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229 Cards in this Set
- Front
- Back
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API 570 covers what? |
inspection, repair, and alteration for metallin and fibergalass reinforced plastic piping systems.
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What is the intent of api 570 |
To specify the in service inspection and condition monitoring program to ensure the integrity of piping. |
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What are the limitations of API 570 |
It is not a substitute for the original code of construction. |
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What are included fluid services? |
petroleum products, chem. products, catalyst lines, hydrogen, natural gas, fuel gas, flare syustems, sour water, haz. waste streams, cryogenic fluids, and high pressure gases |
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What are optional fluids under API 570? |
haz. fluid services below threshold limits, water, steam, steam conddensate, boiler feed water, and Cat. D fluid |
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What are the min. contents of an inspection plan? |
define type of insp. needed, identify future inspection dates, describe insp. methods and BNDE, describe the extent and locations of insp. and NDE at CML's, describe req. for pressure tests, describe repairs previously planned |
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What is API 580 |
Provides elements for developing, implementing, and maintaining a risk based inspection program |
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What factors in API 580 are used to assess the consequence of a release? |
Size of release, type of a release, potential outcomes to include: health effects, environmental impact, additional equipment damage, and process downtime or slowdown. |
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When should RBI assessments be updated? |
Ater each equipment inspection as defined in API 580 |
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What are inspectors required to do before performing inspections on piping systems? |
They shall review prior history of systems, prior inspection results, prior repairs, current inspection plan, and/or similar service inspections. |
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What are damage mechanisms that cause general and local metal loss? |
Sulfidation, oxidation, microbiologically influenced corrosion, organic acid corrosion, erosion, galvanic corrosion, CUI |
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What are damage mechanisms that cause surface connected cracking? |
Fatigue, caustic stress corrosion cracking, sulfide stress cracking, chloride stress corrosion cracking, polythionic acid stress corrosion cracking, other forms of environmental cracking |
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What are damage mechanisms that cause subsurface cracking? |
hydrogen induced cracking |
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What are damage mechanisms that cause microfissuring/microvoid formation? |
High temp. hydrogen attack creep |
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What are damage mechanisms that cause dimensional changes? |
Creep,stress rupture, and thermal |
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What are damage mechanisms that cause changes in material properties? |
Brittle fracture |
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Who performs, and who authorizes on stream inspections? |
The examiner performs, and the inspector authorizes. |
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What are appropriate responses to accelerated corrosion rates? |
Additional thickness readings, UT scans in suspect areas, corrosion/process monitoring, revisions to the piping insp. plan, and addressing nonconformances. |
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What should you do when corrosion buildup is noted at pipe support contact areas? |
Consult with the eng. if necessary and determine if it is necessary to lift the pipe for insp. |
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What type of insp. is preferred for exp. joints and what should the inspector be looking for? |
Visual, unusual deformations, misalignment, and non standard piping components that may have diff. rates of degradation. |
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What does API 574 cover? |
Inspection practices for piping components. |
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What should inspectors look for where vibrating piping systems are restrained to resist dynamic pipe stresses? |
MT or PT should be considered to check for fatigue cracking. Branch connections in particular, should receive special attention. |
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Can injection points that are subject to accelerated or localized corrosion from normal or abnormal operating contitions be treated as separate insp. circuits? |
Yes.
