Definitions Flashcards
1
Q
Shortened title for API570
A
Inspection code
2
Q
Documented plan for detailing scope, methods and timing of inspection activists for piping which may include recommended repair and or maintenance
A
Inspection plan
3
Q
Integrity operating window
Established limits for process variables that can affect the integrity o piping system if the process operation deviates from the established limits for a predetermined amount of time.
A
Integrity operating envelope
4
Q
Inspection performed Id the inside of piping using visual and or NDE
A
Internal inspection
5
Q
A legally constituted government administration that may adopt rules relating to piping
A
Jurisdiction
6
Q
Level gauge glass piping assembly attached to s vessel
A
Level bridle
7
Q
Deterioration such as corrosion that is confined to a limited area of metal surface
A
Localized corrosion
8
Q
Welding repairs that involve removal and replacement of large sections of piping systems
A
Major repairs
9
Q
Documented management system for review and approval of changes in process or piping systems priori to implementation of change
A
Management of change
MOC
10
Q
Documents quality assurance procedure used to asses metallic alloy weldment and attachments shed specified to verify conformance with the selected or specified alloy material designated by owner user
Note: this program may include a description of methods for alloy material testing, physical component marking and proves. Record keeping
A
Material verification program
11
Q
Max internal pressure permitted for confined operation at the most severe condition of coincident internal or external pressure and temp (minimum or max) expected during service. It is the same as design pressure as defined in ASME B31.3 and other code sections and is subject to the same rules relations g to allowances for variations of pressure or temp or both
A
Maximum allowable working pressure
MAWP
12
Q
Lowest temp at which a significant pressure load (operating loss, start up load, transient loads) can be applied to piping systems as defined in construction code.
Ex. ASME B31.3 8th Ed para 323.2 “temp limits”
A
Min design metal temp
MDMT
13
Q
Thickness without corrosion allowance for each component of piping system based on the appropriate design code calcs and code allowable stress that consider pressure, mechanical and structural loadings
Note: alternatively required thickness can be reassessed using FFS analysis in accordance with API579-1
A
Min required thickness
14
Q
Process mid points of joining of process steams of differing composition and or temp where additional design attention. Operating limits and or process monitoring are utilized to avoid corrosion problems not all process mix points are problematic, however they need to be identified and evaluated for possible degradation mechanisms
A
Mix points
15
Q
Item that is not in conformance with specified codes, standards or other requirements.
A
Nonconformance
16
Q
Competent sand attachments of where the portion of piping that does not contain the process pressure
Example clips shoes repads supports where pleats non-stiffening insulation support rings etc.
A
Non-pressure boundary
17
Q
Piping systems not included within the plot boundary limits of a process unit such as a hydrocracker and Etheline cracker or a crude unit
Example tank farm piping and other lower consequence piping outside the limits of the prices unit
A
Off site piping
18
Q
Piping systems included within the plot limits of process units such as a hydrocracker and ethylene cracker or crude unit
A
On site piping
19
Q
A condition where in-service piping systems have not been prepared for an internal inspection
New piping systems that are on stream can also be empty or may still have residual process fluids in them and not be currently part of the process system
A
On stream inspection
20
Q
Piping inspections for in-service equipment that have not been performed by their due dates documented in the inspection schedule plan
A
Overdue inspection
21
Q
Piping located where leakage liquids or solids that would result in discharge into streams rivers bays etc. resulting in a potential environmental incident
A
Overwater piping
22
Q
And Erin or or user of piping systems who exercise control over the operation engineering inspection repair alteration pressure testing and rating of the piping
A
Owner user
23
Q
And authorize inspector employed by an owner user who has qualified by written examination under the provisions of section 4 and annex A
A
Owner user inspector
24
Q
A pressure tight cylinder used to convey a fluid for to transmit a fluid pressure and that is ordinarily designated pipe inapplicable material specifications
Note materials that are designated as two or tubing in the specifications are treated as pipe in his cage when intended for pressure service
A
Pipe
25
Process piping that is supported by consecutive stanchions or sleepers including straddle racks and extensions
Pipe rack piping
26
A section of piping that is exposed to a process environment of similar corrosivity were expected damage mechanisms and is of similar design conditions and construction material
