WorksheetsAPI570
Total questions: 208
Worksheet time: 17hrs 20mins
API 570 covers inspection, repair, alteration, and rerating procedures for metallic piping systems that
are being fabricated.
does not fall under ASTM B31.3.
have been in-service.
as not been tested.
API 570 was developed for the petroleum refining and chemical process industries
It shall be used for all piping systems.
It may be used, where practical, for any piping system.
It can be used, where necessary, for steam piping.
It may not be used unless agreed to by all parties.
API 570 ________ be used as a substitute for the original construction requirements governing a piping
system before it is placed in-service.
shall not
should
may
can
API 570 applies to piping systems for process fluids, hydrocarbons, and similar flammable or toxic fluid
services. Which of the following services is not specifically applicable?
Raw, intermediate, and finished petroleum products.
Water, steam condensate, boiler feed water.
Raw, intermediate, and finished chemical products.
Hydrogen, natural gas, fuel gas, and flare systems
Some of the classes of piping systems that are excluded or optional for coverage under API 570 are listed
below. Which one is a mandatory included class?
Water.
Catalyst lines.
Steam.
Boiler feed water
The _________ shall be responsible to the owner-user for determining that the requirements of API 570 for
inspection, examination, and testing are met.
Piping Engineer.
Inspector.
Repair Organization.
Operating Personnel.
Who is responsible for the control of piping system inspection programs, inspection frequencies, and
maintenance of piping?
Authorized Piping Inspector.
Owner-User.
Jurisdiction.
Contractor.
An Authorized Piping Inspector shall have the following qualifications. Pick the one that does not belong in
this list.
Four years of experience inspecting in-service piping systems.
High school education plus 3 years of experience in the design, construction, repair, operation, or
inspection of piping systems.
Two year certificate in engineering or technology plus 2 years of experience in the design, construction,
repair, operation, or inspection of piping systems.
Degree in engineering plus one year experience in the design, construction, repair, operation, or inspection
of piping systems.
Risk Based Inspections include which of the following:
Likelihood assessment
Consequence analysis.
Operating and Inspection histories.
All of the above.
An RBI assessment can be used to alter the inspection strategy provided:
The degradation methods are identified.
The RBI is fully documented.
A third party conducts the RBI.
Both A & B above.
Which one of the following is not a specific type or an area of deterioration?
Rectifier performance.
Injection points.
Deadlegs.
Environmental cracking.
Injection points subject to accelerated or localized corrosion may be treated as ________.
the focal point of an inspection circuit.
separate inspection circuits.
piping that must be renewed on a regular schedule.
locations where corrosion inhibitors must be used.
The recommended upstream limit of inspection of an injection point is a minimum of:
12 feet or 3 pipe lengths whichever is smaller.
12 inches or 3 pipe diameters whichever is smaller.
12 inches or 3 pipe diameters whichever is greater.
12 feet or 3 pipe lengths whichever is greater
14. The recommended downstream limit of inspection of an injection point is a minimum of:
a. second change in flow direction past the injection point, or 25 feet beyond the first change in flow direction
whichever is less.
b. second change in flow direction past the injection point, or 25 feet beyond the first change in flow direction
whichever is greater.
c. second change in flow direction past the injection point, or 25 inches beyond the first change in flow
direction whichever is less.
d. second change in flow direction past the injection point, or 25 inches beyond the first change in flow
direction whichever is greater.
15. Select thickness measurement locations (TMLs) within injection point circuits subject to localized corrosion
according to the following guidelines. Select the one that does not belong.
a. Establish TMLs on appropriate fittings within the injection point circuit.
b. Establish at least one TML at a location at least 25 feet beyond the downstream limit of the injection point.
c. Establish TMLs on the pipe wall at the location of expected pipe wall impingement or injected fluid.
d. Establish TMLs at both the upstream and downstream limits of the injection point circuit.
16. What are the preferred methods of inspecting injection points?
a. Radiography and/or ultrasonics.
b. Hammer test and/or radiograph.
c. Ultrasonics and/or liquid penetrant.
d. Liquid penetrant and/or eddy current.
17. During periodic scheduled inspections, more extensive inspection should be applied to an area beginning
__________ upstream of the injection nozzle and continuing for at least __________ pipe diameters
downstream of the injection point.
a. 10 inches, 20
b. 12 feet, 10
c. 12 inches, 10
d. 10 feet, 10
18. Why should deadlegs in piping be inspected?
a. API 510 mandates the inspection of deadlegs.
b. Acid products and debris build up in deadlegs
c. The corrosion rate in deadlegs can vary significantly from adjacent active piping.
d. Caustic products and debris build up in deadlegs.
19. Both the stagnant end and the connection to an active line of a deadleg should be monitored. In a hot piping
system, why does the high point of a deadleg corrode and need to be inspected?
a. corrosion occurs due to directed currents set up in the deadleg.
b. erosion occurs due to convective currents set up in the deadleg.
c. corrosion occurs due to convective currents set up in the deadleg.
d. erosion occurs due to directed currents set up in the deadleg.
20. What is the best thing to do with deadlegs that are no longer in service?
a. Ultrasonically inspect often.
b. Radiograph often.
c. Inspect often.
d. Remove them.
21. What are the most common forms of corrosion under insulation (CUI).
a. localized corrosion of nonferrous metals and chloride stress corrosion cracking of carbon steel.
b. localized corrosion of chrome-moly steel and chloride stress corrosion cracking of ferritic stainless steel.
c. localized corrosion of carbon steel and chloride stress corrosion cracking of austenitic stainless steel.
d. localized corrosion of nickel-silicon alloy and caustic stress corrosion of austenitic stainless steel.
22. What climatic area may require a very active program for corrosion under insulation?
a. Cooler northern continent locations.
b. Cooler drier, midcontinent locations.
c. Warmer, marine locations.
d. Warmer drier, desert locations.
23. Certain areas and types of piping systems are potentially more susceptible to corrosion under insulation.
Which of the items listed is not susceptible to CUI?
a. Areas exposed to mist overspray from cooling water towers.
b. Carbon steel piping systems that normally operate in-service above 250 degrees but are in intermittent
service.
c. Deadlegs and attachments that protrude from insulated piping and operate at a different temperature than
the temperature of the active line.
d. Carbon steel piping systems, operating between 250 degrees F and 600 degrees F.
24. What location is subject to corrosion under insulation and inspection contributes to it.
a. Locations where pipe hangers and other supports exist.
b. Locations where insulation has been stripped to permit inspection of the piping
c. Locations where insulation plugs have been removed to permit piping thickness measurements.
d. Locations where there is damaged or missing insulation jacketing.
25. Soil-to-air (S/A) interfaces for buried piping are a location where localized corrosion may take place. If the
buried part is excavated for inspection, how deep should the excavation be to determine if there is hidden
damage?
a. 12 to 18 inches.
b. 6 to 12 inches.
c. 12 to 24 inches.
d. 6 to 18 inches.
