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API 570 > Section 6B - Interval & Extent Of Inspection (API 570 pg 47-51) > Flashcards

Section 6B - Interval & Extent Of Inspection (API 570 pg 47-51) Flashcards

1
Q
  1. On- site process services that are flammable but slowly vaporize during a release, such as those that operate below the boiling point but above the flash point, are considered:

A. Class 1 piping
B. Class 2 piping.
C. Class 3 piping.
D. Class 4 piping.

A

B. Class 2 piping.

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2
Q
  1. On-site process services that are flammable but do NOT significantly vaporize during a release, such as those that operate below the flash point, are considered:

A. Class 1 piping
B. Class 2 piping.
C. Class 3 piping.
D. Class 4 piping.

A

C. Class 3 piping.

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3
Q
  1. An on-site piping system was classified by B31.3 as category D. What is the API 570 classification for this piping?

A. Class 1 piping
B. Class 2 piping.
C. Class 3 piping.
D. Class 4 piping.

A

D. Class 4 piping.

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4
Q
  1. Off-site gasoline is considered as:

A. Class 1 piping
B. Class 2 piping.
C. Class 3 piping.
D. Class 4 piping.

A

C. Class 3 piping.

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5
Q
  1. Off-site caustic is considered as:

A. Class 1 piping
B. Class 2 piping.
C. Class 3 piping.
D. Class 4 piping.

A

C. Class 3 piping.

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6
Q
  1. In petrochemical industry, the majority of the unit process piping is classified as:

A. Class 1
B. Class 2
C. Class 3
D. Class 4

A

B. Class 2

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7
Q
  1. Inspection of class 4 piping is:

A. Optional.
B. Based on environmental impacts.
C. Based on health and safety impacts.
D. Completed at least every 10 years.

A

A. Optional.

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8
Q
  1. Inspection of class 4 piping is based on:

A. Environmental impacts.
B. Health and safety impacts.
C. Business impacts.
D. Corrosion specialist’s opinion.

A

C. Business impacts.

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9
Q
  1. External inspection intervals on piping can be established by using a valid RBI assessment conducted in accordance with:

A. API 570.
B. API 578.
C. API 579.
D. API 580.

A

D. API 580.

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10
Q
  1. Which of the following is NOT a factor that could affect the likelihood of CUI on an existing piping system?

A. Local climate conditions.
B. The condition of the coating system.
C. Process fluids.
D. Insulation design and condition.

A

C. Process fluids.

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11
Q
  1. CUI can occur on insulated carbon steel piping systems operating between:

A. 25–250°F.
B. 10–350°F.
C. 40–125°F.
D. 120–400°F.

A

B. 10–350°F.

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12
Q
  1. CUI is found at a damaged insulation area. What should be done?

A. Inspect additional areas of the piping system.
B. Inspect a minimum of 50% of the piping system.
C. Strip insulation and inspect 100% of the affected piping system.
D. Inspector stands in the pipe rack and shouts “Eureka, I found it!”

A

A. Inspect additional areas of the piping system.

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13
Q
  1. A class 4 piping system has some damaged insulation. How many of the damaged areas should be inspected? (Open book)

A. 25%
B. 50%
C. 75%
D. 100%
E. Inspection is optional

A

E. Inspection is optional

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14
Q
  1. A class 1 piping system has some damaged insulation. How many of the damaged areas should be inspected? (Open book)

A. 25%
B. 50%
C. 75%
D. 100%

A

C. 75%

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15
Q
  1. A class 3 piping system has some damaged insulation. How many of the damaged areas should be inspected? (Open book)

A. 25%
B. 50%
C. 75%
D. Inspection is optional

A

A. 25%

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16
Q
  1. A class 1 piping system is being inspected for CUI. How many of the non-damaged areas should be inspected? (Open book)

A. 10%
B. 25%
C. 33%
D. 50%
E. 75%
F. 100%

A

D. 50%

17
Q
  1. A class 3 piping system is being inspected for CUI. How many of the non-damaged areas should be inspected? (Open book)

A. 10%
B. 25%
C. 33%
D. 50%
E. 75%
F. Inspection is optional.

A

A. 10%

18
Q
  1. What is the recommended extent of CUI inspection at non-damaged locations on class 2 piping systems? (Open book)

A. 75%
B. 50%
C. 33%
D. 10%.

A

C. 33%

19
Q
  1. When thickness measurements are conducted on a pipe circuit, each thickness measurement set should include:

A. A representative #of CML’s.
B. All CMLs
C. At least 50% of the CMLs
D. At least 75% of the CMLs

A

A. A representative #of CML’s.

20
Q
  1. When thickness measurements are taken, each thickness measurement set should include:

A. All CMLs
B. CMLs on each type of component, e.g. ells, tees.
C. The CML with the lowest remaining corrosion allowance.
D. The CML with the longest remain life.

A

B. CMLs on each type of component, e.g. ells, tees.

21
Q
  1. When thickness measurements are conducted , each thickness measurement set should include:

A. The CML with the highest corrosion rate.
B. The CML with the earliest renewal date.
C. The CML with the lowest remaining corrosion allowance.
D. All CMLs in the piping circuit.