Note complex process units or piping systems or divided into piping circuits to manage the necessary inspections calculations and recordkeeping
Note when establishing the boundary of a particular piping circuit the inspector may also size it to provide a practical package for recordkeeping and performing field inspection
Piping circuit
27
Person or organization acceptable to the owner or user who are knowledgeable and experienced in the engineering disciplines associated with evaluating mechanical and material characteristics affecting the integrity and reliability of piping component an systems
The piping engineer by consulting with appropriate specialist should be regarded as a composite of all entities necessary to properly address a technical requirement
Piping engineer
28
And assembly of interconnected piping circuits that are subject to the same set or sets of design conditions and is used to convey distribute mix separate discharge meter control or snub fluid flows
Nude piping systems also include pipe supporting elements but do not include support structures such as structural frames and foundations
Piping system also known as piping circuit
29
Any physical evaluation or test of a material to confirm that the material which is been or will be placed into service is consistent with the selected or specified alloy material designated by the owner user
Note these evaluations Ortez can prove qualitative or quantitative information that is sufficient to verify the nominal alloy composition
Positive material identification PMI
30
Treatment which consists of heating an entire weldment or piece of fabricated piping to an elevated temperature after completion of welding in order to relieve the detrimental effects of welding he such as reduce residual stress is reduced hardness and or slightly modify properties see ASME B31.3 paragraph 331
Post weld heat treatment PW HT
31
The portion of piping that contains the pressure retaining piping elements joined or assembled into pressure tight fluid containing systems. pressure bounding boundaty components include pipe tubing fittings flanges gaskets boating valves and other devices such as expansion joints and flexible joints
Note also see nonpressure boundary definition
Pressure boundary
32
Minimum allowed pipe wall thickness needed to hold design pressure at the design temperature
Note 1 pressure design thickness is determined using the rating code formula including needed reinforcement thickness
Note2: pressure design thickness does not include thickness for structural lutes corrosion allowance or mill tolerances
Pressure design thickness
33
Process piping in normal active service that cannot be valved off or if it were valved off would significantly affect unit operability. primary process piping normally includes most process piping greater then NPS 2" and typically does not include smallbore or auxiliary process piping
Primary process piping
34
A document that specifies or describes how an activity is to be performed on piping system
Note. A procedure may include methods to be employed equipment or materials to be used qualifications of personnel involved and sequence of work
Procedures
35
Hydrocarbon or chemical piping located at where associated with a refinery or manufacturing facility process piping includes pipe rack tank farm and prices yet piping but excludes utility piping
Process piping
36
Those physical activities that are conducted to check conformance with specifications in accordance with the quality assurance plan
Quality control
37
Activity that discards an existing component fitting or portion of the piping circuit and replaces it with new or existing spare materials of the same or better qualities as the original piping components
Renewal
38
work necessary to restore a piping system to a condition suitable for safe operation at the design conditions if any of the restoratative 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
3.1 .78 repair
39
An owner or user of piping systems who repairs or altered his own equipment in accordance with API 570
A contractor who's qualifications are acceptable to the owner or user of piping and he makes repairs or alterations in accordance with API 570
One he was authorized by acceptable to wear otherwise not created by the jurisdiction and he makes repairs in accordance with API 570
Repair organization 3.1 .79
40
Calculations to establish pressures and temperatures appropriate for piping system including design pressure temperature MAWP structural minimums required thicknesses
3.1 .80 rating
41
A change in the design temperature design pressure or the MAWP Of a piping system sometimes called rating a re-rating may consist of an increase or decrease or combination of both D rating below original design conditions is a means to provide increased corrasion allowance
Re-rating 3.1 .81
42
D rating below original design conditions is a means to provide increased
Corrosion allowance
43
A risk assessment and risk management process that is focused on inspection planning for piping systems for loss of containment and processing facilities which considers both the probability of failure and consequence of failure due to material deterioration