26. At concrete-to-air and asphalt-to-air interfaces of buried piping without cathodic protection, the inspector
should look for evidence that the caulking or seal at the interface has deteriorated and allowed moisture
ingress. If such a condition exists on piping systems over ______ years old, it may be necessary to inspect
for corrosion beneath the surface before resealing the joint.
a. 8
b. 5
c. 15
d. 10
27. An example of service-specific and localized corrosion is:
a. Corrosion under insulation in areas exposed to steam vents
b. Unanticipated acid or caustic carryover from processes into non-alloyed piping.
c. Corrosion in deadlegs.
c. Corrosion in deadlegs.
d. Corrosion of underground piping at soil-to-air interface where it ingresses or egresses.
28. Erosion can be defined as:
a. galvanic corrosion of a material where uniform losses occur.
b. removal of surface material by action of numerous impacts of solid or liquid particles.
c. gradual loss of material by a corrosive medium acting uniformly on the material surface.
d. pitting on the surface of a material to the extent that a rough uniform loss occurs.
29. A combination of corrosion and erosion results in significantly greater metal loss than can be expected from
corrosion or erosion alone. This type of loss occurs at:
a. high-velocity and high-turbulence areas.
b. areas where condensation or exposure to wet hydrogen sulfide or carbonates occur.
c. surface-to-air interfaces of buried piping.
d. areas where gradual loss of material occurs because of a corrosive medium.
30. Environmental cracking of austenitic stainless steels is caused many times by:
a. exposing areas to high-velocity and high-turbulence streams
b. excessive cyclic stresses that are often very low.
c. exposure to chlorides from salt water, wash-up water, etc.
d. creep of the material by long time exposure to high temperature and stress.
31. When the inspector suspects or is advised that specific piping circuits may be susceptible to environmental
cracking the inspector should:
a. call in a Piping Engineer for consultation.
b
a. call in a Piping Engineer for consultation.
b. investigate the history of the piping circuit.
c. obtain advise from a Metallurgical Engineer.
d. schedule supplemental inspections.
32. If environmental cracking is detected during internal inspection of pressure vessels, what should the
Inspector do?
a. The Inspector should designate appropriate piping spools upstream and downstream of the vessel to be
inspected if piping is susceptible to environmental cracking.
b. The Inspector should consult with a Metallurgical Engineer to determine the extent of the problems.
c. The Inspector should review the history of adjacent piping to determine if it has ever been affected.
d. The Inspector should consult with a Piping Engineer to determine the extent of the problems.
33. If external or internal coatings or refractory liners on a piping circuit are in good condition, what should an
inspector do?
a. After inspection, select a portion of the liner for removal.
b. The entire liner should be removed for inspection.
c. Selected portions of the liner should be removed for inspection.
d. After inspection, if any separation, breaks, holes or blisters are found, it may be necessary to remove
portions of the lining to determine the condition under it.
34. What course of action should be followed if a coating of coke is found on the interior of a large pipe off a
reactor on a Fluid Catalytic Cracking Unit.
a. Determine whether such deposits have active corrosion beneath them. If corrosion is present, thorough
inspection in selected areas may be required
b. The coke deposits should be removed from the area for inspection
c. The coke deposits may be ignored -- the deposits will probably protect the line from corrosion.
d. Consult with a Process Engineer and a Metallurgist on the necessity of removing the coke deposits.
35. Fatigue cracking of piping systems may result from:
a. embrittlement of the metal due to it operating below its transition temperature.
b. erosion or corrosion/erosion that thin the piping where it cracks.
c. excessive cyclic stresses that are often well below the static yield strength of the material.
d. environmental cracking caused by stress corrosion due to the presence of caustic, amine, or other
substance.
36. Where can fatigue cracking typically be first detected?
a. At points of low-stress intensification such as reinforced nozzles.
b. At points of high-stress intensification such as branch connections.
c. At points where cyclic stress are very low.
d. At points where there are only bending or compressive stresses.
37. What are the preferred NDE methods for detecting fatigue cracking
a. Eddy current testing, ultrasonic A-scan testing, and/or possibly hammer testing.
b. Liquid penetrant testing, magnetic particle testing and/or possibly acoustic emission testing.
c. Visual testing, eddy current testing and/or possibly ultrasonic testing.
d. Acoustic emission testing, hydro-testing, and/or possibly ultrasonic testing.
38. Creep is dependent on:
a. time, temperature, and stress.
b. material, product contained, and stress.
c. temperature, corrosive medium, and load.
d. time, product contained, and load.
39. An example of where creep cracking has been experienced in the industry is in the problems experienced
with cracking of 1.25% Chrome steels operating at temperatures above _________ degrees F.
a. 500
b. 900
c. 1000
d. 1200
40. Brittle fracture can occur in carbon, low-alloy, and other ferritic steels at or below _______ temperatures.
a. 140 degree
b. ambient
c. 100 degree
d. 30 degree
41. Water and aqueous solutions in piping systems may freeze and cause failure because of the:
a. expansion of these materials.
b. contraction of these materials.
c. constriction of these materials.
d. decrease of these materials.
42. Different types of inspection and surveillance are appropriate depending on the circumstances and the
piping system. Pick the one that does not belong in the following list.
a. Internal and external visual inspection.
b. Thickness measurement inspection.
c. Vibrating piping inspection.
d. Chemical analysis inspection.
43. Internal visual inspections are __________ on piping unless it is a large diameter transfer line, duct, catalyst
line or other large diameter piping system.
a. the most effective inspection
b. the most useful means of inspection
c. not normally performed
d. the major means of inspection
44. Name an additional opportunity for a normal non-destructive internal inspection of piping.
a. When the piping fails and the interior is revealed.
b. When maintenance asks for an internal inspection.
c. When piping flanges are disconnected.
d. When a fire occurs and the pipe is in the fire.
45. Why is thickness measurement inspection performed?
a. To satisfy jurisdictional requirements
b. To determine the internal condition and remaining thickness of the piping components.
c. To determine the external condition and amount of deposits inside the piping.
d. To satisfy heat transfer requirements of the piping.
46. Who performs a thickness measurement inspection?
a. The operator or control man.
b. The Inspector or examiner.
c. The maintenance workers or supervisor.
d. The Jurisdiction or OSHA.
47. When corrosion product buildup is noted during an external visual inspection at a pipe support contact area
lifting off such supports may be required for inspection. When doing this, care should be:
. exercised if the piping is in-service.
b. used when determining the course of action.
c. practiced so as not to disturb the supports.
d. taken that a complete record of the problem is made.
48. Qualified operating or maintenance personnel also may conduct external visual inspections, when:
a. satisfactory to the owner-user.
b. acceptable to the inspector.
c. agreeable to the maintenance supervisor.
d. permissible to the operation supervisor.
49. Who would normally report vibrating or swaying piping to engineering or inspection personnel?
a. Operating personnel.
b. Maintenance personnel.
c. Jurisdictional personnel
d. OSHA personnel.
50. Thermography is used to check for:
a. vibrating sections of the piping system.
b. detecting localized corrosion in the piping system.
c. abnormal thermal expansion of piping systems.
d. hot spots in refractory lined piping systems.
51. Thickness measurement locations (TMLs) are specific ________ along the piping circuit where inspections
are to be made.
a. points
b. areas
c. items
d. junctures
52. The minimum thickness at each TML can be located by:
a. electromagnetic techniques.
b. ultrasonic scanning or radiography.
c. hammer testing.
d. MT and/or PT.