A

B. The CML with the earliest renewal date.

22
Q
  1. Thickness measurements on a pipe circuit are due. This circuit is subject to non-uniform corrosion. Who is responsible to determine the specific CMLs that need to be measured?

A. Authorized inspector.
B. Corrosion specialist.
C. Authorized inspector in consultation with the corrosion specialist.
D. Authorized inspector in consultation with the piping engineer.
E. Authorized inspector in consultation with either the corrosion specialist or the Piper engineer.

A

E. Authorized inspector in consultation with either the corrosion specialist or the Piper engineer.

23
Q
  1. Which two methods can be used to manage the thickness measurement’s program?

A. Circuit analysis and point-to-point methods.
B. Circuit analysis and exponential methods.
C. Exponential and point –to– point methods.
D. Point–to-point and relative analysis methods.
E. Relative analysis and circuit analysis methods.

A

A. Circuit analysis and point-to-point methods.

24
Q
  1. The point – to - point method for thickness measurements may lead to:

A. Failures if not closely managed.
B. Frequent inspections if not closely managed.
C. Overly conservative corrosion rates.
D. Overly conservative inspection intervals.

A

B. Frequent inspections if not closely managed.

25
Q
  1. The circuit analysis method may use:

A. FFS analysis to determine a representative minimum thickness.
B. FFS analysis to determine a representative circuit corrosion rate.
C. Statistical analysis to determine a representative minimum thickness.
D. Statistical analysis to determine a representative circuit corrosion rate.

A

D. Statistical analysis to determine a representative circuit corrosion rate.

26
Q
  1. The circuit analysis method is applicable with:

A. All forms of wall loss.
B. Only highly localized corrosion.
C. Only uniform corrosion.
D. Only uniform or mildly localized corrosion.

A

D. Only uniform or mildly localized corrosion.

27
Q
  1. When performing analysis of thickness data, which is the least important to check?

A. Are corrosion rates accelerating?
B. Are any CML remaining life’s below 20 years?
C. Are particular locations corroding faster?
D. Are particular types of components corroding faster than others?
E. Is the short-term rate significantly different than the long-term rate?

A

B. Are any CML remaining life’s below 20 years?

28
Q
  1. When taking thickness readings on a circuit that is subject to localized corrosion:

A. 50% of the CMLs should be inspected with profile RT.
B. 100% of the CMLs should be inspected with profile RT.
C. The orientation of the sample point should be recorded.
D. A 360° UT scan should be conducted at each CML.

A

C. The orientation of the sample point should be recorded.

29
Q
  1. Which of the following is not a good reason for making a CML “inactive”?

A. CML is on a small-bore class 3 deadleg
B. CML is inaccessible during operation.
C. CML was inappropriately placed.
D. Historically this CML has very little corrosion.

A

A. CML is on a small-bore class 3 deadleg

30
Q
  1. Inspection of primary process piping that is small-bore:

A. Should be done to the same requirements as large-bore piping.
B. Should be done to the requirements of large bore class 2
Piping.
C. Should be done to the requirements of large bore class 3 piping.
D. Is optional.

A

A. Should be done to the same requirements as large-bore piping.

31
Q
  1. Inspection of class 1 small – bore secondary process piping is:

A. Done to the requirements of large-bore Class 1 primary piping.
B. Done to the requirements of large-bore Class 2 primary piping
C. Done to the requirements of large-bore Class 3 primary piping.
D. Optional.

A

A. Done to the requirements of large-bore Class 1 primary piping.

32
Q
  1. Inspection of class 2 small – bore secondary process piping is:

A. Done to the requirements Class 1 primary piping.
B. Done to the requirements Class 2 primary piping
C. Done to the requirements Class 3 primary piping.
D. Optional.

A

B. Done to the requirements Class 2 primary piping

33
Q
  1. Inspection of class 3 or class 4 small – bore secondary process piping is:

A. Done to the requirements Class 1 primary piping.
B. Done to the requirements Class 2 primary piping
C. Done to the requirements Class 3 primary piping.
D. Optional.

A

D. Optional.

34
Q
  1. Who is responsible to determine if a deadleg is susceptible to accelerate corrosion?

A. Authorized inspector.
B. Corrosion specialist.
C. Piping engineer.
D. Process engineer.

A

B. Corrosion specialist.

35
Q
  1. Which of the following is NOT a potential causes of accelerated corrosion in deadlegs?

A. Accumulation of dense hydrocarbons.
B. Accumulation of solids.
C. Accumulation of water.
D. Accumulation of a corrosive materials like ammonium salts.
E. Temperature different than mainline.

A

A. Accumulation of dense hydrocarbons.

36
Q
  1. With non-essential deadlegs, consideration should be given to:

A. Increasing the alloy content
B. Performing 50% UT scan or 50% profile RT.
C. Performing 100% UT scan or 100% profile RT.
D. Removing them.

A

D. Removing them.

API 570 (16 decks)

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