API 570 Piping Inspector

API 570 Piping Inspector Sample Questions-Part-1

                                                 

1. For 8” ND Sch 40  and  8” ND Sch 80  pipes,
1. OD for both pipes will be same
2. IDs and ODs  for both pipes will be different
3. Average pipe diameters for both  will be same
4. ID for both pipes will be same

2. Hot tapping is best described by statement:
1. It is technique of heating the pipe to specified temperature and gently tapping with 1 lb.  rounded hammer to detect thinning of pipe wall
2. It is technique of providing a tapping connection while pipe system is in operation
3. It is technique of fixing a water tap on hot water lines for use during winter
4. It is act of using the tap and die for threading the pipe  when the pipe is hot

3. Which of the following defines the term hold point?
1. The point at which a pipe hanger is attached to a pipe. 
2. A point at which a U-clamp is fixed on the pipe.
3. A point at  pipe beyond which work may not proceed until inspections have been performed and documented
4. A trunnion, or sliding shoe used for piping support systems

4. Which of the following statements is true?
1. Flange rating indicates flange diameter.
2. Other factors remaining same, ERW pipes can withstand higher pressure than seamless pipes.
3. Deadlegs means pipes with broken supports.
4. API 570 is applicable for metallic pipes only.

5. Post weld heat treatment is carried out
1. To increase Hardness
2. To increase Tensile strength
3. To release locked-up stresses in the weld
4. None of above.

6. What section of the ASME boiler and pressure vessel code is the basic document for welding procedure qualification?
1. Section III
2. Section VIII
3. Section IX
4. ASME Section II C

7. What can be caused to ferrous metals by the low operating temperatures?
1. Increase of  ductility
2. Loss of ductility and toughness
3. Increase in plasticity or deformation
4. Decrease in yield strength

8. API 570 is intended to apply to:
1. New piping in the chemical Industry
2. Piping that has been placed in service
3. New piping in the Petroleum Refinery
4. New piping in the Paper Industry

9. If a welder is to be qualified in all positions he must pass test in which positions?
1. 1G, 2G, 3G and 4G
2. 5G and 4G
3. 6G 
4. 5G and 4G

10. ASTM A 106 Gr B pipes belong to which type?
1. Seamless only
2. ERW only
3. Seamless or ERW depending on type of Grade
4. None of above

11. Choose correct statement.
1. “REPAIR”  of piping means change of original Design conditions
2. “ALTERATION”  of piping means change of original Design conditions
3. Both are one and same
4. Repair is temporary, alteration is permanent

12. ANSI/ ASME B 31.3 code is meant for:
1. Steam piping in Power stations
2. Piping in Refinery and process plants
3. Cross-country piping
4. Gas transmission piping

  

13. The term “NPS 10 pipe” means:
1. A pipe with National Pressure Standard of 10 bar
2. A pipe whose minimum thickness is 10 mm
3. A pipe whose outside diameter is 10"
4. A pipe whose Nominal diameter is 10"

14. Most of the fluids normally covered by B 31.3 code fall under what category?
1. Category M
2. Category K
3. Category D
4. Normal

  

15. The requirements of the latest edition of ASME Code   Section B 31.3 and any subsequent Addenda become effective:
1. As soon as the latest edition is issued
2. Immediately from date of issue and all piping installed per earlier editions must be upgraded to latest edition/addenda
3. After 6 months from date of issue
4. After 1 year from date of issue

ANSWER KEY

Q. No.	Answer
1	A
2	B
3	C
4	D
5	C
6	C
7	B
8	B
9	C
10	A
11	B
12	B
13	D
14	D
15	C

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API 570 Piping Inspector Practice Questions (Closed Book)Part-2

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             

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.       

ALL SHOULD HAVE MINIMUM ONE YEAR IN THE INSPECTION FIELD

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        

10.  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        

11.  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      

12.  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       

13.  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        

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 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              

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

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          

17.  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         

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 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         

20.  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     

21.  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    

22.  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    

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 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.                                 

                        

24.  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.    