53. Where appropriate, thickness measurements should include measurements at each of _________ on pipe
and fittings.
a. two quadrants
b. three locations
c. four quadrants
d. six points
54. Where should special attention be placed when taking thickness measurements of an elbow?
a. The outlet end.
b. The inlet end.
c. The inside and outside radius.
d. The sides.
55. TMLs should be marked on inspection drawings and __________________ to allow repetitive
measurements
a. on the inspectors notes
b. on a computer system
c. on the piping system
d. on maintenance department charts
56. What is taken into account by an experienced inspector when selecting TML’s?
a. The amount of corrosion expected.
b. The patterns of corrosion that would be expected.
c. The number and the cost of reading the TMLs.
d. Whether the TML’s are easily accessed.
57. In theory, a piping circuit subject to perfectly uniform corrosion could be adequately monitored with ______
TML/s.
a. 1
b. 2
c. 3
d. 4
58. More TML’s should be selected for piping systems with any of the following characteristics:
a. Low potential for creating a safety or environmental emergency in the event of a leak.
b. More complexity in terms of fittings, branches, deadlegs, injection points, etc.
c. Relatively non-corrosive piping systems.
d. Long, straight-run piping systems.
59. Fewer TML’s can be selected for piping systems with any of the following characteristics:
a. More complexity in terms of fittings, branches, deadlegs, injection points, etc.
b. Higher expected or experienced corrosion rates.
c. Long, straight-run piping systems.
d. Higher potential for localized corrosion.
60. TML’s can be eliminated for piping systems with the following characteristics
a. Higher potential for creating a safety or environmental emergency in the event of a leak.
b. Low potential for creating a safety or environmental emergency in the event of a leak.c. Extremely low potential for creating a safety or environmental emergency in the event of a leak.
c. Extremely low potential for creating a safety or environmental emergency in the event of a leak.
d. More complexity in terms of fittings, branches, deadlegs, injection points, etc.
61. What is usually the most accurate means for obtaining thickness measurements on installed pipe larger than
NPS 1
a. MT
b. UT
c. PT
d. ET
62. What thickness measuring technique does not require the removal of some external piping insulation?
a. AE
b. UT
c. ET
d. RT
63. When ultrasonic thickness measurements are taken above ________ degrees F., instruments couplants,
and procedures should be used that will result in accurate measurements at the higher temperature.
a. 150
b. 175
c. 200
d. 250
64. Typical digital thickness gages may have trouble measuring thicknesses less than ____ inches.
a. 0.2188
b. 0.1875
c. 0.1562
d. 0.1250
65. When pressure testing of piping systems are conducted they shall be performed in accordance with the
requirements of:
a. ASME B31.3.
b. ASME B&PV Code, Section VIII.
c. ASA B16.5
d. API 510
66. If a lower pressure test (lower than prescribed by code) is used only for tightness of piping systems, the
_______ may designate the pressure.
a. owner-user
b. inspector
c. jurisdiction
d. contractor
67. The preferred medium for a pressure test is ______.
a. steam
b. air
c. water
d. hydrocarbon
68. If a non-toxic hydrocarbon (flammable) is used as the test medium, the liquid flash point shall be at least
______ degrees F. or greater.
a. 95
b. 100
c. 110
d. 120
69. Piping fabricated of or having components of 300 series stainless steel should be tested with _________.
a. water with a pH of 4
b. water with a pH of 6.
c. water with a chloride content of less than 400 ppm chlorides.
d. steam condensate.
70. For sensitized austenitic stainless steel piping subject to polythionic stress corrosion cracking, consideration
should be given to using _________ for pressure testing.
a. an acidic-water solution
b. an alkaline-water solution
c. a water with a pH of 5
d. a water with a pH of 4
71. When a pipe requires post weld heat treatment, when should the pressure test be performed.
a. During heat treatment
b. Before any heat treatment.
c. After any heat treatment.
d. No test is required.
72. During a pressure test, where the test pressure will exceed the set pressure of the safety relief valve or
valves on a piping system the safety relief valve or valves should be ______________ when carrying out
the test.
a. altered by screwing down on the adjusting screw
b. reset to exceed the test pressure
c. checked or tested
d. removed or blanked
73. If block valves are used to isolate a piping system for a pressure test, what precaution should be taken?
a. Do not use a globe valve during a test.
b. Make sure the packing gland of the valve is tight.
c. Do not exceed the permissible seat pressure of the valve.
d. Check the bonnet bolts to make sure they are tight.
74. Several methods may be used to verify that the correct alloy piping is in a system. Which of the following
methods may be used:
a. 100% verification
b. PMI testing
c. sampling a percentage of materials
d. any of the above may be used
75. Name a part of a piping system that thickness measurements are not normally routinely taken.
a. elbows
b. expansion loops
c. tees
d. valves
76. If environmental cracking is found during in-service inspection of welds, who should conduct the untrasonic
shear wave examination, if required?
a. Owner-user.
b. Inspector.
c. Industry-qualified UT Examiner (after 2003).
d. Industry-qualified inspection-engineers.
77. If an Inspector finds an imperfection in an original fabrication weld and analysis is required to assess the
impact of the weld quality on piping integrity, which of the following may perform the analysis?
a. An API 510 Inspector, a WPS Inspector, a Pressure Vessel Engineer
b. An API 570 Inspector, a CWI Inspector, a Piping Engineer.
c. An Owner-User, a B31.3 Inspector, an Industrial Engineer
d. A Jurisdictional Representative, a API 574 Inspector, an Chemical Engineer.
78. According to API 570, some welds in a piping system that has been subjected to radiography according to
ASME B31.3:
a. will meet random radiograph requirements, and will perform satisfactorily in-service without a hydrotest.
b. will not meet random radiograph requirements, and will not perform satisfactorily in-service even though
hydrotested.
c. will meet random radiograph requirements, and will not perform satisfactorily in-service after a hydrotest.
d. will not meet random radiograph requirements, but will still perform satisfactorily in-service after being
hydrotested.
79. How should fasteners and gaskets be examined to determine whether they meet the material specifications.
a. All fasteners and gaskets should be checked to see if their markings are correct according to ASME and
ASTM standards
b. A representative sample of the fasteners and gaskets should be checked to see if their markings are
correct according to ASME and ASTM standards
c. Purchase records of all fasteners and gaskets should be checked to see if the fasteners and gaskets meet
ASME and ASTM standards.
d. A representative sample of the purchase records of fasteners and gaskets should be checked to see if the
fasteners and gaskets meet ASME and ASTM standards.
80. When checking flange and valve bonnet bolts for corrosion, what type of NDT is usually used?
a. RT
b. UT
c. VT
d. AE
81. What course of action is called for when an inspector finds a flange joint that has been clamped and
pumped with sealant?
a. Disassemble the flange joint; Renew the fasteners and gaskets. The flanges may also require renewal or
repair
b. Renew all the fasteners and renew the gasket if leakage is still apparent.
c. Check for leakage at the bolts; if repumping is contemplated, affected fasteners should be renewed.
d. No action is required since the joint has been pumped with a sealant.
