piping
system made of 300 series
stainless steel, what should be
done?

a. The line may be left full of

water until needed for service.

b. The line should be drained

and dried.

c. The line should be inhibited

with sodium chloride.

d. The line may be placed in

service immediately.

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For sensitized stainless steel b. Water with a pH of 8 or more.

piping subject to polythionic
stress corrosion cracking,
which of the following test
fluids
is recommended?

a. Water with a pH of less than

7.

b. Water with a pH of 8 or
more.

c. A weak acid solution.

d. a or c.

What must be considered d. All of the above.

before applying a hydrostatic
test to a piping system?

a. The support structure.

b. The test fluid to be used.

c. The weather conditions.

d. All of the above.

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Is pneumatic testing an b. Yes, when necessary due to process or support

acceptable alternative to considerations.
hydrostatic testing?

a. Yes, whenever convenient.

b. Yes, when necessary due to

process or support
considerations.

c. Yes, if approved by the

jurisdiction due to the potential
safety hazards.

d. No.

What must be considered c. The possibility of over pressure due to thermal

when a system is to be kept expansion.
under test for a long period of
time?

a. The inspectors lunch break.

b. The possibility of leakage.

c. The possibility of over

pressure due to thermal
expansion.

d. Internal corrosion of the

piping system from the test
fluid.

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When safety valves are d. Any of the above.

installed on a piping system to
be pressure tested, the safety
valves shall be:

a. Removed.

b. Blanked.

c. Gagged.

d. Any of the above.

Is it permissible to prepare a d. No.

safety valve for pressure test
by turning the adjusting screw
down?

a. Yes.

b. Yes, if performed by a
maintenance technician.

c. Yes, if performed by a
certified valve shop.

d. No.

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What should be carefully c. These items must be removed if they may be

considered when a piping damaged by the test pressure of test fluid.
system to be pressure tested
contains instrumentation,
control
valves, or expansion bellows

a. The system should be tested

at a pressure based upon the
highest rated component.

b. These items must always be

removed prior to a pressure
test.

c. These items must be

removed if they may be
damaged by the test pressure
of test fluid.

d. These items must be

designed to withstand any
testing.

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Which of the following a. Thickness readings are routinely taken on valves in

statements is incorrect: piping circuits

a. Thickness readings are

routinely taken on valves in
piping circuits

b. The valve body is normally

thicker than other piping
components.

c. Valves should be inspected

while disassembled .

d. Valve bodies exposed to

thermal cycling should be
periodically inspected for
fatigue cracking.

Why should thickness readings c. Because this is any area of high turbulence and
be thin between the seats on stress.
gate valves?

a. Because this is the thinner

part of the valve.

b. Because of wear from the

gate.

c. Because this is any area of

high turbulence and stress.

d. To comply with API 574

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Where should particular care b. The body and piping downstream of the orifice.
be taken when taking thickness
measurements on control
valves or other valves?

a. Upstream of the valve.

b. The body and piping

downstream of the orifice.

c. The valve bonnet.

d. No special precautions are

required.

Valve closure pressure tests d. API 598.

performed after service should
be in accordance with:

a. API 570.

b. API 574.

c. API 620.

d. API 598.

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Piping weld quality inspections a. During new construction, repair or alterations.

are normally performed?

a. During new construction,

repair or alterations.

b. When taking RT profile

images.

c. When required for thickness

determination.

d. Allow the above.

When preferential corrosion of c. Additional welds on the circuit should be

welds is discovered, which of examined.
the following should be done?

a. Nothing, this is normal wear.

b. Examine all other welds per

API 570.

c. Additional welds on the

circuit should be examined.

d. Retire or replace the system.

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If crack like indications are d. All of the above.

found during profile RT, what
would you recommend?

a. Perform weld quality

radiography.

b. Determine if caused by
original construction or
environmental cracking.

c. Assess the magnitude of the

crack.

d. All of the above.

Who is responsible for b. The piping engineer.

assessing environmental
cracking?

a. The inspector.

b. The piping engineer.

c. The owner-user.

d. The jurisdiction.

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If original weld defects are d. Any or all of the above.

noted in a weld during
inspection, which of the
following is considered in the
analysis?

a. Inspector judgement.

b. CWI judgement.

c. Piping Engineer judgement.

d. Any or all of the above.

When assessing the quality of d. All of the above.

existing welds which of the
following shall be considered?

a. Original acceptance criteria

and time in service.

b. Extent of imperfections and

operating conditions.

c. Secondary piping stresses

and weld hardness.

d. All of the above.

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When evaluating welds in b. No.

service, is it appropriate to
apply the original construction
acceptance criteria?

a. Yes.

b. No.

When checking flange fastener d. A representative sample.

markings in a piping system for
compliance with material
requirements, how many
should be checked?

a. 5%

b. 10%

c. 25%

d. A representative sample.

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If fasteners without markings b. The fasteners should be verified or replaced.

are found in a piping system
what action should be
recommended by the
inspector?

a. None is required.

b. The fasteners should be

verified or replaced.

c. The unmarked fasteners must

be discarded.

d. They should be MT for

evidence of failure.

Which of the following is d. No more than 1 thread unengaged in the nut.

considered "acceptable
engagement" for fasteners in
their nuts?

a. At least four threads past the

nut.

b. At least all of the threads in

the nut engaged.

c. No more than 2 threads

unengaged in the nut.

d. No more than 1 thread

unengaged in the nut.

