API 570 Flashcards

Question 1

Q

What is the ratio of endurance limit stress to ultimate tensile stress for carbon steel?

Answer

A

API 571 (4.2.16.3.b.ii) - 
b) Metallurgical Issues and Microstructure

1) For some materials such as titanium, carbon steel and low alloy steel, the number of cycles to fatigue fracture decreases with stress amplitude until an endurance limit reached. Below this stress endurance limit, fatigue cracking will not occur, regardless of the number of cycles.
2) For alloys with endurance limits, there is a correlation between Ultimate Tensile Strength (UTS) and the minimum stress amplitude necessary to initiate fatigue cracking. The ratio of endurance limit over UTS is typically between 0.4 and 0.5. Materials like austenitic stainless steels and aluminum that do not have an endurance limit will have a fatigue limit defined by the number of cycles at a given stress amplitude.

Question 2

Q

Flanges - What is the threaded engagement acceptance criteria?

Answer

A

API 570 (5.1.2) - Flange fasteners should be examined visually for corrosion and thread engagement. Fasteners should be fully engaged. Any fastener failing to do so is considered acceptably engaged if the lack of complete engagement is not more than one thread.

The markings on a representative sample of newly installed fasteners and gaskets should be examined to determine whether they meet the material specification. The markings are identified in the applicable ASME and ASTM standards.Questionable fasteners should be verified or renewed.
Additional guidance on the inspection of flanged joints can be found in ASME PCC-1 [13].

ASME B31.3 (335.2.3) - Bolt Length. Bolts should extend com- pletely through their nuts. Any which fail to do so are considered acceptably engaged if the lack of complete engagement is not more than one thread.

Question 3

Q

Testing - What is the minimum range of pressure gauge used during a pressure test (multiplied by test pressure)?

Answer

A

ASME Sec. V (T-1031.a) -

(a) Gage Range.

When dial indicating and recording pressure gage(s) are used in leak testing, they should preferably have the dial(s) graduated over a range of approximately double the intended maximum pressure, BUT IN NO CASE SHALL THE RANGE BE LESS THAN 1 1/2, nor more than four times that pressure.

Question 4

Q

Testing - What is the preferred range of pressure gauge used during a pressure test (multiplied by test pressure)?

Answer

A

ASME Sec. V (T-1031.a) -

(a) Gage Range.

When dial indicating and recording pressure gage(s) are used in leak testing, THEY SHOULD PREFERABLY HAVE THE DIAL(S) GRADUATED OVER A RANGE APPROXIMATELY DOUBLE THE INTENDED MAXIMUM PRESSURE, but in no case shall the range be less than 1 1/3nor more than four times that pressure.

Question 5

Q

NDE - What is the # of additional welds or joints to examine when a defect is found during a random examination?

Answer

A

Sec B31.3 (341.3.4.a) -

Progressive Sampling for Examination.

When required spot or random examination reveals a defect, then

(a) two additional samples of the same kind (if welded or bonded joints, by the same welder, bonder, or operator) from the original designated lot shall be given the same type of examination

Question 6

Q

PWHT - What are the minimum # of thermocouples required when performing a local PWHT instead of a 360 degree band?

Answer

A

API 570 (8.2.3.3.d) -

Post Weld Heat Treat

d) The required PWHT temperature shall be maintained for a distance of not less than two times the base metal thickness measured from the weld. The PWHT temperature shall be monitored by a suitable number of thermocouples (a minimum of two) based on the size and shape of the area being heat treated.

Question 7

Q

Weld Qualification - What are the number of tension tests needed to qualify a WPS?

Answer

A

API Sec. IX (QW451.1) -

2

Question 8

Q

Weld Question - What are the # of bend tests needed to qualify a welder or welding operator in welding positions 1G-4G?

Answer

A

API Sec IX (QW452.1.a) - ???

Question 9

Q

NDE - What are the minimum # of exposures to RT 360 degrees of a weld during a double-wall technique, double-wall view (elliptical shot)?

Answer

A

ASME Sec. V (T-271.2.b.1)
DOUBLE-WALL TECHNIQUE
(b) Double-Wall Viewing

(1) For welds, the radiation beam may be offset from the plane of the weld at an angle sufficient to separate the images of the source-side and film-side portions of the weld so that there is no overlap of the areas to be interpreted. When complete coverage is required, A MINIMUM OF TWO EXPOSURES taken 90 deg to each other shall be made for each joint.

Question 10

Q

NDE - What is the RT film density range allowed for the weld and IQI when using a gamma ray source?

Answer

A

ASME Sec. V (T-282) - Radiographic Density
T-282.1 Density Limitations.

The transmitted film density through the radiographic image of the body of the designated hole-type IQI adjacent to the essential hole or adjacent to the essential wire of a wire-type IQI and the area of interest shall be 1.8 minimum for single film viewing for radiographs made with an X-ray source and 2.0 MINIMUM for radiographs made with a gamma ray source.

Question 11

Q

NDE - What is the minimum # of exposures to RT 360 degrees of a weld using a double-wall technique, single-wall view?

Answer

A

ASME Sec. V (T-271.2.a) - Double-Wall Technique
(a) Single-Wall Viewing.

For materials and for welds in components, a technique may be used in which the radiation passes through two walls and only the weld (mate- rial) on the film-side wall is viewed for acceptance on the radiograph. When complete coverage is required for circumferential welds (materials), a MINIMUM OF THREE EXPOSURES taken 120 deg to each other shall be made.

Question 12

Q

Impact Test - What are the number of bars in each set?