82. All process piping systems must be categorized into different classes. On what are the classifications
selection based?
a. Requirements of jurisdiction and the proximity of population areas.
b. Potential safety and environmental effects should a leak occur.
c. Liability to the owner-user and the requirements of the jurisdiction
d. Access to the systems for inspection and closeness to population areas.
82. (1). Inspection strategy based on likelihood and consequence of failure is called:
a. RBI
b. FFS
c. BIR
d. MSOS
82. (2). An RBI assessment can be used to _______________ the inspection interval limits in Table 1 of
API 570 or the extent of the inspection conducted.
a. increase
b. decrease
c. either a or b, above
d. none of the above
82. (3). When an RBI assessment is used to increase or decrease inspection intervals, the assessment
shall be conducted on Class 1 systems at a maximum interval of _________ years
a. 5
b. 10
c. 15
d. 3
83. Listed below are several examples of a CLASS 1 piping system. Which one does not belong?
a. Anhydrous hydrogen chloride.
b. Hydrofluoric acid.
c. Piping over or adjacent to water and piping over public throughways.
d. Distillate and product lines to and from storage and loading.
84. Of the three classification of piping systems, which includes the majority of unit process and selected off-site
piping?
a. Class 3
b. Combination of classes 1 and 2
c. Class 1
d. Class 2
85. Class 3 piping is described as being in services:
a. with the highest potential of resulting in an immediate emergency if a leak occurs.
b. that are flammable but do not significantly vaporize when they leak and are not located in high-activity
areas.
c. that are not flammable and pose no significant risk to populated areas.
d. that are not in classes 1 and 2.
86. Who establishes inspection interval for thickness measurements, external visual inspections and for internal
and supplemental inspections?
a. Piping Engineer.
b. Owner-user or the Inspector.
c. Chemical Engineer.
d. Piping Engineer and the Jurisdiction.
87. Thickness measurement inspection should be scheduled based on the calculation of not more than:
a. one half the remaining life determined from corrosion rates or the maximum interval of 5 years whichever is
shorter
b. one half the remaining life determined from corrosion rates or the maximum interval allowed by API 570 in
Table 1, whichever is shorter.
c. one fourth the remaining life determined from corrosion rates or the maximum interval of 10 years
whichever is shorter.
d. one quarter the remaining life determined from corrosion rates or the maximum interval allowed by API 570
in Table 1, whichever is shorter.
88. For External inspections for potential corrosion under insulation (CUI) on Class 1 systems, the examination
should include at least _____ percent of all suspect areas and _____ percent of all areas of damaged
insulation.
a. 50, 75
b. 50, 33
c. 75, 50
d. 25, 10
89. Piping systems that are known to have a remaining life of over ______ years or that are protected against
external corrosion need not have insulation removed for the periodic external inspection.
a. 10
b. 15
c. 5
d. 20
90. For Class 3 piping systems, the examination for corrosion under insulation (CUI) should include at least
_____ percent of all suspect areas.
a. 50
b. 30
c. 10
d. 0
91. For Class 2 piping, the extent of CUI inspections on a system operating at -45°F will be:
a.75% of damaged areas, 50% of suspect areas.
b. 50% of suspect areas, 33% of damaged areas.
c. 33% of damaged areas, 50% of suspect areas.
d. none of the above
92. Small bore piping (SBP) that is Class 1 shall be inspected:
a. where corrosion has been experienced.
b. at the option of the inspector.
c. to the same requirements as primary process piping.
d. only if it has dead legs.
93. Inspection of small bore piping (SBP) that is secondary and auxiliary (associated with instruments and
machinery) is:
a. only required where corrosion has been experienced.
b. optional
c. only if it has dead legs
d. only if it is threaded
94. If an inspector finds threaded small bore piping (SBP) associated with machinery and subject to fatigue
damage, he should:
a. plan periodically to assess it and consider it for possible renewal with a thicker wall or upgrade it to welded
components
b. inspect it only if it is corroded and the class of service requires an inspection.
c. call for dismantling the threaded joints for close inspection to determine if any cracks are in the roots of the
threads.
d. have all the threaded piping renewed at each inspection period
An eight inch diameter piping system is installed December, 1979. The installed thickness is measured as
0.34”. The required thickness of the pipe is 0.20”. It is inspected on12/83 and the thickness is found to be
0.32”. An inspection 12/87 reveals a loss of 0.01” from the 12/85 inspection. During 12/89 the thickness was
found to be 0.29”. The last inspection was during 12/95 and the thickness was found to be 0.26”. What is
the long term corrosion rate of this system?
a. 0.005”/year
b. 0.0075”/year
c. 0.00375”/year
d. 0.0025”/year
96. Using the information in question 95, calculate the short term corrosion rate
a. 0.005”/year
b. 0.0075”/year
c. 0.00375”/year
d. 0.0025”/year
97. Using the information in questions 95 and 96, determine the remaining life of the system.
a. 18 years
b. 15 years
c. 12 years
d. 6 years
98. You have a new piping system that has just been installed. It is completely new an no information exists to
establish a corrosion rate. Also, information is not available on a similar system. You decide to put the
system in service and NDT it later to determine the corrosion rate. How long do you allow the system to stay
in service before you take your first thickness readings?
a. 1 month
b. 3 months
c. 6 months
d. 12 months
99. After an inspection interval is completed and if calculations indicate that an inaccurate rate of corrosion has
been assumed in a piping system, how do you determine the corrosion rate for the next inspection period?
a. Check the original calculations to find out what the error is in the original assumption
b. Unless the corrosion rate is higher, the initial rates shall be used.
c. The corrosion rate shall be adjusted to agree with the actual rate found
d. If the corrosion rate is higher than originally assumed, call in a corrosion specialist.
100. If a piping system is made up of unknown materials and computations must be made to determine the
minimum thickness of the pipe, what can the inspector or the piping engineer do to establish the minimum
thickness?
a. The lowest grade material and joint efficiency in the applicable code may be assumed for calculations.
b. Samples must be taken from the piping and testing for maximum tensile stress and yield strength will
determine the allowable stress to be used.
c. The piping made of the unknown material must be removed from service and current piping of known
material must be installed.
d. The piping of unknown material may be subjected to a hydrostatic stress tests while having strain gages on
it to determine its yield strength and thus allowable stress.
101. A piping engineer is designing a piping service with high potential consequences if a failure occurs, i.e., a
350 psi natural gas line adjacent to a high density population area. What should he consider doing to
provide for unanticipated situations?
a. Have all his calculations checked twice.
b. Increase the required minimum thickness.
c. Notify the owner-user and the jurisdiction
d. Set up an emergency evacuation procedure
102. When evaluating locally thinned areas, the provisions of RP 579 Section ______ should be followed.
4
b. 5
c. 6
d. 7
103. An Inspector finds a thin area in a fabricated 24” diameter pipe. The thin area includes a longitudinal weld
in the pipe and is 10 feet long and 2 foot circumferentially. Calculations show that with 0.85 joint factor,
the pipe must be repaired, renewed, etc. or the pressure in the pipe must be lowered. The owner does
not want do any hot work on the pipe and he does not wish to lower the pressure. What other course
could be followed, per API 570?
a. Write the results of the inspection up and leave it with the owner.
b. Conduct an FFS per RP 579.
c. Insist that the weld be repaired or renewed or that the pressure be lowered.
d. Call in a regulatory agency to force the owner to repair, renew, etc. the line.