Risk based inspection
| RBI
44
Inspection technique used to find the thinnest thickness measurement Eddie CML C guidance contain in API 574
3.1 .83 scanning
45
An individual who joins in overlays cured subassemblies of FRP piping
3.1.84 secondary bonder
46
Process piping often small boiler piping downstream of block bows that can be clues without significantly affecting the process of unit operability
3.1 .85 secondary process piping
47
Piping that is less than or equal to NPS 2
Small bore piping
| SBP
48
An area in which external corrasion may occur on partially buried pipe
Note: the zone of the corrasion will vary depending on five factors such as moister oxygen content of the soil and operating temperature is it generally is considered to be from 12 inches below to 6 inches above the soil surface pipe running parallel with the soil surface that contacts the soil is included
Soil to air interface
S/A
3.1.87
49
A section of piping encompassed by flanges are other connecting fittings such as unions
Spool 3.1 .88
50
Minimum thickness without corrasion allowance based on structural and other loadings
Structural minimum thickness 3.1 .89
51
Repairs made to piping systems in order to restore sufficient integrity to continue safe operation until permanent repairs can be scheduled and accomplish within a time. Acceptable to the inspector or piping engineer
Temporary repairs 3.1 .90
52
Process piping inside tank farm dates or directly associated with the tank farm
Tank Farm piping
53
Condition monitoring location
CML
54
Corrasion under installation including stress corrasion cracking under insulation
CUI
55
Fiberglass reinforced plastic
FRP
56
Long term
LT
57
Management of change
MOC
58
Maximum allowable working pressure
MAWP
59
Magnetic particle technique
MT
60
Material test report
MTR
61
Nominal pipe size follow when appropriate by the specific size designation number without an inch symbol
NPS
62
Procedure qualification record
PQR
63
Post weld heat treatment
PWHT
64
Risk based inspection
RBI
65
Radiographic examination method or radiography
RT
66
Reinforce thermoset plastic
RTP
67
Small bore piping
SBP
68
Short-term
ST
69
Specified minimum yield strength
SMYS
70
Welding procedure specification
WPS
71
External internal on stream eval of piping condition conducted by authorized inspector or designee
Inspection
72
Blank is responsible to the owner user for activities involving design engineering review rating analysis or evaluation of piping system systems covered by API 570
4.3.2 piping engineer
73
All repairs and alterations shall be performed by a repair organization the repair organization shall be responsible to the owner user and shop provide the materials equipment quality control and workmanship necessary to maintain and repair the piping systems in accordance with requirements of API 570
4.3.3 authorize piping inspector
74
4.3.4 when inspections repairs or alterations are being conducted on piping systems a blank shall be responsible to the interviews are for determining that the requirements of API 571 inspection examination quality shorts and testing or met
4.3.4 authorize piping inspector
75
4.3.4 The blank shall be directly involved in the inspection activities with which in most cases will require field activities to ensure the procedures are followed
Authorize piping inspector
76
4.3.4 The inspector is also responsible for extending the scoop of the inspection with appropriate consultation with engineers specialists where do you justify depending upon the findings of the inspection where nonconformance is our discovered the inspector is responsible for notifying the blank in a timely manner and making appropriate repair or other mitigating recommendations
Owner user
77
4.3.4 The authorized piping inspector may be assisted in performing visual inspections by other properly trained and qualified qualified individuals who may or may not be certified piping inspectors such as examiners and operating personnel personnel performing NDE shall meet the qualifications identified in 4.3.5 but need not be authorized piping inspectors however all examination results will be evaluated and excepted by the authorize piping inspector
Authorize piping inspector
78
5.1.1.1 INSPECTION PLANS
blank should be consulted to clarify potential damage mechanisms and locations where degradations may occur
Corrosion specialist
79
he or she maybe should be consulted when developing the inspection plan for piping systems to operate at elevated Temps above
700 Fahrenheit/400°C and piping systems that operate below the ductile to brutal transition tips
80
This section has more information on the development of inspection plans
API 574
81
5.1.1.2 inspection plans are developed from several sources of data piping shall be evaluated based on present were possible
Damage mechanisms
82
5.1.1.2 BLANK determined by
type of damage
Rate of damage progression
Tolerance of equipment to the type of damage
Capability of NDE method to identify damage
Extent of examination
RBI see section 5.2
Exam intervals
83
On stream is the same as
Non-intrusive
84
5.2 when the owner user chooses to conduct an BLANK assessment it show include a systematic evaluation of both the probability and the associated consequences of failure