Answer

A

ASME B31.3 (323.3.3) Test Specimens

Each set of impact test specimens shall consist of THREE SPECIMEN BARS. All impact tests shall be made using standard 10 mm (0.394 in.) square cross section Charpy V-notch specimen bars, except when the material shape or thickness does not permit.

Question 13

Q

NDE - When using a shim under a hole-type IQI, what number of sides of the IQI must be seen in the RT image?

Answer

A

ASME Sec. V (T-277.3) - Shims Under Hole-Type IQI

The shim dimensions shall exceed the IQI dimensions such that the outline of AT LEAST THREE SIDES of the IQI image shall be visible in the radiograph.

Question 14

Q

Leak Testing - What the maximum range of pressure gauge used during a pressure test (multiplied by test pressure)?

Answer

A

ASME Sec. V (T-1030) - Equipment
(T-1031.a) Gauges -

When dial indicating and recording pressure gage(s) are used in leak testing, they should preferably have the dial(s) graduated over a range of approximately double the INTENDED MAXIMUM PRESSURE, but in NO CASE shall the range be less than 1 1/2 nor MORE THAN FOUR TIMES THAT PRESSURE.

Question 15

Q

Weld Qualification - What is the number of bend tests needed to qualify a WPS?

Answer

A

ASME Sec. IX (QW 451.1) -

4

Question 16

Q

Weld Qualification - What is the # of bend tests needed to qualify a welder or welding operator in welding positions 5G and 6G?

Answer

A

ASME Sec. IX (QW452) Performance Qualification Thickness Limits and Test Specimens
(QW452.1) Groove-Weld Tests
(QW452.1 (a) Test Specimens
Note (1)
To qualify using positions 5G or 6G, a TOTAL OF FOUR bend specimens are required. To qualify using a combination of 2G and 5G in a single test coupon, a total of six bend specimens are required. See
QW-302.3. The type of bend test shall be based on weld metal thickness.

Question 17

Q

Design - What is the # of Stress Cycles needed to become rated as a Sever Cyclic Service?

Answer

A

ASME B31.3 (300.2) - Definitions

Severe Cyclic Conditions: conditions applying to specific piping components or joints in which SE computed in accordance with para. 319.4.4 exceeds 0.8SA (as defined in para. 302.3.5), and the equivalent NUMBER OF CYCLES NEEDED (N in para. 302.3.5) EXCEEDS 7000; or other conditions that the designer determines will produce an equivalent effect.

Question 18

Q

API 570

What code is followed when performing an internal inspection of pipe?

Answer

A

API 570 (5.5.1) - Internal Visual Inspection

When possible and practical, internal visual inspections may be scheduled for systems such as large-diameter transfer lines, ducts, catalyst lines, or other large- diameter piping systems. Such inspections are similar in nature to pressure vessel inspections and should be conducted with methods and procedures similar to those outlined in API 510 and API 574.

API 510 -

API 574 -

Question 19

Q

API 570

Where can I find specific inspection detail on Positive Material Identification (PMI)?

Answer

A

API 570 (5.9) - Material Verification and Traceability

During repairs or alterations to alloy material piping systems, where the alloy material is required to maintain pressure containment, the inspector shall verify that the installation of new materials is consistent with the selected or specified construction materials.This material verification program should be consistent with API 578.Components identified during this verification that do not meet acceptance criteria of the PMI testing program (such as in API 578, Section 6) would be targeted for replacement.

API 578 (Section 6) - Evaluation of PMI Test Results

Question 20

Q

API 570

Where can I find specific inspection detail on Fitness for Service (FFS)?

Answer

A

API 570 (7.4) - Assessment of Inspection Findings

Pressure containing components found to have degradation that could affect their load carrying capability [pressure loads and other applicable loads (e.g. weight, wind, etc., per API 579-1/ASME FFS-1)] shall be evaluated for continued service. Fitness-For-Service techniques, such as those documented in API 579-1/ASME FFS-1, Second Edition, may be used for this evaluation. The Fitness-For-Service techniques used shall be applicable to the specific degradation observed.

API 579-1 -

ASME FFS-1 -

Question 21

Q

API 570

Where can I find specific inspection detail on Risk Based Inspection (RBI)?

Answer

A

API 570 (5.2) - RBI

RBI can be used to determine inspection intervals and the type and extent of future inspection/examinations.

API 580 -

Question 22

Q

API 570

Where can I find specific inspection detail on Valve Inspection and Testing?

Answer

A

API 570 (5.10) - Inspection of Valves

When valve body and/or closure pressure tests are performed after servicing, they should be conducted in accordance with API 598

API 598 - Valve Inspection and Testing

Question 23

Q

API 570

Where can I find specific inspection detail on Cathodic Protection?

Answer

A

API 570 (9.3.5) - Cathodic Protection

If the piping is cathodically protected, the system should be monitored at intervals in accordance with Section 10 of NACE RP0169 or API 651.

API 651 -

Question 24

Q

API 570

Where can I find information about Welding on
In-Service Equipment Containing Flammables?

Answer

A

API 570 (8.2) - Welding and Hot Tapping
             (8.2.1) - General 
Any welding conducted on piping components in operation shall be done in accordance with API 2201. The inspector shall use as a minimum the “Suggested Hot Tap Checklist” contained in API 2201 for hot tapping performed on piping components. See API 577 for further guidance on hot tapping and welding in-service.

API 2201 -

Question 25

Q

ASME B31.3

Where can I find information on the NDE Procedure Guidelines?

Answer

A

ASME B31.3 (Chapter 6 Sec. 343)

EXAMINATION PROCEDURES

ASME Sec.V (Art.1 T-150)

Question 26

Q

ASME B31.3

Where can I find the Design Code for Fabrication of Piping Relief Devices?