104. Piping stress analysis is done during the system’s original design. How can the inspector make use of
stress analysis information?
. An inspector can not use this information. It is only meaningful to a piping engineer.
b. It can be used to make sure the piping system was originally evaluated and designed correctly.
c. It can be used to concentrate inspection efforts at locations most prone to fatigue or
creep damage, and to solve vibration problems
d. The inspector should use this information to evaluate the need for conducting
additional piping stress analysis.
105. You are inspecting a piping system. You find a significant loss of material (a major increase of corrosion
rate) in gas oil piping (used as reboiler oil, temperature 500 degrees F.) on an Fluid Catalytic Cracking
Unit. What is the best course of action for you to take?
a. The losses may be reported to your supervisor for corrective response.
b. The losses should be recorded & reported in your final report after the unit has started.
c. It shall be reported to the owner-user for appropriate action
d. Replace excessively thin piping & note replacement in the final report after unit start-up.
106. The ___________ shall maintain appropriate permanent and progressive records of each piping system
covered by API 570.
a. inspector
b. owner-user
c. jurisdiction
d. examiner
107. When making repairs and alterations to piping systems the principles of ________ or the code to which the
piping system was built shall be followed.
a. ASME B31.3
b. API 570
c. API 574
d. ASME B&PV Code
108. Repair and alteration work must be done by a repair organization as defined in API 570 and must be
authorized by the _________ prior to its commencement.
a. jurisdiction
b. inspector
c. owner-user
d. examiner
109. Authorization for alteration work to a piping system may be given by the inspector after:
a. notifying the jurisdiction and getting their approval
b. consulting API 570 and getting the approval of the owner-user.
c. consultation with, and approval by a piping engineer
d. discussing with, and consent by an examiner.
110. A repair procedure involving welding requires that the root pass of the weld be inspected before continuing
the weld. A “hold” on the repair is required at this point. Who designates this “hold”?
a. A metallurgist
b. The owner-user
c. An API 570 inspector.
d. The welder Supervisor.
111. What type of repairs and procedures may the inspector give prior general authorization to continue
(provided the inspector is satisfied with the competency or the repair organization?
a. major repairs and minor procedures.
b. limited or routine repairs and procedures
c. alterations and reratings
d. minor reratings and alterations.
112. Who approves all proposed methods of design, execution, materials, welding procedures, examination,
and testing of in-service piping?
a. The jurisdiction or the piping engineer as appropriate.
b. The analyst and the operator as appropriate.
c. The examiner and the piping programmer as appropriate.
d. The inspector or the piping engineer, as appropriate.
113. Who must give approval for any on-stream welding?
a. owner-user.
b. jurisdiction.
c. examiner.
d. analyst.
114. An inspector finds a crack in the parent metal of a pipe adjacent to a support lug. The pipe was being
inspected after a 5 year run. Before repairing the he should:
a. Notify the jurisdiction prior to the start of any repairs.
b. Write a detailed procedure for the repair organizations use in repairing the crack.
c. Consult with the piping engineer to identify and correct the cause of the crack.
d. Consult with a metallurgist prior to writing a procedure to repair the crack.
115. A full encirclement welded split sleeve designed by a piping engineer may be applied over a damaged or
corroded area of a pipe. This is considered a temporary repair. When should a permanent repair be made?
a. If the owner-user designates the welded split sleeve as permanent, it may remain.
b. A full encirclement welded split sleeve is permanent if okayed by the inspector
c. A full encirclement welded split sleeve is considered a permanent repair
d. A permanent repair must be made at the next available maintenance opportun
116. What type of defect, corrosion, pitting and/or discontinuity should not be repaired by a full encirclement
welded split sleeve?
a. A longitudinal crack.
b. A circumferential crack.
c. Pits that are one half through wall.
d. General corrosion in the longitudinal direction.
117. If a repair area is localized (for example, pitting or pin-holes) and the specified minimum yield strength
(SMYS) of the pipe is not more than ___________ psi, a temporary repair may be made by fillet welding a
properly designed plate patch over the pitted area.
a. 30,000 psi
b. 55,000 psi
c. 40,000 psi
d. 36,000 psi
118. Insert patches (flush patches may be used to repair damaged or corroded areas of pipe if several
requirements are met. One of these is that an insert patch (flush patch) may be of any shape but it shall
have rounded corners with ______ minimum radii.
a. 0.375”
b. 0.50”
c. 0.75”
d. 1”
119. An inspector finds a pin-hole leak in a weld during an on-stream inspection of a piping system. A
permissible temporary repair is:
a. the use of plastic steel to seal off the leak.
b. driving a wooden plug into the hole.
c. screwing a self tapping screw into the hole.
d. the installation of a properly designed and fabricated bolted leak clamp.
120. Temporary leak sealing and leak dissipating devices shall be removed and the pipe restored to original
integrity:
a. as soon as the piping system can be safely removed from service
b. at a turnaround or other appropriate time.
c. when the leak seal and leak dissipating device ceases to work.
d. as soon as possible--must be done on a safe, emergency shut-down basis.
121. Which of the following is NOT an item for consideration by an inspector when a leak sealing fluid
(“pumping”) is used for a temporary leak seal repair.
a. Consider the compatibility of the sealant with the leaking material.
b. Consider the pumping pressure on the clamp (especially when repumping).
Consider the pressure testing of the piping in question.
d. Consider the number of times the seal area is repumpe
122. Any welding conducted on piping components in operation must be done in accordance with:
a. NFPA 704
b. API Standard 510
c. ASME B31.3.
d. API Publication 2201.
123. All repair and alteration welding to piping systems shall be done in accordance with the:
a. exact procedures of ASME B31.3 or to the code to which it was built.
b. standards of ASME B31.1 or the code to which it was built.
c. principles of ASME B31.3 or the code to which it was built.
d. ideals of ASME, NBIC, or API standards.
124. Welders and welding procedures used in making piping repairs, etc. shall be qualified in accordance with:
a. ASME B31.3 or the code to which the piping was built.
b. NBIC or the system to which the piping was built.
c. NACE or the method to which the piping was built.
d. ASTM or the law to which the piping was built
125. The repair organization responsible for welding shall maintain records of welding procedures and welder
performance qualifications. These records shall be available to the inspector:
a. at the end of the job.
b. after the start of welding.
c. following the start of welding.
d. before the start of welding.
126. Preheating to not less than ________ degrees F. may be considered as an alternative to post weld heat
treatment for alterations or repairs of P-1 piping initially post weld heat treated as a code requirement (may
not be used if the piping was post weld heat treated due to environmental cracking prevention).
a. 150
b. 200
c. 300
d. 350
127. When using local PWHT as a substitute for 360-degree banding on local repairs of PWHT’d piping, which
of the following items is NOT considered?
a. The application is reviewed, and a procedure is developed by the piping engineer.
b. The locally PWHT’d area of the pipe must be RT’d or UT’d
c. A preheat of 3000 F., or higher is maintained while welding.
d. The PWHT is performed for code compliance and not for environmental cracking.