25.  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    

26.  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      

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 process into non-alloyed piping

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 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

                       

29.  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  

30.  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     

   

31.  When the inspector suspects or is advised that specific piping circuits may be susceptible to environmental cracking, the inspector should:

a.    Call in piping engineer for consultation

b.    Investigate the history of the piping circuit

c.    Obtain advise from a Metallurgical Engineer

d.    Schedule supplemental inspection   

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 extent of the problems

c.    The inspector should review history of adjacent piping to determine if it has ever been affected

d.    The inspector should consult with a piping engineer to determine the extend of the problem   

33.  If external or internal coating or refractory liners on a piping circuit are not 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 it a coating of coke is found on the interior of a large pipe of 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 deposit may probably protect the line from corrosion.

d.    Consult with a Process Engineer and a Metallurgist on the necessity of removing the coke deposit.   

35.  Fatigue cracking of pipe system may result from

a.    Embrittlement of the metal due to operating bellow its transition temperature

b.    Erosion or corrosion /erosion that thin the piping where it cracks

c.    Excessive cyclic stress 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 stresses 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, ultra sonic 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

To detect fatigue crack ( Surface  in nature) usually MT & PT Is used, RT & UT are not preferred

                   

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 temperature above___________ degree F

a.    500

b.    900

c.    1000

d.    1200    

40.  Brittle fracture can occur in carbon, low-alloy and other ferritic steels at or bellow_____________ temperature.

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.    Construction 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 the 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 the thickness measurement inspection?

a.    The operator or control man

b.    The inspector or examine

c.    The maintenance workers or supervisors

d.    The jurisdiction or OSHA  

47.  When corrosion product build-up is noted during an external visual inspection at a pipe support contact area, lifting of such supports may be required for inspection. When doing this, care should be

a.    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.  Who would normally report vibrating or swaying piping to engineering or inspection personnel?

a.    Operating personnel

b.    Jurisdictional personnel

c.    Maintenance personnel

d.    OSHA personnel   

49.  Thermography is used to check for:

a.    Vibrating sections of the pipe system

b.    Detecting localized corrosion in the piping system

c.    Abnormal thermal expansion of piping system

d.    Hot spots in refractory lined piping systems   

50.  Thickness measurement locations (TMLs) are specific ______________ along the piping circuit where inspections are to be made

a.    Points

b.    Areas

c.    Items

d.    Junctures   

ANSWER KEY

Q.NO.	ANS	REFERENCE FROM API 570 Book
1	C	1.1.1
2	B	1.1.2
3	A	1.1.3
4	B	1.2.1
5	B	1.2.1
6	B	4.3.4
7	B	4.1
8	A	APX A2
9	D	5.2
10	D	5.2
11	A	BOK
12	B	5.5.9
13	C	5.5.9
14	A	5.5.9
15	B	5.5.9
16	A	5.5.9
17	C	5.5.9
18	C	7.4.3 (574)
19	C	7.4.3 (574)
20	D	7.4.3 (574)
21	C	7.4.4 (574)
22	C	7.4.4 (574)
23	D	7.4.4.1 (574)
24	C	7.4.4.1 (574)
25	B	7.4.5 (574)
26	D	7.4.5 (574)
27	B	7.4.6 .2 C (574)
28	B	7.4.7   (574)
29	A	7.4.7   (574)
30	C	7.4.8.1  (574)
31	D	7.4.8.2 (574)
32	A	7.4.8.3 (571)
33	D	7.4.9.1 (574)
34	A	7.4.9.4 (574)
35	C	7.4.10.1  (574)
36	B	7.4.10.2 (574)
37	B	7.4.10.2 (574)
38	A	7.4.11.1 (574)
39	B	7.4.11.1 (574)
40	B	7.4.12.1 (574)

41	A	7.4.13.1 (574)
42	D	GK
43	C	5.5.1
44	C	5.5.1
45	B	5.5.3
46	B	5.5.3
47	A	5.5.4
48	A	5.5.7
49	D	5.5.8
50	B	3.1.20

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