Answer

A

ASME B31.3 (322) Specific Piping Systems

(322. 6) Pressure Relieving Systems
(322. 6.3) Pressure Relieving Devices
(a) Pressure relieving devices required by para. 301.2.2(a) shall be in accordance with the BPV Code, Section VIII, Division 1, UG-125(c), UG-126, UG-127, and UG-132 through UG-136, excluding UG-135(e) and UG-136(c).

ASME Sec.Vlll

Question 27

Q

ASME B31.3

Where can I find the Welder and Weld Procedure Qualifications (WPQs)?

Answer

A

ASME B31.3
(328.2) Welding and Brazing Qualifications
(328.2.2) Procedure Qualification by Others.
In order to avoid duplication of effort and subject to the approval of the owner, WPSs and BPSs qualified by a technically competent group or agency may be used provided the following are met:
(a) The procedures meet the requirements of Sec- tion IX and any additional qualification requirements of this Code.

ASME Sec.lX

Question 28

Q

ASME B31.3

Where can I find the NDE Personnel Qualifications?

Answer

A

ASME 31.3 (342) EXAMINATION PERSONNEL
(342.1) Personnel Qualification and Certification
Examiners shall have training and experience com- mensurate with the needs of the specified examinations.1
(342.1-Note)
1 For this purpose, SNT-TC-1A, Recommended Practice for Nondestructive Testing Personnel Qualification and Certification, may be used as a guide.
ASNT SNT-TC-1A

Question 29

Q

API 570

What is the Scope of the API 570?

Answer

A

API 570 (1.1.1)

AIRR (Alterations, Inspections, Repairs, Rerates)

API 570 covers inspection, rating, repair, and alteration procedures for metallic and fiberglass reinforced plastic (FRP) piping systems and their associated pressure relieving devices that have been placed inservice.

Question 30

Q

API 570

What is the means of the API 570 Repair Organization?

Answer

A

API 570 (3.1.79)
JOC (authorized by Jurisdiction, Owner, and Contractor)

ANY OF THE FOLLOWING…

A) An owner or user of piping systems who repairs or alters his or her own equipment in accordance with API570.

B) A contractor whose qualifications are acceptable to the owner or user of piping systems and who makes repairs or alterations in accordance with API 570.

C) One who is authorized by, acceptable to, or otherwise not prohibited by the jurisdiction and who makes repairs in accordance with API 570.

Question 31

Q

API 570

Who is the API 510 AI’s (Authorized Inspection Agency) Employer?

Answer

A

API 570 (3.1.6)
JUIC (Jurisdiction, User, Insurance Company, Contractor)

A) The inspection organization of the jurisdiction in which the piping system is used.

B) The inspection organization of an insurance company that is licensed or registered to write insurance for piping systems.

C) An owner or user of piping systems who maintains an inspection organization for activities relating only to his equipment and not for piping systems intended for sale or resale.

D) An independent inspection organization employed by or under contract to the owner or user of piping systems that are used only by the owner or user and not for sale or resale.

E) An independent inspection organization licensed or recognized by the jurisdiction in which the piping system is used and employed by or under contract to the owner or user.

Question 32

Q

API 570

How do you Determine the Corrosion Rate for New Service or Change the Corrosion Rate for In Service Piping?

Answer

A

API 570 (7.1.2) Newly Installed Piping Systems or Changes in Service

SOPI (Same or Similar Service, Owners Experience, Published Data, or Inspect in 3 Months)

For new piping systems and piping systems for which service conditions are being changed, one of the following methods shall be employed to determine the probable rate of corrosion from which the remaining wall thickness at the time of the next inspection can be estimated.

A) A corrosion rate for a piping circuit may be calculated from data collected by the owner/user on piping systems of similar material in comparable service and comparable operating conditions.

B) If data for the same or similar service are not available, a corrosion rate for a piping circuit may be estimated from the owner/user’s experience or from published data on piping systems in comparable service.

C) If the probable corrosion rate cannot be determined by either method listed in
Item a) or Item b), the initial thickness measurement determinations shall be made after no more than three months of service by using nondestructive thickness measurements of the piping system. Corrosion monitoring devices, such as corrosion coupons or corrosion probes, may be useful in establishing the timing of these thickness measurements. Subsequent measurements shall be made after appropriate intervals until the corrosion rate is established.

Question 33

Q

API 570

What are the primary responsibilities of the API 510 AI (Authorized Inspection Agency)?

Answer

A

API 570 (4.3.4) Authorized Piping Inspector

TIE (Testing, Inspection, Examination)

When inspections, repairs, or alterations are being conducted on piping systems, an authorized piping inspector shall be responsible to the owner/user for determining that the requirements of API 570 on inspection, examination, quality assurance and testing are met. The inspector shall be directly involved in the inspection activities which in most cases will require field activities to ensure that procedures are followed. The inspector is also responsible for extending the scope of the inspection (with appropriate consultation with engineers/specialists), where justified depending upon the findings of the inspection. Where nonconformances are discovered, the inspector is responsible for notifying the owner-user in a timely manner and making appropriate repair or other mitigative recommendations.

The authorized piping inspector may be assisted in performing visual inspections by other properly trained and qualified individuals, who may or may not be certified piping inspectors (e.g. examiners and operating personnel). Personnel performing NDEs shall meet the qualifications identified in 4.3.5, but need not be authorized piping inspectors. However, all examination results shall be evaluated and accepted by the authorized piping inspector.