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How far upstream of the injection point is the recommended upstream limit of the injection point circuit? |
12" or 3 pipe dia. |
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What is the recommended downstream limit of the injection point circuit? |
The second change in flow direction past the inj. point, or 25 ft. beyond the first change iin flow direction, whichever is less. |
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When can CML's be eliminated or reduces? |
Olefin plant cold side piping, anhydrous ammonia piping, clean noncorrosive hydrocarbon product, or high allow piping for product purity. |
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How can the min. thickness at each CML be determined |
Throught RT or UT |
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When using UT, how thin areas be determined to calculate corrosion rates, remaining life, and next insp. date? |
You can take the thinnest reading, or an ave. of several insp. points within the area of examination. |
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Where should CML's be established? |
Areas with continuing CUI, corrosion at S/A interfaces, or other locations of potential localized corrosion. |
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Why should CML's be marked on drwgs and on the piping system? |
To allow for repetitive measurements at the same CML's. |
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How should the insp. decide on the type, number and locations of CML's? |
The insp. should take into acct....patterns of corrosion, results from previous insp., and potential consequences of loss of containment. |
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What types of corrosion common to refining and petrochem units are relatively uniform in nature? |
High temp. sulfur corrosion and sour water corrosion. |
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What are characteristics that should result in more CML's? |
potential for safety or environmental emergency in case of a leak, higher corrosion rates, higher potential for localized corrosion, more complexity with many branches/fittings, higher potential for CUI, |
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What are factors that can reduce the number of CML's necessary? |
Low potential for a safety or environmental emergency in case of a leak, relatively noncorrosive piping systems, long, straight runs |
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What factors can lead to the elimination of CML's? |
Extremely low potential for a safety or environmental emergency in case of a leak, noncorrosive systems, systems not subject to changes that could cause corrosion. |
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What is the preferred method of determining thickness of NPS 1 and smaller pipe? |
RT |
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What kind of specialized UT equip. might be needed for NPS 2 or smaller pipe? |
miniature transuducers, curved shoes, diameter specific calibration blocks. |
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What API code should you reference for additional information on monitoring thickness of pipe? |
API 574 |
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What type of condition in a pipe would require additional thickness measuring? |
Nonuniform corrosion, remaining thickness approaching t min. |
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At what temp. should high temp. couplants, instruments, and procedures be used to perform UT? |
Above 150 deg. F |
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What are factors that can reduce the accuracy of UT readings? |
Improper instrument calibration, external coatings or scale, significant surface roughness, rocking of the probe, subsurface flaws, te p. effects, improper resolution on detector screens, thickness of less than 1/8" for typical digital thickness guages, improper coupling of probe to the surface. ( too little or too much couplant) |
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How should the inspector determine the type of damage to a piping system? |
Consult with a corrosion expert or engineer. |
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Which API code provides general guidance on inspection techniques that are appropriate for different damage mechanisms? |
API 571 |
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What can be used to determine the depth of localized metal loss? |
Pit gauges |
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What is a good NDE type to use to detect cracks and other linear discontinuities that extend to the surface of the material in ferromagnetic materials? |
MT |
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What is a good NDE type to use to detect cracks, porosity, pin holes, and other surface imperfections......esp. in nonmagnetic materials? |
PT |
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What is a good NDE type to detect internal imperfections such as porosity, weld slag, cracks, and thickness of components? |
RT |
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What is a good NDE type to detect temp. of components? |
Thermography |
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What code should the 570 inspector generally refer to for hydrotesting? |
B31.3 |
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Can a pressure test be performed on individual components/sections in lieu of the entire circuit? |
Yes, where practical. An eng. should be consulted. |
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If a tightness test is to be performed at a lower pressure than req. for hydrotest......who designates that pressure? |
The owner / user |
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If a carbon, low alloy, or high alloy steel that is embrittled by service exposure succumbs to brittle failure........when is that likely to happen |
upon the first hydrotest or overload. |
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How can you minimize the risk of brittle fracture during a pressure test? |
By maintaining the metal temp at least 30 deg F. above the MDMT for piping that is more than 2" thick, and 10 deg. F above the MDMT for piping that is 2" or less |
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What steps can be take with relief valves when they are included on a pressure test in which thte pressure will exceed the their set pressure? |