128. Piping butt joints shall be:
a. double spiral fillet welds
b. single fillet lap welds
c. double fillet lap welds
d. full-penetration groove welds.
129. When should piping components that need repair be replaced?
a. When enough time remains on a turnaround to allow replacement.
b. When repair is likely to be inadequate.
c. When the cost of repair is as high as renewal.
d. When replacement is preferred by maintenance personnel.
130. Fillet welded patches (lap patches) shall be designed by:
a. an engineer
b. the inspector.
c. the piping engineer
d. the repair organization.
131. Fillet welded lap patches (overlay patches) shall have:
a. no membrane stresses.
b. right-angled corners.
c. rounded corners.
d. burnished corners.
132. Materials used in making welding repairs or alterations _______ be of known weldable quality.
a. may
b. shall
c. should
d. can
133. Acceptance of a welded repair or alteration shall include _______ in accordance with the applicable code
and the owner-user’s specification, unless other wise specified in API 570.
a. Nominal pragmatic sizing (NPS)
b. NBE
c. safeguards
d. Nondestructive examination
After welding is completed on a repair or alteration, __________________ in accordance with API 570
shall be performed if practical and deemed necessary by the inspector
a. NPS
b. safety sanctions
c. NBE
d. a pressure test
135. When are pressure tests normally required?
a. Pressure tests are normally required after alterations and any repair.
b. Pressure tests are normally required after alterations and major repairs.
c. Pressure tests are normally required after major and minor repairs
d. Pressure tests are normally required only as specified by the owner-user.
136. When a pressure test is not necessary or practical, what shall be utilized in lieu of a pressure test?
a. NPS
b. Nondestructive examination.
c. Vacuum visual examination
d. NBE
137. Substituting special procedures in place of a pressure test after an alteration or repair may be done only
after consultation with:
a. the operators and the repair organization
b. the inspector and the piping engineer
c. the jurisdiction
d. the examiner and the inspector.
138. When it is not practical to perform a pressure test of a final closure weld that joins a new or replacement
section of piping to an existing system, several requirements shall be satisfied. Which of the following is
NOT one of the requirements.
a. The closure weld is a full-penetration fillet weld between a weld neck flange and standard piping component
or straight sections of pipe of equal diameter and thickness, axially aligned, and of equivalent materials.
For design cases up to Class 150 and 5000 F., slip-on flanges are acceptable alternates.
b. MT or PT shall be performed on the root pass and the completed butt weld. Fillet welds must have PT/MT
on the completed weld.
c. The new or replacement piping is pressure tested.
d. Any final closure butt weld shall be of 100 % radiographic quality; or angle-beam UT may be used, provide
the appropriate acceptance criteria is established
139. Which of the following is NOT a requirement for rerating a piping system by changing the temperature or
the MAWP.
a. The existing pressure relieving devices are still in place & set as they were originally.
b. Calculations are performed by the piping engineer or the inspector.
c. Piping flexibility is adequate for design temperature changes.
d. A decrease in minimum operating temperature is justified by impact test results, if required by the
applicable code.
140. Why is inspection of buried process piping (not regulated by DOT)different from other process piping
inspection?
a. The insulating effect of the soil increases the possibility of more internal corrosion
b. Internal corrosion has to be controlled by cathodic protection.
c. Significant external deterioration can be caused by corrosive soil conditions.
d. Internal corrosion must be controlled by internal coatings
141. Indications of leaks in buried piping may include several indications. Which of the ones listed below is NOT
one of the indications.
a. A change in the surface contour of the ground.
b. Water standing on the pipeline right-of-way.
c. Discoloration of the soil.
d. Notice odor.
142. Corrosion cells can form on both bare and coated pipe where bare steel contacts the soil. How can these
cells be detected?
a. Run an acoustic emission test on the piping.
Visually survey the route of buried piping.
c. The potential at the area of corrosion will be measurable different than other areas and a close-interval
potential survey can detect the location of corrosion.
d. Run a internal survey of the piping using a video camera.
143. A pipe coating holiday survey is used to locate coating defects on coated pipes. It can be used on newly
constructed pipe systems to ensure that the coating is intact and holiday-free. More often it is used on
buried pipe to:
a. show the measurable differences in electrical potential in corroded areas.
b. evaluate coating serviceability for buried piping that has been in-service for a long time.
c. determine the depth of the piping for resistivity testing.
d. evaluate the cathodic protection components of the under-ground pipe.
144. Cathodically protected buried piping should be monitored __________ to assure adequate levels of
protection.
a. regularly
b. intermittently
c. erratically
d. frequently
145. If an “intelligent pigging” system is used to inspect buried piping, what type of bends are usually required in
the piping system?
a. Five diameter bends.
b. 90 degree pipe ells.
c. Ten diameter bends
d. Three diameter bends.
146. How often should above-grade visual surveillance of a buried pipeline right-of-way be made?
a. Once a month.
b. Approximately 6 month intervals.
c. Once a year
d. Once every 3 months.
How often should poorly coated pipes with inconsistent cathodic protection potentials have a pipe-to-soil
potential survey made?
a. Yearly.
b. Every 2 years.
c. Every 5 years.
d. Every 7 years.
148. On buried piping, what is the frequency of pipe coating holiday surveys?
a. The frequency is governed by the leak test interval of the pipe.
b. It is usually based on indications that other forms of corrosion control are ineffective.
c. Surveys are normally made every 5 years
d. Pipe coating holiday surveys are made when the pipe is excavated.
149. For piping buried in lengths greater than ________ feet and not cathodically protected, evaluation of soil
corrosivity should be performed at 5-year intervals.
a. 50
b. 75
c. 100
d. 150
150. If buried piping is cathodically protected, the system should be monitored at intervals in accordance with
Section 10 of NACE RP0169 or Section 9 of API RP 651. API RP 651 specifies _________ interval.
a. annual
b. biannual
c. biennial
d. triennial
151. Buried piping inspected periodically by excavation shall be inspected in lengths of ________ feet at one or
more locations judged to be most susceptible to corrosion.
a. 2 to 4
b. 4 to 6
c. 6 to 8
d. 8 to 10
152. After excavation of buried piping, if inspection reveals damaged coating or corroded piping:
a. the condition should be noted in the records and the inspection interval shortened.
b. the complete piping system must be daylighted (excavated) for repair or replacement.
the damaged coating or corroded piping must be repaired or replaced.
d. additional piping shall be excavated until the extent of the condition is identified.
153. If buried piping is contained inside a casing pipe, the casing should be:
a. capable of caring the same pressure as the product pipe.
b. checked to see if its protective coating is intact and serviceable.
c. pressure tested to make sure it is serviceable.
d. inspected to determine if water and/or soil has entered the casing.