Question 34

Q

API 570

Define ALTERATION

Answer

A

API 570 (3.1.2)

A PHYSICAL CHANGE in any component that has design implications affecting the pressure containing capability or flexibility of a piping system beyond the scope of its original design. The following are not considered alterations: comparable or duplicate replacements and the addition of small-bore attachments that do not require reinforcement or additional support.

Question 35

Q

API 570

Define REPAIR

Answer

A

API 570 (3.1.78)

The work necessary to RESTORE a PIPING SYSTEM to a CONDITION SUITABLE for SAFE OPERATION at the DESIGN CONDITIONS. If any of the restorative changes result in a change of design temperature or pressure, the requirements for re-rating also shall be satisfied. Any welding, cutting, or grinding operation on a pressure-containing piping component not specifically considered an alteration is considered a repair.

Question 36

Q

API 570

Define DEFECT

Answer

A

API 570 (3.1.17)

An imperfection of a type or magnitude exceeding the acceptable criteria.

Question 37

Q

API 570

Define IMPERFECTION

Answer

A

API 570 (3.1.30)

Flaws or other discontinuities noted during inspection that may be subject to acceptance criteria during an engineering and inspection analysis.

Question 38

Q

API 570

What are RBI’s two Primary Factors?

Answer

A

API 570 (5.2) RBI

5.2.1 Probability Assessment
and
5.2.2 Consequence Assessment

Question 39

Q

API 570

Number of CMLs to obtain Thickness Readings of during inspection (NDE)?

Answer

A

API 570 (6.5) Extent of Thickness Measurement Inspection

To satisfy inspection interval requirements, each thickness measurement inspection should obtain thickness readings on a representative sampling of CMLs on each circuit (see 5.6). This representative sampling should include data for all the various types of components and orientations (horizontal and vertical) found in each circuit.

Question 40

Q

API 570

CML that must be measured during a Thickness Inspection (NDE)?

Answer

A

API 570 (6.5) Extent of Thickness Measurement Inspection

This sampling also shall include CMLs with the earliest renewal date as of the previous inspection.

Question 41

Q

API 570

How are Pressure Relief Device intervals determined (PRD’s)?

Answer

A

API 570 (6.7) Inspection and Maintenance of Pressure-relieving Devices (PRDs)
(6.7.3) PRD Testing and Inspection Intervals
(6.7.3.1) General
[PERFORMANCE] Pressure-relieving devices shall be tested and inspected at intervals that are frequent enough to verify that the valves perform reliably in the particular service conditions. Other pressure-relieving devices (e.g. rupture disks and vacuum- breaker valves) shall be inspected at intervals based on service conditions. The inspection interval for all pressure- relieving devices is determined by either the inspector, engineer, or other qualified individual per the owner/user’s quality assurance system.

Question 42

Q

API 570

What is the Basis of an API 570s Piping Classification (Inspection)?

Answer

A

API 570 (6.3) Piping Inspection Planning
(6.3.1) General
[CONSEQUENCE of FAILURE] The frequency and extent of inspection on piping circuits whether above or below ground depend on the forms of degradation that can affect the piping and consequence of a piping failure. The various forms of degradation that can affect process piping circuits are described in Table 1 and API 571 in more detail. A simplified classification of piping based on the consequence of failure is defined in 6.3.4. As described in 5.1, inspection strategy based on probability and consequence of failure is referred to as RBI.

Question 43

Q

API 570

Method by which Process Leaks can lead to Brittle Failure (Corrosion)?

Answer

A

API 570 (6.3) Piping Inspection Planning
(6.3.4) Piping Service Classes
(6.3.4.2) Class 1
Services with the highest potential of resulting in an immediate emergency if a leak were to occur are in Class 1. Such an emergency may be safety or environmental in nature.
(6.3.4.2.a)
[AUTO-REFRIGERATION]
Flammable services that can auto-refrigerate and lead to brittle fracture

Question 44

Q

API 574

What is the Cause for a Fatigue Crack (Corrosion)?

Answer

A

API 574 (7.4) Inspection for Specific Damage Mechanisms
(7.4.10) Fatigue Cracking
(7.4.10.1) [CYCLIC STRESS] Fatigue cracking of piping systems can result from excessive cyclic stresses that are often well below the static yield strength of the material. The cyclic stresses can be imposed by pressure, mechanical, or thermal means and can result in low-cycle or high-cycle fatigue.

Question 45

Q

API 574

What are the factors that affect the Creep Rate (Corrosion)?

Answer

A

API 574 (7.4) Inspection for Specific Damage Mechanisms

(7. 4.11) Creep Cracking
(7. 4.11.1) [TIME, TEMPERATURE, and STRESS] Creep is dependent on time, temperature, and stress. Creep cracking can eventually occur at design conditions since some piping code allowable stresses are in the creep range. Cracking is accelerated by creep/ fatigue interaction when operating conditions in the creep range are cyclic. Particular attention should be given to areas of high stress concentration.

Question 46

Q

API 570

Type of Soil that is Most Corrosive (Corrosion)?

Answer

A

API 570 (9) Inspection of Buried Piping

(9. 2) Types and Methods of Inspection
(9. 2.4) Soil Resistivity [LOW RESISTIVITY] Corrosion of bare or poorly coated piping is often caused by a mixture of different soils in contact with the pipe surface. The corrosiveness of the soils can be determined by a measurement of the soil resistivity. Lower levels of resistivity are relatively more corrosive than higher levels, especially in areas where the pipe is exposed to significant changes in soil resistivity.

Question 47

Q

API 570

What is the # of New Flange Assemblies to be Inspected During Repairs and Alterations (Repairs)?

