1.

A fillet-welded external patch installed over a piping system defect:

A) Is considered a permanent repair B) Must be designed by a piping engineer

C) Does not require rounded corners D) Is designed without using joint efficiency

Answer: B … API 570, Para. 8.1.4.1, First sentence … A/C/D are false statements

2. When the MAWP is recalculated for the continued use of a piping system, the wall thickness to be
used is the:

A) Actual thickness
B) Actual thickness minus the estimated corrosion loss before the next inspection
C) Actual thickness minus the discovered corrosion loss since the previous inspection
D) Actual thickness minus 2 times the estimated corrosion loss before a next inspection

Answer: D … API 570, Para. 7.2 … MAWP calculation rules for t  See Table 4

3. CML readings on a piping system indicate that a corrosion rate has increased. The Inspector’s
most appropriate response is to:

A) Recalculate the inspection interval of the system

B) Recalculate the piping circuit average corrosion rate
C) Schedule the next inspection within six months (very soon)
D) Report this change in condition to the Maintenance Supervisor

Answer: A … API 570, Para. 7.1.1, Last Para.  LT & ST corrosion rates should be compared to see
which results in shortest RL as part of the data assessment!

4. A piping system installed in January 1993 (initial thickness 0.320 in.)

In January 2004, a thickness of 0.200 in. was recorded just prior to a change of service in the piping system as
reported to the Corrosion Specialist by the Inspector, who was told to expect a significant decrease in the
corrosion rate. The next thickness in January 2009 measured 0.180 inches. What corrosion rate shall be used
for this line and, given this information, the Retirement thickness of 0.150 inches will be reached on:
A) Corrosion rate almost 9 MPY & retirement thickness will be reached by Jan 2012
B) Corrosion rate almost 9 MPY & retirement thickness will be reached by Jan 2013
C) Corrosion rate of 4 MPY & retirement thickness will be reached by July 2015
D) Corrosion rate of 4 MPY & retirement thickness will be reached by July 2016
Answer: D … API 570, Para. 7.1.1.1 (Last Para) & Corr Rate (ST & LT) & RL Calcs
Solution: The authorized inspector, in consultation with a corrosion specialist, shall select the corrosion rate that best reflects the current
process (last paragraph of Section 7.1.1) … In this case, the ST corrosion rate should be selected which = 4 mils per year (7.5 years of RL
exist)
LT = .32 - .18 = .14 lost in 16 yrs, so .14 (140 mils) ÷ 16 = .00875 (8.75 mils/year)
ST = .20 - .18 = .02 lost in 5 yrs, so .02 (20 mils) ÷ 5 = .004 (4.0 mils/year)
RL = .18 - .15 = .03 (30 mils remaining life) ÷ .004 (4.0 mils/year) = 7.5 years
January 2009 + 7.5 years = July 2016 = Answer D
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5. To which of the following fluid services does API 570 specifically apply?
A) Category D fluid services as defined in ASME B31.3
B) Raw, intermediate, and finished petroleum products
C) Hydrocarbons and utility streams
D) Steam and steam condensate
Answer: B … API 570, Para. 1.2.1 & 1.2.1.a

06. An imperfection exceeding the acceptable criteria is known as a/an:

A) Flaw B) Defect
C) Discontinuity D) Indication

Answer: B … API 570, Para. 3.1.17  Definition of Defect

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7. Which of the following best describes the term undercut?

A) An incomplete bonding between the parent metal and filler metal under the weld
B) A lack of fusion under the cap that appears as a “cut” on a radiographic image
C) A groove melted into the base metal adjacent to weld toe or weld root
D) Incomplete filling of the weld root

Answer: C … API 577, Definition of Undercut (QW-480 ASME IX Definitions also)

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8. Under which of these circumstances must a welder requalify?