154. An alternative or supplement to inspection of buried piping is leak testing with liquid at a pressure at least
____ % greater than the maximum operating pressure at intervals 1/2 the length of those shown in Table
9-1 of API 570 for piping not cathodically protected and at the same intervals as shown in Table 9-1 for
cathodically protected piping.
a. 5
b. 10
c. 25
d. 50
155. The leak test for buried piping should be for a period of ______ hours.
a. 4
b. 8
c. 12
d. 24
156. The leak test for a 8” diameter buried piping system is 300 psi. After 7 hours, the pressure reads 273 psi.
What should the inspector do?
a. Nothing is required. The loss of pressure is negligible and will not affect the test. The loss can be
disregarded
b. The system should be repressured to the original leak test pressure and the test should begin again.
c. The test charts and the temperature should be reviewed to determine if any change in temperature caused
the pressure drop.
d. The piping should be visually inspected externally and/or inspected internally to find the leak and assess
the extent of corrosion.
157. A buried piping system that is not cathodically protected has to have an inspection interval set. The soil
resistivity is checked and found to be 3400 ohm-cm. As the inspector, what interval of would you set?
a. 2.5 year
b. 7.5 years
c. 5 years
d. 10 years
158. Buried piping also may be surveyed for integrity by removing the line from service and performing a leak
test. This inspection method typically involves pressurizing the line with a __________ , allowing time for
the ___________ to diffuse to the surface, and surveying the buried line with a gas-specific detector to
detect the __________.
a. tracer gas (such as helium or sulfur hexafluoride)
b. light hydrocarbon (such as butane)
c. smoke type material (such as chemical smoke)
d. water vapor (such as steam)
159. Repairs to coatings on buried piping may be tested using:
a. a low-voltage holiday detector.
b. light taps with a inspection hammer.
c. an flaw indicator fluid.
d. a high-voltage holiday detector.
160. If buried piping leaks are clamped and reburied,:
a. no further action is required unless the piping leaks again.
b. the date of installation shall be marked on the clamp for future identification.
c. a record of the location and the date of installation shall be maintained.
d. the clamped line shall be leak tested.
161. A 10” diameter piping system with 4” diameter and 6” diameter reinforced branch connections is to have
changes made to it. Which of the following is considered an alteration?
a. A new 1” diameter unreinforced nipple is installed.
b. A new 8” diameter reinforced branch connection is installed.
c. A new 4” diameter reinforced branch connection is installed
d. A new 3” diameter reinforced branch connection is installed
162. Which of the following would not be classified as an applicable code to which a piping system was built?
a. ASME B31.3
b. ASME B31.1
c. ASA B31.1-1955, Section 3
d. ASTM A-20
163. Which of the inspection agencies listed below is NOT an authorized inspection agency as defined in API
570?
a. Jurisdictional inspection organization
b. Owner-user inspection organization.
c. ASTM inspection organization
d. Independent inspection organization.
164. An authorized piping inspector is an employee of an authorized inspection agency who is qualified to
perform the functions specified in API 570. Which individual listed below is not usually an authorized piping
inspector.
a. An owner-user inspector
b. A jurisdictional inspector
c. An NDE examiner.
d. An insurance inspector.
165. Which of the following qualifies as auxiliary piping?
a. control valve manifolds
b. bypass lines around exchangers
c. pump seal oil lines
d. orifice runs.
166. CUI stands for:
a. control unit inspector
b. corrosion under insulation
c. corrected unobtrusive inserts
d. corroded underground installation
167. Deadlegs legs of a piping system are:
a. the upstream piping of control valve manifolds.
b. supports attached to a pipeline that has no product in them.
c. the upstream part of an orifice runs.
sections that normally have no significant flow.
168. A defect is an imperfection of a type or magnitude exceeding the ______ criteria.
a. nonspecific
b. imprecise
c. general
d. acceptable
169. The design temperature of a piping system component is the temperature at which, under the coincident
pressure, the ______________________________________ is required.
a. smallest thickness or highest component rating
b. greatest thickness or highest component rating
c. maximum thickness or lowest component rating
d. minimum thickness or minimum component rating
170. An examiner is a person who _________ the inspector.
a. supplants
b. assists
c. supervises
d. directs
171. Hold point is a point in the repair or alteration process beyond which work may not proceed until the
_______ _________ has been performed and documented.
a. PWHT required
b. required inspection
c. RT required
d. ultrasonic testing
172. What is an imperfection?
a. It is a flaw or discontinuity noted during inspection that may be subject to acceptance.
b. It is a defect noted during inspection that is unacceptable.
c. It is a weld flaw noted during an inspection that may be subject to repair.
d. It is a blemish that is only cosmetic and acceptable under all conditions.
173. _____________ : is a response or evidence resulting from the application of a nondestructive evaluation
technique.
a. indication
b. imperfection
c. breach
d. division
174. What are points where chlorine is introduced in reformers, water is added in overhead systems, etc. called.
a. primary process points
b. level bridle points
c. injection points
d. test points
175. What is the loss of ductility and notch toughness in susceptible low-alloy steels such as 1.25 and 2.5 Cr.,
due to prolonged exposure to high-temperature service called?
a. creep
b. temper embrittlement
c. incipient melting
d. graphitization
176. Secondary process piping is small-bore (less than or equal to _______) process piping downstream of
normally closed block valves.
a. NPS 3/4
NPS 1
c. NPS 2
d. NPS 3
177. A test point is an area defined by a circle having a diameter not greater than _____ inches for a line
diameter not exceeding 10 inches or not greater than ______ inches for larger lines.
a. 3, 4
b. 2, 3
c. 1, 2
d. 3/4, 1
178. When making a repair utilizing a welded full encirclement repair sleeve and the sleeve material is
different from the pipe material, you should:
a. consult the piping engineer.
b. use a weld rod matching the higher strength material.
c. use a weld rod matching the lower strength material
d. use a alloy weld rod such as Inco-A.
179. What type of electrode should be used when welding a full encirclement repair sleeve?179. What type of electrode should be used when welding a full encirclement repair sleeve?
a. low-hydrogen electrode
b. low-phosphorus electrode
c. low-chrome electrode
d. low-nitrogen electrode
180. Which of the following welding electrodes is low-hydrogen?
a. E6010
b. E7016
c. E7011
d. E7014
181. When welding a small repair patch, the diameter of electrodes used should not exceed:
a. 1/8”
b. 3/16”
c. 5/32”
d. 1/4”
182. An industry-qualified UT examiner may be qualified by:
a. API
b. ASNT
c. An equivalent qualification approved by the owner/user
d. Either a or b, above
183. An FFS assessment for general metal loss must be conducted to ________________.
a. RP 578, Section 4
b. RP 579, Section 4
c. RP 579, Section 5
d. RP 579, Section 6
184. The difference between ‘retirement” thickness and “required” thickness is:
a. Retirement thickness includes corrosion/loading allowances.
b. Required thickness includes corrosion/loading allowances
c. One is actual thickness – the other is measured thickness.
d. Retirement thickness is when the pipe must be removed from service.
185. PMI testing is defined as:
a. Alloy analysis using an alloy tester
b. spark testing
c. any physical evaluation that confirms the alloy
d. a qualitative test to confirm carbon content.