The relief valve should be removed, blanked, or held down by a suitable designed clamp for the pressure test. Other appurtenances such as gauge glasses, pressure gauges, expansion joints and rupture disks....should also be removed. |
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What must you have before you can substitute NDE for a pressure test after an alteration? |
Approval by the engineer and inspector. |
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Which API code should you consult for help with constructing a material identification program? |
API 578 |
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Upon discover of incorrect material substituted for the correct material in a piping system, what is the inspector required to do? |
Consider the need for further verification of existing piping materials. The extent of such testing will depend on consequences of failure and the probability of further material errors. |
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Who shall assess the need for and extent of application of a material verification program consistent with API 578? |
The owner / user |
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If a gate valve is suspected of being susceptible to unuasual corrosion-erosion.....where should thickness readings be taken? |
On the body of the valve between the seats.........as this is an area of high turbulence. |
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Which API code covers pressure testing of valve bodies after servicing? |
API 598 |
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Upon inspection of a piping system, preferential corrosion is found. It is decided that additional welds should be examined for corrosion. Which API code can provide additional guidance on weld inspection? |
API 577 |
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If imperfections are found in in service piping, what should the inspector do? |
The inspector should order further RT or UT and should make an effort to determine if the imperfections are from fabrication, or environmental mechanisms. |
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What are issues to consider when assessing the quality of existing welds? |
Original fabrication method and acceptance criteria, extent and magnitude of imperfections, length of time in service, operating vs. design contitions, presences of secondary piping stresses, potential for fatigue loads, and potential of environmental cracking and weld harness......among others. |
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What should flanged joints be inspected for? |
Leakage, stains, deposits, or drips. |
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What should the inspector do if he sees flanges that are significantly bent or distorted? |
He should check their markings and thicknesses against engineering requirements before taking corrective action. |
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If an audit team is conducting an audit of an inspection agency, what should they look for at a minimum? |
The code is being met, the owner/user is discharging his responsibilities, documented insp. plans are in place for piping systems, intervals and extent of inspections are sufficient, data analysis and recording is acceptable, all repairs, reratings, and alterations are in accordance with code. |
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Which API code can you reference for guidance oon RBI |
API 580 |
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If piping service conditions are changed to exceed the current operation envelope...what has to be established? |
Allowable service conditions and acceptable inspection intervals. |
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If RBI is not being used, what criteria shall be used to determine the interval between piping inspections? |
Corrosion rate, remaining life calculations, piping service classification, jurisdictional req., the judgment of the inspector, eng., materials specialist......based on operating conditions, previous inspection history, current insp. results, and conditions that may warrant supplemental insp. |
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What are types of Class 1 piping? |
Flammable services that can autorefrigerate and lead to brittle fracture, pressurized services that can rapidly vaporize during realease....creating explosive vapors, hydrogen sulfide greater than 3% weight, anhydrous hydrogen chloride, hydrofluoric acid, piping over water, flammable services operating above auto ignition temps. |
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What are types of Class 2 piping? |
Hydrocarbons that will slowly vaporize during realease, hydrogen, fuel gas, natural gas, on site strong acids and caustics. |
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What are types of Class 3 piping? |
On site hydrocarbons that will not significantly vaporize during release, distillate and product lines to and from storage and lading, tank farm piping, off site acids and caustics. |
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What are types of Class 4 piping? |
Steam and condensate, air, nitrogen, water, boiler feed water, stripped sour water, lube oil, seal oil, Cat. D fluids, plumbing and sewers. |
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What are factors that may affect the likelihood of CUI? |
Climate, insulation design and maint., coating quality, and service conditions. |
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Is inspection of auxiliary SBP req.? |
It is optional and should be determined by risk assessment. |
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What should be considered in determining if auxiliary SBP will need some form of insp.? |
Classification, potential for environmental or fatigue cracking, potential for corrosion based on experience with adjacent primary systems, potential for CUI. |
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Which API code governs the inspection, testing, and maintenance of PRD's? |
API 576 |
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Generally, inspect. intervals for PRD's should not exceed.......... |
5 years for typical service 10 years for clean, non fouling, and non corrosive service. |