A) When a welder’s foreman discovers the welder is not making acceptable welds
B) When a welder has not welded with same P-No in the previous three months
C) When a welder has not worked as a welder for the previous two months
D) When a welder has not requalified within the past twelve months

Answer: D … API 577, Par. 8.2 (KNOW MAJOR RULES) & ASME IX, QW-322.1.a … In this case, SIX-
MONTH RULE APPLIES … A is arguably also correct because of the REASON TO QUESTION HIS
ABILITY RULE … But the reason MAY NOT be his ability … It may be equipment or a variety of other
reasons  D = Best answer
9. Measurements from inspection of Class 3 pipe reveal actual metal thickness of 0.350 inches.
Calculated minimum thickness is 0.250 inches. If the corrosion rate is 0.0025 inches/year, the NEXT
thickness measurement inspection is due in:

A) 3 years B) 5 years C) 10 years D) None of these

Answer: C … API 570, Para. 6.3.3 & Table 2 (Should state NO RBI … old question) Solution: Use the
Lesser of ½ RL or Table 2 Value for UT Class 3 (which is 10 yrs) .350 - .250 = .100 mils RL ÷ 0.0025
loss/yr = 40 yrs RL = ½ RL = 20 years  Use 10

10. Which 2 positions qualify a welder for all positions when welding 8-inch pipe?

A) 2G and 5G B) 1G and 3G
C) 1G and 2G D) 2G and 3G

Ans: A … ASME IX, QW-303 sends you to TABLE QW-469.1 (MUST KNOW TABLE) YOU MUST KNOW
… “6G” RULE & “2G+5G” RULE & “24 NPS RULE PIPE/PLATE … SO BE SURE TO HIGHLIGHT ALL
CRITICAL TABLES IN ASME IX

11. Which of the following valves would make “pigging” impossible?

A) Gate B) Globe C) Slide D) Ball

Answer: B … API 574, Para. 4.3.2 & Figures 4.1/2/3/4 … MUST KNOW Valve basics & CHECK VALVE Q
IN API 570, Section 5.10 … Expect exam Q about valve basics

12. The ASME IX A-number is based on:

A) The group of base metals having specified impact testing requirements

B) The weldability characteristics of a group of metal alloys
C) The chemical composition of the deposited weld metal
D) The chemical composition of the electrode

Answer: C … API 577, Section 7.5 (2nd Sentence), & ASME IX QW-442 & Table  Answer B is correct
for P-numbers … Expect these types Qs on real API exams!!!

13. In pipe caps, corroded areas evidenced by local thinning:

A) May be ignored if in small-bore piping

B) May be ignored if they make up less than 10% of the total area
C) May be evaluated in accordance with the principles outlined in API 579
D) Are considered insignificant if they do not decrease cap t by more than ½ original “t”

Answer: C … API 570, Para. 7.4.a.2 (579 Section 5) … Expect an API 579 answer on your 570 exam 
… A, B & D are nonsense answers!!!
14. After welding is completed, a pressure test should be performed if practical and deemed
necessary by the:

A) Inspector
B) Piping engineer
C) Owner/user & the piping engineer
D) Owner/user’s inspection carrier & the piping engineer

Answer: A … API 570, Para. 8.2.7 (First Para/1st sent) MUST KNOW THIS RULE

15. ASNT recommended Practice SNT-TC-1A is a:

A) Manual covering nondestructive examination (NDE) safety procedures

B) Procedure for the visual examination of piping systems
C) Document covering NDE personnel qualifications
D) Document covering NDE procedures

Answer: C … API 570, Sect 2 Reference/Para. 4.3.5.2 & ASME V … MUST KNOW

16. Vertical supports constructed of pipe components should be checked to determine if they are
filled with water, because water inside a support may cause:

A) Internal corrosion of the support B) Internal corrosion of the process pipe

C) External corrosion of the support D) Additional stress to be placed on a support

Answer: A … API 570, Para. 5.5.4 (2nd Paragraph)  External Inspection Question

17. The recommended MAXIMUM inspection interval at an injection point for thickness measurement
for an injection point circuit is:

A) 3 years or ½ remaining life, whichever is less

B) 5 years or ½ remaining life, whichever is less
C) 10 years or ½ remaining life, whichever is less
D) None of these are correct because it is determined by piping classification

Answer: A … API 570, Section 6, Table 2  3 years rule

18. A metal thickness reading of 0.220 inches was obtained on June 1, 2006. The baseline reading for
the thickness measurement location (TML) was 0.250 inches on May 31, 2000. The corrosion rate is:

A) 0.003 inches per year (3 MPY) B) 0.005 inches per year (5 MPY)
C) 0.006 inches per year (6 MPY) D) 0.010 inches per year (10 MPY)

Answer: B … API 570, Section 7.1  Corrosion rate formula

19. The responsibility for qualifying repair welders is restricted to the:

A) Welding Qualification Test Company employed by the owner/user

B) Owner/user of the site where the repaired equipment will be used
C) Contractor or manufacturer employing the welder
D) Welder’s supervisor

Answer: C … API 577, 2nd last sentence in Para 8.1 & ASME IX, QW-300.2(a)

20. What is the cause for rejection of the “B” image on a film due to excessive backscatter?

A) Light image of the Letter B

B) Dark image of the Letter B
C) Any image of the Letter B
D) No image of the Letter B

Answer: A … API 577 Para. 9.8.9.4  Light image of B on a dark background

21. Which inspection method is most appropriate for detecting chloride stress corrosion cracking in
austenitic stainless-steel piping systems?

A) Longitudinal wave ultrasonics

B) Dry magnetic particle method
C) Liquid Penetrant
D) Radiography

Answer: C … API 571, Para. 4.5.1.7.b

22. If the corrosion rate for a piping system cannot be determined by similar service, initial thickness
measurements should be taken within:

A) 3 months B) 6 months
C) 9 months D) 1 year

Answer: A … API 570, Para 7.2.1.c  3-month rule to determine corrosion rate

23. In-service ultrasonic testing measurements at TML points indicate thinning in the heat-affected
zone of an elbow-to-weld neck flange on an NPS 30 vapor line. What is the best method to determine
the extent of the deterioration during the next scheduled downtime?

A) Internal inspection
B) UT A-scan of the elbow
C) Spot radiograph of the welds
D) Full radiography of the elbow

Answer: A … API 570, Para. 5.5.1 … 2nd sentence

24. On what basis are image quality indicators selected?

A) The strength of the radiation source

B) The film type used by the radiographer
C) The alloy content of the material being radiographed
D) The thickness of base material plus weld reinforcement

Answer: D … ASME V, Art T-276 (a) & (b) … IQI reinforcement rule (Table T-276)

25. Inspection of small-bore piping (SBP) that is part of a Class 2 secondary process system is:

A) Optional
B) Outside the scope of API 570
C) Performed at the same intervals as for Class 2 primary process piping
D) Performed at the same intervals as for Class 3 primary process piping
Answer: C … API 570, Section 6.6.1 … 2nd Paragraph

26. Dead legs include all of the following EXCEPT:

A) Lines with one end blanked

B) Control valve bypass lines
C) Relief valve inlet and outlet header piping
D) Sample points, drains, bleeders, and instrument connections
Answer: B (API 570, Para. 3.1.16)

27. Which of the following statements are correct?

A) Soil resistivity is a measure of resistance used by drilling operations in oil exploration and it has no connection with
corrosive soil
B) Soil resistivity has nothing to do with corrosiveness of soil because soil corrosion depends on the amount of corrosive
chemicals present in the soil
C) Lower soil resistivity indicates less corrosive soil
D) Higher soil resistivity indicates less corrosive soil
Answer: D (API 570, 9.1.4 on Soil Resistivity) HIGHER soil resistivity indicates LESS corrosive soil … and
therefore, LOWER soil resistivity will indicate MORE corrosive soil