Answer

A

API 570 (5.12) Inspection of Flanged Joints
[REPRESENT-ATIVE] The markings on a representative sample of newly installed fasteners and gaskets should be examined to determine whether they meet the material specification. The markings are identified in the applicable ASME and ASTM standards. Questionable fasteners should be verified or renewed.
Additional guidance on the inspection of flanged joints can be found in ASME PCC-1 [13].

Question 48

Q

API 574

SCC (Corrosion) can develop at Hot Spots, including where the Heat Tracing attaches to the pipe (Services).

Answer

A

API 574 (7.4) Inspection for Specific Damage Mechanisms

(7. 4.6) Service-specific and Localized Corrosion
(7. 4.6.2) There are many types of internal corrosion possible from the process service. These types of corrosion are usually localized, and are specific to the service. Examples of where this type of corrosion might be expected include:
(7.4.6.2.n) (CAUSTIC) “Hotspot” corrosion on piping with external heat tracing;
NOTE In services which become much more corrosive to the piping with increased temperature (e.g. sour water, caustic in carbon steel), corrosion or SCC can develop at hot spots that develop under low flow conditions.

Question 49

Q

API 574

Where does dew point corrosion often occur (Service)?

Answer

A

API 574 (7.4) Inspection for Specific Damage Mechanisms

(7. 4.6) Service-specific and Localized Corrosion
(7. 4.6.2) There are many types of internal corrosion possible from the process service. These types of corrosion are usually localized, and are specific to the service. Examples of where this type of corrosion might be expected include:
(7.4.6.2.b) (OVERHEAD FRACTIONATION) dew-point corrosion in condensing streams (e.g.overhead fractionation)

Question 50

Q

API 570

What Service has the Potential for none or very few CMLs on circuit (Service)?

Answer

A

API 570 (5.6) CMLs
(5.6.2) CML Monitoring
(OLEFIN COLD SIDE and ANHYDROUS AMMONIA)
Each piping system shall be monitored at CMLs. Piping circuits with high potential consequences of failure should occur and those subject to higher corrosion rates or localized corrosion will normally have more CMLs and be monitored more frequently. CMLs should be distributed appropriately throughout each piping circuit. CMLs may be eliminated or the number reduced under certain circumstances, such as olefin plant cold side piping, anhydrous ammonia piping, clean noncorrosive hydrocarbon product, or high-alloy piping for product purity. In circumstances where CMLs will be substantially reduced or eliminated, persons knowledgeable in corrosion should be consulted.

Question 51

Q

API 570

Process causing relatively uniform corrosion (Service)?

Answer

A

API 570 (5.6) CMLs
(5.6.3) CML Selection
SULFIDATION and SOUR WATER
A number of corrosion processes common to refining and petrochemical units are relatively uniform in nature, resulting in a fairly constant rate of pipe wall reduction independent of location within the piping circuit, either axially or circumferentially. Examples of such corrosion phenomena include high-temperature sulfur corrosion and sour water corrosion (provided velocities are not so high as to cause local corrosion/erosion of elbows, tees, and other similar items). In these situations, the number of CMLs required to monitor a circuit will be fewer than those required to monitor circuits subject to more localized metal loss.

Question 52

Q

API 570

Valves that should be inspected for thermal fatigue (Service)?

Answer

A

API 570 (5) Inspection, Examination, and Pressure Testing Practices
(5.10) Inspection of Valves
CAT REFORMER Normally, thickness measurements are not routinely taken on valves in piping circuits. The body of a valve is normally thicker than other piping components for design reasons. However, when valves are dismantled for servicing and repair, the shop personnel should visually examine the valve components for any unusual corrosion patterns or thinning and, when noted, report that information to the inspector. Bodies of valves that are exposed to significant temperature cycling (for example, catalytic reforming unit regeneration and steam cleaning) should be examined periodically for thermal fatigue cracking.
If gate valves are known to be or are suspected of being exposed to severe or unusual corrosion-erosion, thickness readings should be conducted on the body between the seats, since this is an area of high turbulence and high stress.

Question 53

Q

API 574

What are the Mill Tolerances for Rolled and Welded Pipe (Design)?

Answer

A

API 574 (4) Piping Components

(4. 1) Piping
(4. 1.1) General
(4. 1.1.3)
- 0.010” Allowable tolerances in pipe diameter differ from one piping material to another. Table 3 lists the acceptable tolerances for diameter and thickness of most ASTM ferritic pipe standards. The actual thickness of seamless piping can vary from its nominal thickness by a manufacturing tolerance of as much as 12.5 %. The under tolerance for welded piping is 0.01 in. (0.25 mm).

Question 54

Q

ASME B31.3

What is the Maximum Length of a Crack, or Incomplete Fusion Allowed on a New Weld (NDE)?

Answer

A

ASME B31.3
(Table 341.3.2) Acceptance Criteria for Welds and Examination Methods for Evaluating Weld Imperfections (Cont’d)

Zero (no evident imperfection)

Question 55

Q

ASME 16.5

What is the Typical Flange Face Finish in Micro-Inches (Flanges)?

Answer

A

ASME 16.5 (6) DIMENSIONS
(6.4) Flange Facings
(6.4.5) Flange Facing Finish Flange facing finishes shall be in accordance with paras. 6.4.5.1 through 6.4.5.3, except that other finishes may be furnished by agreement between the user and the manufacturer.
(6.4.5.3) Other Flange Facings 125-250 Micro-Inches
Either a serrated concentric or serrated spiral finish having a resultant surface finish from 3.2 micro-m to 6.3 micro-m (125 micro-in. to 250 micro-in.) average roughness shall be furnished.

Question 56

Q

ASME B31.3

When Mating Flanges, what is the Maximum Amount of Unparalleled Allowed (per Diameter of Flange in Feet) (Flanges)?