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How can the inspector determine probable rate of corrosion in new piping or piping that has a change in service? |
1. Can calc. based on data from similar piping. 2. May be est. based on insp. experience, or from data on similar systems. 3. Init. thickness measurements can be made nor more than 3 months after initial service....and corrosion rate can be calculated. |
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What is the req. thickness of a pipe? |
The thickness shall be the greater of the pressure design thickness or the structural min. thickness. |
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What API code can be used for guidance to determine fitness for service? |
API 579 |
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Piping shall be supported and guided so that..... |
1. Its weight is carried safely 2. It has sufficient flexibility for thermal exp. 3. It does not vibrate excessively. |
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What are 4 types of information required in piping system and PRD records? |
1. Fab and const. info. 2. Insp. history 3. Repair, alteration, and rerating info. 4. Fitness for service docs. |
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What code should be followed to the extent practical for in service repairs? |
B31.3 or the code to which the piping system was built. |
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What API code provided guidance on welding procedures and welder performance qualifications? |
API 577 |
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What API code can provide guidance on preheat and PWHT? |
API 577 |
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When can preheat be substituted for PWHT? |
For P-1, P-3 (except Mn-Mo steels), preheat is not less than 300 deg. F., when the operating temp. will provide reasonable toughness, and when there is no risk associated with pressure testing, start up, and shutdown. Joint should be covered with ins. to slow cooling rate. |
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When can preheating not be substituted for PWHT? |
When the purpose of PWHT is to prevent environmental cracking. |
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What are acceptable alternatives to a butt weld for a closure weld? |
1. Slip on flanges up to 150#, and 500 deg. F. 2. S.W. flanges or unions for SBP up to 150# and 500 deg. F 3. SW's shall be min. 2 passes and have a gap. |
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What NDE is req. for a closure weld? |
100% RT or angle beam UT for butt weld, MT or PT on root and final for butt welds, and on final for fillet welds. |
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What criteria have to be met to rerate pipe? |
1. Calc's done by eng. 2. rerating meets code requirements. 3. insp. records indicate appropriate service conditions and corrosion rates. 4. rerated systems pressure tested to code of construction. 5. PRD's are set right. 6. rerating acceptabale to insp. or eng. 7. piping components adequate for new cond. 8. Piping flexibility ok 9. eng. records updated. 10. decrease in min. operating temp. justified by impact results............where required. |
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What is an alteration? |
A physical change
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What is a repair? |
Work necessary to make a piping system suitable for safe operation. |
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What is a defect? |
A defect is an imperfection that exceeds the acceptance criteria. |
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What is an imperfection? |
An imperfection is a discontinuity that may or may not exceed the acceptance criteria. |
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What are the two primary factors defining the use of RBI's? |
1. Probability of a failure. 2. Consequences of a failure. |
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How many CML's do you need to determine thickness of a piping system? |
Enough for a representative sample. |
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Which CML must be measured during a thickness inspection? |
The CML with the earliest renewal date as of the previous inspection. |
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How often shall PRD's be inspected and tested? |
Enough to ensure that they are performing reliably.
Performance. |
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What is the basis of API's 570 pipig classification system? |
Consequence of failure. |
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Corrosion- Method by which process leaks can lead to brittle failure. |
Auto refrigeration. |
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Corrosion- cause for fatigue crack |
Cyclic stress. |
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Corrosion- Type of soil that is most corrosive |
Low resistivity. |
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How many new flange assemblies must be inspected during repairs and alteratoions? |
Enough to be
Representative. |
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What service can cause stress corrosion cracking to develop at hot spots, including where heat tracing connects to pipe? |
Caustic |
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Where does dew point corrosion often occur? |
Overhead fractionation. |
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What services can have none or very few CML's? |
Olefin cold side, anhydrous ammonia, clean non corrosive hydrocarbons, and high alloy piping for product purity. |
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What are services that tend to have consistent and uniform corrosion and thus require fewer CML's? |
Sulfidation and sour water. |
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What is a service that would lead the inspector to check often for thermal fatigue cracking? |
Cat Reformer. |
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What code do you follow for internal insp. on pipe? |
API 510 |
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AIRR |
Alteration, Insp., repair, rerate. |
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JOC |
Repair organization authorized by:
Jurisdiction User Insurance company Contractor |
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SOPI |
Determine corrosion rate for new service or change in service......