28. Any welding conducted on piping components in operation shall be done in accordance with API 2201
29. A buried piping system for 100 psig service is hydrostatically tested at 125 psig for 8
hours. After 4 hours, the pressure dropped 5 psig, and the system was repressurized
back to 125 psig. During the remaining 4 hours, the pressure drop was noted again to
be by 5 psig. According to API 570, the inspector should:
A) Accept the test as successful
B) Visually inspect the piping and find the leak
C) Repeat the test and conduct further inspection
D) Excavate the piping and conduct an external visual inspection

30. For piping systems where service conditions have been changed, if data for the
same or similar service is not available, a corrosion rate is estimated from the
experience of the owner/operator or from:
A) Published data on piping systems in comparable service
B) The highest known corrosion rate in the unit
C) A default corrosion rate of 10 mils per year
D) Worst case industry data

Answer: A … API 570, Para. 7.1.2.b …

31. A fillet-welded external patch installed over a piping system defect:

A) Is considered a permanent repair B) Must be designed by a piping engineer

C) Does not require rounded corners D) Is designed without using joint efficiency

Answer: B … API 570, Para. 8.1.4.1, First sentence … A/C/D are false statements

32. TML readings on a piping system indicate that a corrosion rate has increased. The
Inspector’s most appropriate response is to:

A) Recalculate the inspection interval of the system

B) Recalculate the piping circuit average corrosion rate
C) Schedule the next inspection within six months (very soon)
D) Report this change in condition to the Maintenance Supervisor

33. Which of the following best describes the term undercut?

A) An incomplete bonding between the parent metal and filler metal under the weld
B) A lack of fusion under the cap that appears as a “cut” on a radiographic image
C) A groove melted into the base metal adjacent to weld toe or weld root
D) Incomplete filling of the weld root
Answer: C … API 577, Definition of u/c
34. Vertical supports constructed of pipe components should be checked to determine
if they are filled with water, because water inside a support may cause:

A) Internal corrosion of the supportB) Internal corrosion of the process pipe

C) External corrosion of the support D) Additional stress to be placed on a support

Answer: A … API 570, Para. 5.5.4 (2nd Paragraph)  External Inspection Question

35. The responsibility for qualifying repair welders is restricted to the:

A) Welding Qualification Test Company employed by the owner/user

B) Owner/user of the site where the repaired equipment will be used
C) Contractor or manufacturer employing the welder
D) Welder’s supervisor

Answer: C … API 577, 2nd last sentence in Para 8.1 & ASME IX, QW-300.2(a)

36. If the corrosion rate for a piping system cannot be determined by similar service,
initial thickness measurements should be taken within:

A) 3 months B) 6 months
C) 9 months D) 1 year

Answer: A … API 570, Para 7.2.1.c3-month rule to determine corrosion rate

37. Acceptance of a welded repair or alteration shall include NDE in accordance with
the applicable code and:

A) B31.3 specifications
B) Owner/user specifications
C) ASME/ANSI V specifications
D) Guidelines of owner/user’s insurance carrier

Answer: B … API 570, Section 8.2.6, 1st Sentence

38. On what basis are image quality indicators selected?

A) The strength of the radiation source

B) The film type used by the radiographer
C) The alloy content of the material being radiographed
D) The thickness of base material plus weld reinforcement

Answer: D … ASME V, Art T-276 (a) & (b) … IQI reinforcement rule (Table T-276)
39. Polyethylene are not specifically covered by this Code./

40. The owner/user is also responsible for implementing an effective MOC process that will
review and control changes

41. The test fluid If the liquid is flammable, its flash point shall be at least 120 °F (49 °C) or
greater.

42. full encirclement welded split sleeve or box-type enclosure designed by the piping
engineer may be applied over the damaged or corroded area.

43. Any welding conducted on piping components in operation shall be done in accordance
with API 2201.

44-The materials used in making repairs or alterations shall be of known weldable quality.

45. Piping inspected periodically by excavation shall be inspected in lengths of 6 ft to 8 ft (2.0

m to 2.5 m).