Answer

A

ASME B31.3 (335) ASSEMBLY AND ERECTION
(335.1) Alignment
(335.1.c)
1/16" Per Foot 
(c) Flanged Joints. Unless otherwise specified in the engineering design, flanged joints shall be aligned as described in subparas. (1) or (2), and (3).
(1) Before bolting, mating gasket contact surfaces shall be aligned to each other within 1 mm in 200 mm (1⁄16 in./ft), measured across any diameter.
(2) The flanged joint shall be capable of being bolted such that the gasket contact surfaces bear uni- formly on the gasket.
(3) Flange bolt holes shall be aligned within 3 mm (1⁄8 in.) maximum offset.

Question 57

Q

ASME B31.3

What is the Max Offset for boltholes for mating flanges (Flanges)?

Answer

A

ASME B31.3 (335) ASSEMBLY AND ERECTION
(335.1) Alignment
(335.1.c)
1/8"
(c) Flanged Joints. Unless otherwise specified in the engineering design, flanged joints shall be aligned as described in subparas. (1) or (2), and (3).
(1) Before bolting, mating gasket contact surfaces shall be aligned to each other within 1 mm in 200 mm (1⁄16 in./ft), measured across any diameter.
(2) The flanged joint shall be capable of being bolted such that the gasket contact surfaces bear uni- formly on the gasket.
(3) Flange bolt holes shall be aligned within 3 mm (1⁄8 in.) maximum offset.

Question 58

Q

ASME Sec. lX

What is the Maximum Allowed size of open discontinuity in a bend test (Welding)?

Answer

A

ASME Sec. lX
(QW-163) Acceptance Criteria — Bend Tests
1/8”
The weld and heat-affected zone of a transverse weld- bend specimen shall be completely within the bent portion of the specimen after testing.
The guided-bend specimens shall have no open disconti- nuity in the weld or heat-affected zone exceeding 1⁄8 in. (3 mm), measured in any direction on the convex surface of the specimen after bending. Open discontinuities occurring on the corners of the specimen during testing shall not be considered unless there is definite evidence that they result from lack of fusion, slag inclusions, or other internal discontinuities. For corrosion-resistant weld overlay cladding, no open discontinuity exceeding 1⁄16 in. (1.5 mm), measured in any direction, shall be permitted in the cladding, and no open discontinuity exceeding 1⁄8 in. (3 mm) shall be permitted along the approximate weld interface.

Question 59

Q

API 570

What is the Minimum radius of an insert patch (Repairs)?

Answer

A

API 570 (8) Repairs, Alterations, and Rerating of Piping Systems
(8.1) Repairs and Alterations
(8.1.4) Welding Repairs (Including On-stream)
(8.1.4.2) Permanent Repairs
(8.1.4.2.c)
1”
Insert patches (flush patches) may be used to repair damaged or corroded areas if the following requirements are met:
a) full-penetrationgrooveweldsareprovided;
b) for Class1 and Class2 piping systems, the welds shall be 100% radiographed or ultrasonically tested using NDE procedures that are approved by the inspector;
c) patches may be any shape but shall have rounded corners [1in.(25mm)minimumradius]. See ASME PCC-2 for more information on welded repairs to piping systems.

Question 60

Q

API 570

What is the Maximum diameter of a CML exam point less than or equal to 10” NPS (NDE)?

Answer

A

API 570 (3) Terms, Definitions, Acronyms, and Abbreviations
(3.1) Terms and Definitions
(3.1.20) Examination Point
2”
An area within a CML defined by a circle having a diameter not greater than 2 in. (50 mm) for a pipe diameter not exceeding 10 in. (250 mm), or not greater than 3 in. (75 mm) for larger lines and vessels. CMLs may contain multiple test points.
NOTE Test point is a term no longer in use as test refers to mechanical or physical tests (e.g. tensile tests or pressure tests).

Question 61

Q

API 570

What is the Maximum diameter of a CML exam point greater than 10” NPS (NDE)?

Answer

A

API 570 (3) Terms, Definitions, Acronyms, and Abbreviations
(3.1) Terms and Definitions
(3.1.20) Examination Point
3”
An area within a CML defined by a circle having a diameter not greater than 2 in. (50 mm) for a pipe diameter not exceeding 10 in. (250 mm), or not greater than 3 in. (75 mm) for larger lines and vessels. CMLs may contain multiple test points.
NOTE Test point is a term no longer in use as test refers to mechanical or physical tests (e.g. tensile tests or pressure tests).

Question 62

Q

API 570

In a Soil-to-Air area what is the distance in air from interface (Corrosion)?

Answer

A

API 570
(3) Terms, Definitions, Acronyms, and Abbreviations
(3.1) Terms and Definitions
(3.1.87) soil-to-air interface (S/A)
6”
An area in which external corrosion may occur on partially buried pipe.

(NOTE ) The zone of the corrosion will vary depending on factors such as moisture, oxygen content of the soil, and operating temperature. The zone generally is considered to be from 12 in. (305 mm) below to 6 in. (150 mm) above the soil surface. Pipe running parallel with the soil surface that contacts the soil is included.

Question 63

Q

API 570

In a Soil-to-Air area what is the distance in soil from interface (Corrosion)?

Answer

A

API 570 (3) Terms, Definitions, Acronyms, and Abbreviations
(3.1) Terms and Definitions
(3.1.87) soil-to-air interface (S/A)
12”
An area in which external corrosion may occur on partially buried pipe.
NOTE The zone of the corrosion will vary depending on factors such as moisture, oxygen content of the soil, and operating temperature. The zone generally is considered to be from 12 in. (305 mm) below to 6 in. (150 mm) above the soil surface. Pipe running parallel with the soil surface that contacts the soil is included.

