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HomePiping MCQPiping QC :: Interview Questions and Answers (MCQ) Part-3

Piping QC :: Interview Questions and Answers (MCQ) Part-3

Piping QC Inspector Interview Questions and Answers Part-3

  1. API 570 covers inspection, repair alteration, and re-rating procedures for metallic piping systems that____________.
    a. are being fabricated
    b. does not fall under ASTM B31.3
    c. have been in-service
    d. has not been tested
  2. API 570 was developed for the petroleum refining and chemical process industries
    a. It shall be used for all piping systems.
    b. It may be used, where practical, for any piping system
    c. It can be used, where necessary, for steam piping
    d. It may not be used unless agreed to by all parties
  3. API 570____________ be used as a substitute for the original construction requirements governing a piping system before it is placed in-service.
    a. shall not
    b. should
    c. may
    d. can
  4. 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
    a. Raw, intermediate and finished petroleum products
    b. Water, steam condensate, boiler feed water
    c. Raw, intermediate, and finished chemical products
    d. Hydrogen, natural gas, fuel gas, and flare systems
Piping QC Inspector Interview Questions and Answers Part-3
  • 5. Some of the classes of piping systems that are excluded or optional for coverage under API 570 are listed bellow. Which one is a mandatory included class?
    a. Water
    b. Catalyst lines
    c. Steam
    d. Boiler feed water
  • 6. The __ shall be responsible to the owner-user for determining that the requirements of API 570 for inspection, examination and testing are met.
    a. piping Engineer

    b. Inspector
    c. Repair Organization
    d. Operating Personal
  • 7. Who is responsible for the control of piping system inspection programs, inspection frequencies and maintenance of piping?
    a. Authorized piping Inspector
    b. Owner-User
    c. Jurisdiction
    d. Contractor
  • 8. An authorized piping inspector shall have the following qualifications. Pick the one that does not belong to this list
    a. Four years of experience inspecting in-service piping systems
    b. High school education plus 3 years of experience in the design, construction, repair, operation, or inspection of piping system.
    c. Two year certificate in engineering or technology plus 2 years of experience in the design, construction, repair, operation or inspection of piping systems
    d. Degree in engineering plus one year experience in the design, construction, repair, operation or inspection of piping.

Piping QC Inspector Interview Questions and Answers Part-3

9)- Risk based inspections include which of the following:
a. Likelihood assessment
b. Consequence analysis
c. Operating and inspection histories
d. All of the above

  1. An RBI assessment can be used to alter the inspection strategy provided:
    a. The degradation methods are identified
    b. The RBI is fully documented
    c. A third party conducts the RBI
    d. Both A and B above
  2. Which one of the following is not a specific type of an area of deterioration?
    a. Rectifier performance
    b. Injection points
    c. Deadlegs
    d. Environmental cracking
  3. Injection points subject to accelerated or localised corrosion may be treated as _
    a. The focal point of an inspection circuit
    b. Separate inspection circuits
    c. Piping that must be renewed on a regular schedule
    d. Locations where corrosion inhibitors must be used
  4. The recommended upstream limit of inspection of an injection point is a minimum of ………
    a. 12 feet of 3 pipe lengths whichever is smaller
    b. 12 inches or 3 pipes diameters whichever is smaller
    c. 12 inches or 3 pipe diameters whichever is greater
    d. 12 feet or 3 pipe length which is greater
  5. 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
  6. Select thickness measurement location (TMLs) within injection point circuits subjected to localised 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 atleast one TML at a location atleast 25 feet beyond the downstream limit of the injection point
    c. Establish TMLs on the pipe wall at the location of the expected pipe wall impingement or injected fluid
    d. Establish TMLs at both the upstream and downstream limits of the injection point circuit
    B Gives 25 feet beyond the down stream limit of the injection point. So it is wrong. Please not it is not given as 25 feet beyond the Down stream injection point. The word LIMIT makes the entire difference
  7. 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
    In general UT is More for thickness Measurement , But RRT also can be used for small sizes where UT is not possible ( Profile radiography ) But For defect detection RT is Better

Also Read :
Piping QC Inspector Interview Questions and Answers Part-1
Piping QC Inspector Interview Questions and Answers Part-2

  1. During periodic scheduled inspections, more extensive inspection should be applied to an area beginning ____ upstream of the injection nozzle and continuing for atleast __ pipe diameters downstream of the injection point
    a. 10 inches, 20
    b. 12 feet, 10
    c. 12 inches, 10
    d. 10 feet, 10
    Injection Point Inspection upstream 12 inch or 3 times dia which ever is more
    Injection point Downstream Second change in flow direction or 25 feet beyond thee first change in flow direction which ever is less
    More extensive inspection up steam 12 inch, Down stream 10 times Dia
  2. 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
  1. 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 dead leg 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 setup in the deadleg
    c. Corrosion occurs due to convective currents setup in deadleg
    d. Erosion occurs due to directed currents set up in the deadleg
  2. What is the best thing to do with dead legs that are no longer in service?
    a. Ultrasonically inspect often
    b. Radiograph often
    c. Inspect often
    d. Remove them
  3. What are the most common forms of corrosion under insulation (CUI)
    a. Localised corrosion of non-ferrous metals and chloride stress corrosion cracking of carbon steel
    b. Localised corrosion of chrome-moly steel and chloride stress corrosion cracking of ferritic stainless steel
    c. Localised corrosion of carbon steel and chloride stress corrosion of cracking of austenitic stainless steel
    d. Localised corrosion of nickel-silicon alloy and caustic stress corrosion of austenitic stainless steel
  4. What climatic area may require a very active program for corrosion under insulation?
    a. Cooler northern continent locations.
    b. Cooler direr, mid-continent locations
    c. Warmer, marine locations
    d. Warmer drier, desert locations
  5. 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 over-spray from cooling water towers.
    b. Carbon steel a pipings system that normally operates 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 degree F.
  6. What location is subject to particular attention related to corrosion under insulation and inspection contributes to it?
    a. Location where pipe hangers and other supports exist.
    b. Locations where insulators 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.

Also Read :
Piping QC Inspector Interview Questions and Answers Part-1
Piping QC Inspector Interview Questions and Answers Part-2

  1. Soil-to-Air (S/A) interfaces of 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 14 inches
    d. 6 to 18 inches
  2. At concrete-to-air and asphalt-to-air interfaces of buried piping without cathode protection, the inspector look for evidence that the caulking or seal at the interface has deteriorated and allowed moisture ingress. If such a condition exists on piping system 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
  3. 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 process into non-alloyed piping
    c. Corrosion in Deadlegs
    d. Corrosion of underground piping at soil-to-air interface where it ingresses or egresses
  4. Erosion can be defined as:
    a. Galvanic corrosion of 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 the material to the extend that a rough uniform loss occurs
  5. A combination of corrosion and erosion results in significantly greater metal loss that 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 sulphide or carbonates occur
    c. Surface-to-air interfaces of buried piping
    d. Areas where gradual loss of material occurs because of a corrosive medium
  6. Environmental cracking of austenite stainless steel 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, was-up water, etc
    d. Creep of the material by long time exposure to high temperature and stress

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