46 An alternative or supplement to inspection is leak testing with liquid at a pressure at least

10 % greater than maximum

47-The temperature of the calibration standard should be within 25 °F (14 °C) of the part to be
examined
48-lead letter “B” USED FOR backscatter radiation .

49. (API 571 )MIC corrosion is usually observed as localized pitting under deposits or tubercles that
shield the organisms

50.filler metal not listed in ASME 9 can use to weld: when WPS qualified and welder qualified.

51. When a piping inspector notices deformation of a pressure attachment , the most
appropriate of the following action:
1. Note the deformation in the inspection report.
2. Recommend an immediate shutdown of the unit .
3. Check for piping misalignment.
4. Calculate the allowable deformation.
51. local PWHT may be considered for piping repairs under all of the following conditions
except when the: (
1. Pipe wall thickness exceeds ½ inch (13 mm)
2. PWHT is for environmental cracking resistance .
3. Material has higher than 12 % chrome content.
4. Pipe diameter exceeds NPS 12 (DN300).

52. Measurements from an inspection of a class 3 pipe reveal metal thickness of 0.350 inch
(8.89mm). the calculated minimum thickness is 0.250inch (6.35mm).if the corrosion rate is
0.0025 inches (0.064mm) per year, the next thickness measurement inspection should be
scheduled within: \
1. 3 years.
2. 5 years.
3. 10 years
4. 20 years

53. The ASME section ix A number is based on:

1. the weldability characteristics of metal alloys.
2. the chemical composition of the electrode .
3. the chemical composition of the deposited weld metl.
4. a group of base metals having specified impact test requirements.

54. In pipe caps, corroded areas evidenced by local thinning:

1. May be ignored in small-bore piping.
2. May be ignored if they make up less then 10%of the total area.
3. May be evaluated in accordance with principles outlined in Api Rp579.
4. are considered insignificant if they do not decrease cap thickness by more than half the Original thickness.

55. An alternative or supplement to the inspection of buried piping is leak testing with liquid . At what
percentage greater than the maximum operating pressure should this test be conducted?
1. 5%.
2. 10%.
3. 25%.
4. 50%.

56. Which of the following valves would make “ pigging” impossible?

1. Gate.
2. Globe.
3. Slide.
4. Ball.
 57. After welding is completed, a pressure test should be performed if it is practicle and deemed necessary by the :

1. Inspector.
2. Owner /user and the piping engineer.
3. The piping engineer.
4. Owner/user’s insurance carrier and the piping engineer.

58. ASNT Recommended Practice SNT-TC-1A is a: (ASME IX- QW-191.2.2)

1. Manual covering nondestructive examination (NDE) safety procedures.
2. Document covering NDE personnel qualifications.
3. Document covering NDE procedures.
4. Procedure for the visual examination of piping systems

59. Vertical supports constructed of pipe components should be checked to determine if they are filled with water ,
because water inside a support may cause: (API 570- 5.5.4)
1. Internal corrosion of the support.
2. Internal corrosion of the process pipe.
3. External corrosion of the support.
4. Additional stress to be placed on the support.

60.Which inspection method is most appropriate for detecting external chloride stress corrosion cracking in
austenitic stainless-steel piping system ?
1. Dry magnetic – particle.
2. Liquid – penetrant .
3. Longitudinal ultrasonic.
4. Radiography.

61. Vibrating and swaying piping , liquid hammer, liquid slugging in vapor lines or abnormal thermal expansion, can
lead to which type of deterioration mechanism? (API 570- 5.5.7)
1. Fatigue cracking .
2. Creep cracking.
3. Stress –corrosion cracking.
4. Brittle facture.

62. Materials used in repairing or altering piping systems must be:

1. the original construction materials. (API 570- 8.2.5)
2. compatible with 7018 weld electrodes.
3. approved by the maintenance manager.
4. of known weldable quality.
63. when taking CML on elbows what are the areas of special attention
1. in the HAZ of both welds. (API 570-5.6.2)
2. Outside radius only.
3. At all four quadrants.
4. Inside and outside radii.