Question 64

Q

API 570

What is minimum upstream limit of intensive examination to an injection point circuit (NDE)?

Answer

A

API 570 (5) Inspection, Examination, and Pressure Testing Practices

(5. 5) General Types of Inspection and Surveillance
(5. 5.9) 12” Injection points are sometimes subject to accelerated or localized corrosion from normal or abnormal operating conditions. Those that are may be treated as separate inspection circuits, and these areas need to be inspected thoroughly on a regular schedule. When designating an injection point circuit for the purposes of inspection, the recommended upstream limit of the injection point circuit is a minimum of 12 in. (300 mm) or three pipe diameters upstream of the injection point, whichever is greater. The recommended downstream limit of the injection point circuit is the second change in flow direction past the injection point, or 25 ft (7.6 m) beyond the first change in flow direction, whichever is less. In some cases, it may be more appropriate to extend this circuit to the next piece of pressure equipment, as shown in Figure 1.

Answer 65

A

API 570 (9) Inspection of Buried Piping
(9.3) Frequency and Extent of Inspection
(9.3.6) External and Internal Inspection Intervals
6’-8’
If internal corrosion of buried piping is expected as a result of inspection on the above-grade portion of the line, inspection intervals and methods for the buried portion should be adjusted accordingly. The inspector should be aware of and consider the possibility of accelerated internal corrosion in deadlegs.The external condition of buried piping that is not cathodically protected should be determined by either pigging, which can measure wall thickness, or by excavating according to the frequency given in Table 5. Significant external corrosion detected by pigging or by other means may require excavation and evaluation even if the piping is cathodically protected.
Piping inspected periodically by excavation shall be inspected in lengths of 6 ft to 8 ft (2.0 m to 2.5 m) at one or more locations judged to be most susceptible to corrosion. Excavated piping should be inspected full circumference for the type and extent of corrosion (pitting or general) and the condition of the coating.

Answer 66

A

API 570 (Fig. C.2)
1/2” Diameter
Size of patch should not exceed 1/2 the pipe diameter. A full encirclement sleeve should be used if the corroded area exceeds 1/2 the diameter.

Answer 67

A

API 570 (5) Inspection, Examination, and Pressure Testing Practices
(5.5) General Types of Inspection and Surveillance
(5.5.9) Injection Point Inspection
3D or 12” whichever is greater
When designating an injection point circuit for the purposes of inspection, the recommended upstream limit of the injection point circuit is a minimum of 12 in. (300 mm) or three pipe diameters upstream of the injection point, whichever is greater. The recommended downstream limit of the injection point circuit is the second change in flow direction past the injection point, or 25 ft (7.6 m) beyond the first change in flow direction, whichever is less. In some cases, it may be more appropriate to extend this circuit to the next piece of pressure equipment, as shown in Figure 1.

Answer 68

A

API 570 (5) Inspection, Examination, and Pressure Testing Practices
(5.8) Pressure Testing of Piping Systems—General
(5.8.1) Test Fluid
120°F
The test fluid should be water unless there is the possibility of damage due to freezing or other adverse effects of water on the piping system or the process or unless the test water will become contaminated and its disposal will present environmental problems. In either case, another suitable nontoxic liquid may be used. If the liquid is flammable, its flash point shall be at least 120 °F (49 °C) or greater, and consideration shall be given to the effect of the test environment on the test fluid.

Answer 69

A

API 570 (5) Inspection, Examination, and Pressure Testing Practices
(5.7) Condition Monitoring Methods
(5.7.1) UT and RT
150°F
When ultrasonic measurements are taken above
150°F (65°C), instruments, couplants, and procedures should be used that will result in accurate measurements at the higher temperatures. If the procedure does not compensate for higher temperatures, measurements should be adjusted by the appropriate temperature correction factor.

Answer 70

A

API 570 (8) Repairs, Alterations, and Rerating of Piping Systems
(8.2) Welding and Hot Tapping
(8.2.3) Preheating and PWHT
(8.2.3.2) Preheating
300°F
Preheat temperature used in making welding repairs shall be in accordance with the applicable code and qualified welding procedure. Exceptions for temporary repairs shall be approved by the piping engineer.
Preheating to not less than 300 °F (150 °C) may be considered as an alternative to PWHT for alterations or repairs of piping systems initially PWHT as a code requirement (see note). This applies to piping constructed of the P-1 steels listed in ASME B31.3. P-3 steels, with the exception of Mn-Mo steels, also may receive the 300 °F (150 °C) minimum preheat alternative when the piping system operating temperature is high enough to provide reasonable toughness and when there is no identifiable hazard associated with pressure testing, shutdown, and startup. The inspector should determine that the minimum preheat temperature is measured and maintained. After welding, the joint should immediately be covered with insulation to slow the cooling rate.

NOTE: Preheating may not be considered as an alternative to environmental cracking prevention.

Piping systems constructed of other steels initially requiring PWHT normally are postweld heat treated if alterations or repairs involving pressure retaining welding are performed. The use of the preheat alternative requires consultation with the piping engineer who should consider the potential for environmental cracking and whether the welding procedure will provide adequate toughness. Examples of situations where this alternative could be considered include seal welds, weld metal buildup of thin areas, and welding support clips.

Answer 71

A

API 570 (8) Repairs, Alterations, and Rerating of Piping Systems
(8.2) Welding and Hot Tapping
(8.2.3) Preheating and PWHT
(8.2.3.3) PWHT
(8.2.3.3.c)
300°F
A pre heat of 300°F (150°C), or higher as specified by specific welding procedures, is maintained while welding.