Same or similar service. Owner's experience Published data or Inspect in three months. |
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TIE |
PRimary responsibilities of API 570 AI:
TEsting Inspection Examination |
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What is the mill tolerance for rolled and welded pipe? |
-0.010" |
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What is the profile on a typical flange face finish? |
125-250 micro-inches |
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What is the max offset for bolt holes for mating flanges? |
1/8" |
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How far from the toe of the weld must the preheat zone reach? |
1" |
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How far from the toe of the weld must be PWHT? |
1" |
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What is the min. radius of an insert patch? |
1" |
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What is the max dia. of CML exam points for lines less than 10" NPS? |
2" |
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What is the max dia. of CML exam points for lines more than 10" NPS? |
3" |
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What is the min. length of RT/UY when qualifying a welder with a test coupon or 1st production weld? |
6" |
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How far up should you inspect when looking for corrosion at a soil to air interface? |
6" |
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How far down should you dig when looking for corrosion at a soil to air interface? |
6-12" |
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What is the min. length of buried pipe to expose when excavating for insp.? |
6-8' |
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What is the ma. size of a fillet weld patch on a pipe? |
1/2 dia. |
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At what temp. range does CUI affect CS and low alloy steel? |
10-350 deg. F |
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At what temp. range does CUI affect austenitic stainless steel? |
120-400 deg. F. |
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At what temp does chloride stress corrosion cracking become a concern? |
More than 140 deg. F. |
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At what temp. do you need special procedures for doing UT's? |
Greater than 150 deg. F |
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What is the min. preheat temp. when preheat is substituted for PWHT? |
300 deg. F |
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According to API 574, what is the starting temp. for sulfidation on CS? |
450 deg. F. |
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According to API 571, what is the starting temp for sulfidation on iron based alloys? |
500 deg. F. |
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What temp. range can cause temper embrittlement in low chromes? |
650-1100 deg. F. |
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At what temp. can graphitization occur in CS? |
800 deg. F. |
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At what temp. can creep occur in 1-1/4 CR material? |
More than 900 deg. F. |
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What is min. metal temp. during pressure testing when wall thickness is less than 2" thick? |
MDMT + 10 deg. F. |
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What is min. metal temp. during pressure testing when wall thickness is more than 2" thick? |
MDMT + 30 deg. F. |
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What is the max temp. for MT |
Manufacturer recommended. |
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What damage mechanisms can cause metal loss? |
Sulfidation, oxidation, mirobiological corrosion, organic acid corrosion, erosion, galvanic corrosion, CUI |
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What damage mechanism can cause surface connected cracking? |
Fatigue, caustic stress corrosion cracking, sulfide stress cracking, chloride stress corrosion cracking, polythionic acid stress corrosion cracking, other forms of environmental cracking. |
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What damage mechanism can cause subsurface cracking? |
Hydrogen induced cracking. |
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What damage mechanism can cause Microfissuring formation? |
High temp. hydrogen attack creep. |
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What damage mechanism can cause Metallurgical changes? |
Graphitization, temper embrittlement.