64. The table below shows the years of operation and corresponding wall thickness of a Class 1 piping system .
Years of Operation Wall Thickness
0 0.455 inch (11.6 mm)
3 0.420 inch (10.7 mm)
4 0.415 inch ( 10.5 mm)
For a minimum required thickness of 0.380 inch ( 9.652 mm) , the shortest remaining life of the piping system is :
1. 1.75 years.
2. 3.5 years.
3. 5 years.
4. 7 years.

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65. A piping circuit containing hydrocarbons is located within the boundary limits of an operating unit. The
hydrocarbons, if released, would evaporate slowly. According to API standard 570, what classification should this piping
receive?
1. Class 1. (API 570- 6.3.4.3)
2. Class 2.
3. Class 3.
4. Auxiliary.
5.
66. A piping system has an assumed corrosion rate of 0.010 inch per year. An inspection shows an actual short term
corrosion rate of 0.021 inch per year .The proper course of action would be to:
1. Place corrosion tabs of a known like material and thickness into the piping system to establish the actual
corrosion rate.
2. Average the previous and present corrosion rate and inspect the piping at one-half the calculated
inspection interval.
3. Adjust the rate of corrosion to agree with the actual corrosion rate.
4. Recalculate both the long term and short term corrosion rate and use the most conservative value.

67. long –term and short –term corrosion rates should be compared in order to:
1. locate thin areas.
2. check calculations for accuracy.
3. validate CML locations.
4. determine the shortest remaining life.
68. API 570 Fluid included service ( 1.2.1)

69. API 570 Optional Service (1.2.2).

70. Statistical analysis employing point measurements is not applicable to piping circuits with
significant localized unpredictable corrosion mechanisms

71. Classes 1,2,3,

72. A106 Gr. B Welded With A234 WBP required hydrotest pressure All given and u will collect
Allowable Stress from B31.3 for both material at Design and operation temp. and choose the lesser of
Stress ratio for Hydro test pressure.

73. Slag…. Is an Inclusion

74. Process piping systems that are temporarily out of service but have been mothballed (preserved
for potential future use) are still covered by this Code.

75. An engineering methodology whereby flaws and other deterioration/damage contained within
piping systems are assessed in order to determine the structural integrity of the piping for continued
service Answer : Fitness-For-Service evaluation

76. Ultrasonic thickness measurements taken on small bore pipe (NPS 2 and below) may require
specialized equipment (e.g. miniature transducers and/or curved shoes as well as diameter specific
calibration blocks).

77. Temp. Correction for UT is 65 Degree.

78. CUI Temp.

79. The liquid is flammable, its flash point shall be at least 120 °F (49 °C) or greater,

80. A pneumatic pressure test may be used when it is impracticable to hydrostatically test.

81. Any fastener failing to do so is considered acceptably engaged if the lack of complete engagement
is not more than one thread.
82. As a default criteria for a valve being stuck shut, use a max 150 % of set pressure beyond which
the valve is classified as stuck shut if it does not pop, and the test is discontinued.

83. For repaired or in-kind replacement piping, the corrosion rate shall be established based on the
previous worse case measured rate at the replacement location or the circuit average rate.

84. If calculations indicate that an inaccurate rate of corrosion has been assumed, the rate to be used
for the next period shall be adjusted to agree with the actual rate found.

85. The required thickness of a pipe shall be the greater of the pressure design thickness or the
structural minimum thickness.

86. API 570 (8.2.8 (b) (1) : slip-on flanges for design cases up to Class 150 and 500 °F (260 °C)

87. API 570 (9.3) Close-interval Potential Survey

88. An alternative or supplement to inspection is leak testing with liquid at a pressure at least 10 %
greater than maximum operating pressure.

89.API 570 Table 4 (Soil resistivity inspection interval).

90. Raised face of Flange 400 rating is 07mm.

91. ‫ مسائل‬CR , R/L