Answer 72

A

API 570 (5) Inspection, Examination, and Pressure Testing Practices
(5.1) Inspection Plans
(5.1.1) Development of an Inspection Plan
(5.1.1.1)
[above 750 °F (400 °C)]
An inspection plan shall be established for all piping systems within the scope of this code. The inspection plan shall be developed by the inspector and/or engineer. A corrosion specialist should be consulted as needed to clarify potential damage mechanisms and specific locations where degradation may occur. A corrosion specialist should be consulted when developing the inspection plan for piping systems that operate at elevated temperatures [above 750 °F (400 °C)] and piping systems that operate below the ductile-to-brittle transition temperature.

Answer 73

A

API 574 (10) Inspection Procedures and Practices
(10.3) Internal Visual Inspection
(10.3.5) Joints
(10.3.5.2) Welded Joints
(10.3.5.2.4)
800 °F (426 °C) or Greater
Welded joints in carbon steel and carbon-molybdenum steel exposed to elevated temperatures of 800 °F (426 °C) or greater can be subject to graphitization. When graphitization is suspected, a sample should be taken from a welded joint and examined metallurgically for evidence of excessive graphitization.

Answer 74

A

API 574 (7) Inspection Plans
(7.4) Inspection for Specific Damage Mechanisms
(7.4.11) Creep Cracking
(7.4.11.1)
Above 900°F (482°C)
Creep is dependent on time, temperature, and stress. Creep cracking can eventually occur at design conditions since some piping code allowable stresses are in the creep range. Cracking is accelerated by creep/ fatigue interaction when operating conditions in the creep range are cyclic. Particular attention should be given to areas of high stress concentration. If excessive temperatures are encountered, mechanical property and microstructural changes in metals can also take place, which can permanently weaken equipment. An example of where creep cracking has been experienced in the industry is in 1 1/4 Cr steels above 900 °F (482 °C).

Answer 75

A

API 570 (5) Inspection, Examination, and Pressure Testing Practices

(5. 8) Pressure Testing of Piping Systems—General
(5. 8.3) Test Temperature and Brittle Fracture Considerations

To minimize the risk of brittle fracture during a pressure test, the metal temperature should be maintained at least 30 °F (17 °C) above the MDMT for piping that is more than 2 in. (5 cm) thick, and 10 °F (6 °C) above the MDMT for piping that have a thickness of 2 in. (5 cm) or less. The test temperature need not exceed 120 °F (50 °C) unless there is information on the brittle characteristics of the piping construction material indicating a higher test temperature is needed.

Answer 76

A

API 570 (5) Inspection, Examination, and Pressure Testing Practices

(5. 8) Pressure Testing of Piping Systems—General
(5. 8.3) Test Temperature and Brittle Fracture Considerations

To minimize the risk of brittle fracture during a pressure test, the metal temperature should be maintained at least 30 °F (17 °C) above the MDMT for piping that is more than 2 in. (5 cm) thick, and 10 °F (6 °C) above the MDMT for piping that have a thickness of 2 in. (5 cm) or less. The test temperature need not exceed 120 °F (50 °C) unless there is information on the brittle characteristics of the piping construction material indicating a higher test temperature is needed.

Answer 77

A

API 570 (8) Repairs, Alterations, and Rerating of Piping Systems
(8.2) Welding and Hot Tapping
(8.2.3) Preheating and PWHT
(8.2.3.2) P1 & P3
Preheat temperature used in making welding repairs shall be in accordance with the applicable code and qualified welding procedure. Exceptions for temporary repairs shall be approved by the piping engineer.
Preheating to not less than 300 °F (150 °C) may be considered as an alternative to PWHT for alterations or repairs of piping systems initially PWHT as a code requirement (see note). This applies to piping constructed of the P-1 steels listed in ASME B31.3. P-3 steels, with the exception of Mn-Mo steels, also may receive the 300 °F (150 °C) minimum preheat alternative when the piping system operating temperature is high enough to provide reasonable toughness and when there is no identifiable hazard associated with pressure testing, shutdown, and startup. The inspector should determine that the minimum preheat temperature is measured and maintained. After welding, the joint should immediately be covered with insulation to slow the cooling rate.

Answer 78

A

API 570 (5) Inspection, Examination, and Pressure Testing Practices
(5.12) -1 Thread
Inspection of Flanged Joints
Flanged joints should be examined for evidence of leakage, such as stains, deposits, or drips. Process leaks onto flange fasteners and valve bonnet fasteners may result in corrosion or environmental cracking. This examination should include those flanges enclosed with flange or splash-and-spray guards. Flanged joints that have been clamped and pumped with sealant should be checked for leakage at the bolts. Fasteners subjected to such leakage may corrode or crack (e.g. caustic cracking). If repumping is contemplated, affected fasteners should be renewed first.
Accessible flange faces should be examined for distortion and to determine the condition of gasket-seating surfaces. If flanges are significantly bent or distorted, their markings and thicknesses should be checked against engineering requirements before taking corrective action. Flange fasteners should be examined visually for corrosion and thread engagement. Fasteners should be fully engaged. Any fastener failing to do so is considered acceptably engaged if the lack of complete engagement is not more than one thread.
The markings on a representative sample of newly installed fasteners and gaskets should be examined to determine whether they meet the material specification. The markings are identified in the applicable ASME and ASTM standards. Questionable fasteners should be verified or renewed.
Additional guidance on the inspection of flanged joints can be found in ASME PCC-1 [13].

Brainscape's Knowledge GenomeTM

API 570 Flashcards

Brainscape's Knowledge Genome^TM