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What damage mechanism can cause blistering? |
Hydrogen blistering. |
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What damage mechanism can cause dimensional changes? |
Creep and stress rupture thermal. |
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What damage mechanism can cause Material properties changes? |
Brittle fracture. |
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During a piping repair, if there is a conflict between the requirements of the API 570 and the construction code, which should be followed? |
API 570 |
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During a piping alteration, if there is a conflict between the requirements of the API 570 and the construction code, which should be followed? |
API 570 |
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An in service pipe is being repaired or altered. If there is a conflict between the requirements of API 570 and the legal jurisdiction, which should be followed? |
The most stringent requirements. |
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During an in service internal insp., a crack is discovered on a longitudinal weld. This crack can be evaluated to which code? |
API 579 |
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Which code provides requirements for hot tapping? |
API 578 |
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Which publication provides information on corrosion mechanisms? |
API 571 |
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Which recommended practice is used for guidance in inspecting and testing valves? |
API 598 |
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Which document can be used when determining soil resistivity? |
ASTM G57 |
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Which document can provide more information on Injection and Mixing points? |
NACE Pub 34101 |
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What is max. diameter of an examination point on a 12 NPS line? |
3" |
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An indication is: |
A response from an NDE examination. |
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Which of the following insp. organizations is not considered an acceptable API 570 Repair Organization? |
The governing jurisdiction based on the location of the piping system. |
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Secondary process piping is defined as pipe that is: |
Downstream of normally closed block valves. |
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Thje soil to air zone is considered to be: |
6" above the interface and 12" below the interface. |
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Which of the following is not a role for the API 570 Insp.? |
Proved the Owner assurance that all welding meet requirements. |
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All in service piping in the petrochemical industry must: |
Have an insp. plan. |
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The insp. plan for a piping system should be developed by: |
Either the insp. or the engineer. |
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Whose input is required when developing an insp. plan for piping that operates at an elevated temp? |
Corrosion specialist. |
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A corrosion specialist should be consulted when developing insp. plans for piping that operates above: |
750 deg. F |
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All NDE equipment sued in petrochemical facilities must: |
Have a safety rating appropriate for the gaseous environment at the exam site. |
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If a pipe is large enough for an internal insp. The internal insp. should meet the requirements of: |
API 510 |
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The number of CML's on a piping system are being substantially reduced? Who should be consulted? |
Person knowledgeable in corrosion. |
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A pressure test cannot be pfrformed using water due to potential contamination of the process. A flammable liquid will be used in lieu of water. The flash point of the test medium must be at least: |
120 deg. F |
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A hydrotest will be performed on SS piping that is subject to polythionic stress corrosoion cracking. What type of test fluid should be considered for the hydro? |
Alkaline water solution. |
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Per API 570, during repairs and alteration, the insp. shall verify that the new materials being used are correct. What is the min. amount of verification that the insp. shall perform? |
A sampling of all alloys used to maintain pressure containment. |
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A 9% Cr. piping system failed. It is determined that 2-1/4 Cr. was accidentally installed. Who determines how much additional material verification is needed? |
The Authorized Inspector. |
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A flanged joint that was clamped and pumped with leak sealant is found to be leaking. What should be done prior to repumping the flanged joint assembly? |
Replace all of the flanged joint bolting before repumping. |
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Off site hydrogen is what class of service? |
Class 2 piping. |
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When thickness measurements are conducted, each thickness measurement set should include: |
CML's on each type of component, like ells, tees. |
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What is the max interval for the external insp. of a Class 1 piping system? |
5 years. |
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What is the max interval for thickness measurements on a Class 1 piping system? |
Lesser of 1/2 life or 5 years. |
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What is the max interval for the external insp. of a Class 2 piping system? |
5 years. |
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What is the max. interval for thickness measurements on a Class 2 piping system? |
Lesser of 1/2 life or 10 years. |
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A Class 3 piping system has some damaged ins. How many of the damaged areas should be insp.? |
25% |
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A Class 1 piping system is being insp. for CUI. How many of the suspect areas should be insp.? |
50% |
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A Class 3 piping system is being insp. for CUI. How many of the suspect areas should be insp.? |
10% |
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What is the recommended extent of CUI insp. at suspect locations on Class 2 piping systems? |
33% |
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What code should be used to evaluate localized thin areas on an existing piping system? |
API 579 |
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An old pipng system has significant corrosion and is being replaced. This activity must be authorized by the: |
Authorized Insp. |
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Prior to a piping system repair, all proposed NDE and testing must be approved by the: |
Authorized insp. or the pipng eng. |
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A deep corroded area is found on a pipe system. A temp. repair may be made by fillet welding a split sleeve as long as the specified min. yield strength of the pipe is: |
Less than or equal to 40,000 psi. |
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Who can authorize exceptions to code specified postweld heat treatment requirements on temp. repairs? |
The piping eng. |
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What at the 9 sections of API 570? |
1. Scope 2. Normative References 3. Definitions 4. Owner/User 5. Insp., Examination, and Pressure Testing. 6.Interval Frequency and Extent of Insp. 7. Data Evauation, Analysis, Recording 8. Repairs, Alterations, Reratings 9. Insp. of Buried Piping.