186. A 14” O.D. pipe has a corroded area on it. What is the maximum size of a small repair patch that may be
used to cover the corroded area?
a. 3.5”
b. 7”
c. 6”
d. 6.5”
187. A NPS 4 Schedule 80 (0.337” wall) branch is welded into a NPS 12 Schedule 40 (0.406” wall)
header. What size cover fillet weld (tc) is required over the full penetration groove weld? (Express
answer to nearest hundredth)
a. 0.578”
b. 0.286”
c. 0.334”
d. 0.236”
188. A NPS 6 (6.625” od) seamless pipe made from ASTM A335 Grade P2 material operates at 800psi and
600 degrees F. The conditions require that a corrosion allowance of 0.125” be maintained.
Calculate the minimum required thickness for these conditions.
a. 0.290”
0.343”
c. 0.631”
d. 0.524”
189. A NPS 14 (14.00” od) seamless pipe made from ASTM A106 Grade A material operates at 300 psi and
600 degrees F. The pipe must cross a small ditch and it must be capable of supporting itself without a
visible sag. A piping engineer states that the pipe must be at least 0.375” to support itself and the liquid
product. He also states that a 0.125” corrosion allowance must be included. Calculate the minimum
required thickness for the pipe.
a. 0.778”
b. 0.567”
c. 0.642”
d. 0.600”
190. A 10’ long carbon steel pipe is welded to a 10’ 18-8 stainless pipe and is heated uniformly to 475
degrees F. from 70 degrees F. Determine its total length after heating.
a. 20.067''
b. 20.156’
c. 20.234’
d. 20.095’
191. A blank is required between two NPS 10, 300 lb. class flanges. The maximum pressure in the system is
385 psi at 200 degrees F. A corrosion allowance of 0.175” is required. The inside diameter of the gasket
surface is 9.25”. The blank is ASTM A516 Grade 70 material with no weld joint. Calculate the pressure
design thickness required for the blank.
a. 0.789”
b. 0.692”
c. 0.556
d. 0.768”
192. A NPS 14 (14.00” od) seamless pipe made from ASTM A53 Grade B material operates at 600 psi 600
degrees F. Calculate the pressure design thickness for these conditions, using the formula:
t =
PD
2SE
a. 0.243”
b. 0.442''
c. 0.205”
d. 0.191”
193. A NPS 6 piping system is installed in December 1989. The installed thickness is measured at 0.719”. The
required thickness of the pipe is 0.456” It is inspected December 1994 and the measured thickness is
0.608”. An inspection in December 1995 reveals a 0.025” loss from the December 1994 inspection.
During December 1996 the thickness was measured to be 0.571”.
What is the long term corrosion rate of this system?
a. 0.01996”/year
b. 0.02567”/year
c. 0.02114”/year
d. 0.03546” year
194. Using the data in question #193, calculate the short term corrosion rate in mils per year (M/P year)
a. .0012 M/P year
b. .012 M/P year
c. .12 M/P year
d. 12 M/P year
195. Using the information in questions #193 and #194, determine the remaining life of the system.
a. 18 years
b. 5.44 years
c. 1.2 years
d. 6 years
196. Using the information in question #193 - #195 and assuming an injection point in a Class 2 system with 7
years estimated until the next inspection, what would the next UT interval be?
a. 10 years
b. 5 years
c. 3 years
d. 2.72 years
197. A seamless NPS 10 pipe, ASTM A106 Grade B material , operates at 750 psi and 700 degrees F.
maximum. Considering only pressure design thickness, what minimum thickness is required?
a. 0.24”
b. 0.20”
c. 0.28”
d. 0.17”
198. A seamless NPS 16 pipe, ASTM A135 Grade A material operates at 550 psi and 600 degrees F.
maximum. The thickness of the pipe as determined by the last inspection is 0.40”. The pipe has been in
service for 8 years. The original thickness at installation was measured to be 0.844” Two years previous
to the 0.40” measurement the thickness of the pipe was found to be 0.54”.
Determine the greatest corrosion rate, i.e. short or long term in mils per year (M/P year)
a. 55 M/P year
b. 70 M/P year
c. .70 M/P year
d. 700 M/P year
199. A seamless NPS 12 pipe, ASTM A106 Grade B material operates at 750 psi and 700 degrees F.
maximum. The thickness of the pipe as determined by the last inspection is 0.305”. The pipe has been in
service for 13 years. The original thickness at installation was measured to be 0.405” . Two years
previous to the 0.305” measurement the thickness of the pipe found to be 0.316”. The next planned
inspection is scheduled for 8 years. Using the appropriate corrosion rate determine what MAWP the pipe
will withstand at the end of the next inspection period.
a. 720 psi
b. 499 psi
c. 611 psi
d. 550 psi
200. A seamless NPS 6, ASTM A106 Grade A pipe operates at 300 degrees F. and 765 psi. The allowable
stress is 16,000 psi. Using the Barlow equation, determine the required thickness for these conditions.
a. 0.446”
0.332”
c. 0.231”
d. 0.155”
201. A seamless NPS 8, ASTM A106 Grade A pipe operates at 300 degrees F. and 741 psi. The allowable
stress is 16,000 psi. The owner-user specified that the pipe must have 0.125” for corrosion allowance.
Using the B31.3 equation, determine the required thickness for these conditions
a. 0.295”
b. 0.195”
c. 0.321”
d. 0.392”
202. A NPS 4 Schedule 80 (0.337” wall) branch connection is welded into a NPS 6 Schedule 40 (0.280” wall).
A .375” reinforcing pad is used around the branch connection. The fillet weld sizes are as required by the
Code. The branch connection is inserted into the header. The material of the branch and header is ASTM
A672 Grade B70. What thickness would be used to determine whether heat treatment of the this
connection is required? (Express answer to nearest hundredth)
a. 0.768”
b. 0.891”
c. 0.998”
d. 0.567”
203. An Inspector finds a thin area in the body of a NPS 8, 600 lb. gate valve body. The body is made from
ASTM A216 WCB material The system operates at 900 psi and 750 degrees F. Using a corrosion
allowance of 0.125”, what minimum required thickness must the valve body have to continue to safely
operate? (Round to the nearest 3 decimals)
a. 0.492”
b. 0.617”
c. 0.510”
d. 0.345”
204. A seamless NPS 10 pipe, ASTM A106 Gr. B material, operates at 750 psi and 700 degrees F. (maximum).
The thickness of the pipe as determined by the last inspection is 0.30”. The pipe has been in service for 10
years. The original thickness (measured when installed) was 0.365”. Two years previous to the 0.30”
measurement the thickness of the pipe was measured to be 0.31”.
Determine the greatest corrosion rate, i.e., short or long term.
a. 0.0050 inches per year
b. 0.0065 inches per year
c. 0.0100 inches per year
d. 0.0130 inches per year
205. A seamless NPS 10 pipe, ASTM A106 Gr. B material, operates at 750 psi and 700 degrees F. (maximum).
The thickness of the pipe as determined by the last inspection is 0.30”. The pipe has been in service for
10 years. The original thickness (measured when installed) was 0.365”. Two years previous to the 0.30”
measurement the thickness of the pipe was measured to be 0.31”. The next planned inspection is
scheduled for 7 years. Using the worst corrosion rate (short or long term) determine what pressure the
pipe will withstand at the end of its next inspection period?
a. 920 psi
b. 663 psi
c. 811 psi
d. 750 psi