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Before replacing bent flanges a. Their markings and thickness should be checked
installed in a piping system, against engineering requirements.
what should be done?

a. Their markings and thickness

should be checked against
engineering requirements.

b. The flanges should be PMI

tested.

c. The fasteners should be

loosened.

d. The flanges should be

checked for leaks.

When flanges are leaking, what b. Environmental cracking or corrosion.

should the fasteners be
inspected for?
a. Torque.
b. Environmental cracking or
corrosion.
c. Elongation.
d. Proper material.

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Fasteners in flanges that have d. All of the above.

been pumped with sealant
should be checked for?

a. Leakage.

b. Corrosion.

c. Cracking.

d. All of the above.

Is it necessary to inspect c. Yes, if subjected process pressures and

fasteners on instrumentation? temperatures.

a. Yes.

b. Yes, if under pressure.

c. Yes, if subjected process

pressures and temperatures.

d. No.

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What is the purpose of the b. To organize piping systems by failure

classification of piping consequence.
systems?

a. To organize piping systems

by process.

b. To organize piping systems

by failure consequence.

c. To organize piping systems

by pressure and temperature.

d. To organize piping systems

by fire risk.

Which of the following piping a. Class 1.

classifications has the highest
potential consequences?

a. Class 1.

b. Class 2.

c. Class 3.

d. Class 4.

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When classifying piping c. Risk of personnel and the environment.

systems, which of the following
is the main concern?

a. Risk of fire.

b. Risk of leaks.

c. Risk of personnel and the

environment.

d. Economic loss.

Are owner-users required to a. Yes.

classify process fluids?

a. Yes.

b. No.

Class 1 piping contains all but c. Hydrogen.

which of the following?

a. Flammable services which

may auto-refrigerate.

b. Hydrofluoric acid.

c. Hydrogen.

d. Piping over or adjacent to

water.

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Class 2 piping systems include c. Anhydrous hydrogen chloride.

all but which of the following?

a. Fuel gas.

b. Strong acids and caustics.

c. Anhydrous hydrogen
chloride.

d. On site, slow vaporizing

hydrocarbon.

Class 3 piping systems include d. H2S greater than 3% by weight.

all but which of the following?

a. On site hydrocarbons that

will not vaporize.

b. Off site acids and caustics.

c. Distillate and products lines

to storage.

d. H2S greater than 3% by

weight.

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Which of the following is used d. All of the above.

to determine the inspection
interval?

a. The corrosion rate and

remaining life calculations.

b. Piping device classification

an jurisdictional
requirements.

c. The judgement of the

inspector, piping engineer.

d. All of the above.

When should thickness c. At the half corrosion rate life whichever is less.
measurements be scheduled
on piping systems?

a. At the calculated retirement

thickness.

b. At the quarter corrosion rate

life or table 1 whichever is less.

c. At the half corrosion rate life

whichever is less.

d. At the corrosion rate life

whichever is less.

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When should the inspection b. After each inspection or significant change in

interval be adjusted or operating conditions.
reviewed?

a. Annually.

b. After each inspection or

significant change in operating
conditions.

c. At the half corrosion rate.

d. At each change in service.

Per API 570 table 1 what is the c. 5 years.

maximum inspection interval
for visual inspection on class 2
piping?

a. 1 year.

b. 3 years.

c. 5 years.

d. 10 years.

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When should a visual external d. Every 10 years.

inspection be conducted on a
class 2 line?

a. Annually.

b. Every 3 years.

c. Every 5 years.

d. Every 10 years.

For first time CUI inspection on c. At least 50% of all suspect or damaged insulation
class 1 and 2 lines, what is the areas.
minimum amount if inspection
recommended by API
570?

a. At least 10% of all suspect or

damaged insulation areas.

b. At least 25% of all suspect or

damaged insulation areas.

c. At least 50% of all suspect or

damaged insulation areas.

d. At least 100% of all suspect

or damaged insulation areas.

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For first time CUI inspection of a. At least 10% of all suspect or damaged insulation
class 3 systems, what is the areas.
minimum amount of inspection
required?

a. At least 10% of all suspect or

damaged insulation areas.

b. At least 25% of all suspect or

damaged insulation areas.

c. At least 50% of all suspect or

damaged insulation areas.

d. At least 100% of all suspect

or damaged insulation areas.

When conducting first time CUI c. Up to 100%.

inspections what percentage
of inspection of the circuit may
be required if CUI is
found?

a. An additional 10%.

b. An additional 25%.

c. Up to 100%.

d. Two additional areas for

each CUI area.

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For piping systems with a d. The system insulation system or outer jacketing
remaining life over 10 years or should be observed periodically by operating or
that are protected against other
external corrosion, what personnel.
inspection requirements apply

a. The requirements in table 1.

b. The external visual

inspection frequency is twice
that listed in table 1.

c. The system should be

profiled RT inspected every 5
years.

d. The system insulation system

or outer jacketing should be
observed periodically by
operating or other
personnel.

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Examples of piping systems b. Insulated piping systems without sealed jacketing.

protected from external
corrosion per API 570 include
all but which of the following?

a. Jacketed cryogenic piping

systems.

b. Insulated piping systems

without sealed jacketing.

c. Piping installed in a cold box

an insert gas purge.

d. Piping system with a high or

low enough temperature to
preclude the pressure of water.

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