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How should the boundary of a piping circuit be sized? |
To provide for accurate record keeping and Insp. |
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What type of corrosion might be suspected in Amine service? |
SCC
Stress Corrosion Cracking |
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What are three methods to test soil resistivity? |
1. Wenner 4-pin
2. Soil Bar
3. Soil Box |
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What should be checked for if you find a hot spot? |
1. Oxidation
2. Scaling
3. Creep |
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What are three ways to measure pipe thickness if you have access to the inside of the pipe? |
1. Caliper
2. RT
3. UT |
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What is SMTS? |
Specified Min. Tensile Strength |
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What area is of the most concern when insp. a piping system? |
At and/or downstream of an inj. point. |
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UT instruments that are not equipped with High Temp. material can be damaged at temps over what? |
1000 deg F. |
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Reduction of strength of the metal in a pipe, scaling, bulging, metal deterioration or complete failure are all symptoms of: |
Excessive temp. |
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When making a visual insp. of a piping system, and fouling is found, what should the insp. do? |
Clean the line.........and check the deposits to determine their origin. |
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Bodies of valves that operate in severe cyclic temp. service should be checked internally for: |
Cracks |
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Why is the area between the seats of a gate valve a weak location? |
The wedging action of the disk when it seats can cause strain. |
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What should be done after a valve is insp, repaired, and reassembled? |
It should be tested to API 598. |
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A weld is being made in CS piping carrying Amine (MEA). What should the insp. check for? |
Environmental cracking.....the weld should be checked for hardness.
Amine=SCC=check for hardness of weld.
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How can you check a pipie that has had hot spots for creep or deformation? |
Measure the OD of the pipe and compare it to est. data for life. |
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What discontinuity is never acceptable when fabricating a normal service piping system? |
Lack of Fusion |
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What is the max insp. interval for a relief valve in normal service? |
5 years |
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UT readings are generally accurate above what dia. of pipe? |
1 NPS |
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What material is most susceptible to polythionic cracking? |
SS |
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The code covering insp. and testing of valves is: |
API 578 |
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Which code can be used to evaluate an in service crack? |
API 579 |
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A propane system should be classified as Class: |
1 |
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During pipe fabrication, who has overall responsibility for compliance with the Code? |
Owner/User |
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When calibrating a UT instrument, that has a delay line with a single element search unit, use: |
At least two test blocks with thicknesses near the max and min to be examined. |
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Thickness measurements on Injection Points should be conducted at least every: |
3 years |
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What is the min. # or RT exposures tequired to RT a new 2 NPS weld? |
2 |
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Insulated austenitic stainless steel pipe is susceptible to CUI (chloride stress corrosion cracking) at: |
120-400 deg. F |
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The min and max density range in the area of interest on a radiograph using a gamma ray source is: |
2.0-4.0 |
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According to API 570, sho should conduct the external inspection? |
The Authorized Inspector or qualified operation or maintenance personnel. |
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What NDE technique is useful for finding plugging in piping? |
RT |
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Marking pens used to mark piping components should not contain: |
Sulfur |
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Which type of valve creates the most turbulence in fluid flow? |
Globe |
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What is the hardness limits for pipe made from 9%CR-1% Mo? |
241 BNH |
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Which Code may be used to evaluate locally thinned pipe? |
API 598 |
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When can welded temp repairs on pipe remain past the next maintenance opportunity? |
Only if approved and documented by the engineer. |
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How often should the external insp. on a Class 2 line be conducted? |
Every 5 years. |
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Per API 578, How many more PMI samples should be taken after incorrect material is found? |
100% of the items from the insp. lot. |
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How may pipe welds are required to be radiographed per API 570? |
Zero |