RBI
85
Details on RBI methodology G that has all the key elements are defined in
API 580. API 581
86
5.2 RBI identifying blank for key process variables is an important adjunct to RBI
Integrity of reading envelopes. See 4.1
87
Instrument and machinery piping typically smallbore secondary process piping they can be isolated from primary piping systems examples include flush line see you will nines analyzer lines balance lines but for gas lines drains and vents
Auxiliary piping
88
The blank in FRP equipment typically composed of an inner service and interior layer which is specified as necessary to provide the best overall resistance to chemical attack
Corrasion barrier
89
The rate of metal loss due to erosion erasion corrasion for the chemical reactions with the environment either internal or external
Corrasion rate
90
Blank and piping systems that have been identified as vital to process safety
No critical blank or those that need to operate reliably in order to avoid the potential to house it is events were substantial consequences should a leak occur
Critical check valves
91
API blank is a comprehensive list and description of damage mechanisms
API 571
92
And imperfection of a type or magnitude exceeding the acceptable criteria
Defect
93
```
5.4.1.1 damage mechanism
Sulfidation
Oxidation
Microbiologically influenced corrosionm
Organic acid corrosion
Erosion corrosion
Galvanic corrosion
CUI
```
General and local metal loss
94
```
5.4.1.1 damage mechanism
Fatigue
Caustic stress corrosion cracking
Sulfide stress cracking
Chloride. Stress corrasion cracking
Polly sigh ionic acid stress corrasion cracking
Other forms of environmental cracking
```
Surface connected cracking
95
5.4.1.1 damage mechanism
| Hydrogen induced cracking
Subsurface cracking
96
5.4.1.1 damage mechanism
| High temperature hydrogen attack creep
Microfissuring during microvoid formation
97
5.4.1.1 damage mechanism
| Graphitizatiinbtemper embrittlement
Metalllurgical changes
98
Hydrogen blistering
Blistering
99
Creep and stress rupture thermal
Dimensional changes
100
Brittle fracture
Material properties changes
101
```
Damage mechanism
Sulfudation
Oxidation
Microbiologically influence corrosion
Organic acid corrasion
Erosion/erosion corrosion
Galvanic corrosion
CUI
```
General and local metal loss
102
```
Damage mechanism
Fatigue
Caustic stress corrosion cracking
Sulfide stress cracking
Chloride stressed corrasion cracking
Pollys ionic acid stress corrosion cracking
Other forms of environmental cracking
```
Surface connected cracking
103
Damage mechanism is hydrogen induce cracking
Damage type subsurface cracking
104
High temperature hydrogen attack creep
Damage type is micro figuring/microvoid formation
105
Damage mechanism
Graphitization
Temper embrittlemenr
Metallurgical changes
106
Damage mechanism
| Hydrogen blistering
Blistering
107
Damage mechanism
| Creep and stress rupture thermal
Dimensional changes
108
Damage mechanism
| Brittle fracture
Material properties changes
109
The potential of damage and equipment is dependent dependent upon
Material of construction design construction and operating conditions
110
Detailed information concerning common damage mechanisms (critical factors, appearance, and typical inspection and monitoring techniques) is found in
API 571
111
Recommended inspection practices for specific types of damage mechanisms are described in
API 574
112
This section of API 570 covers interval frequency and extent of inspection
Section 6
113
Imperfections identified during inspections and examinations should be characterized size and evaluated per
Section 7 of API 570
114
```
Damage mechanism
Sulfudation
Oxidation
Microbiologically influence corrosion
Organic acid corrasion
Erosion/erosion corrosion
Galvanic corrosion
CUI
```
General and local metal loss
115
```
Damage mechanism
Fatigue
Caustic stress corrosion cracking
Sulfide stress cracking
Chloride stressed corrasion cracking
Pollys ionic acid stress corrosion cracking
Other forms of environmental cracking
```
Surface connected cracking
116
Damage mechanism is hydrogen induce cracking
Damage type subsurface cracking
117
High temperature hydrogen attack creep
Damage type is micro figuring/microvoid formation
118
Damage mechanism
Graphitization
Temper embrittlemenr
Metallurgical changes
119
Damage mechanism
| Hydrogen blistering
Blistering
120
Damage mechanism
| Creep and stress rupture thermal
Dimensional changes
121
Damage mechanism
| Brittle fracture
Material properties changes
122
The potential of damage and equipment is dependent dependent upon
Material of construction design construction and operating conditions
123
Detailed information concerning common damage mechanisms (critical factors, appearance, and typical inspection and monitoring techniques) is found in
API 571
124
Recommended inspection practices for specific types of damage mechanisms are described in
API 574
125
This section of API 570 covers interval frequency and extent of inspection
Section 6
126
Imperfections identified during inspections and examinations should be characterized size and evaluated per
Section 7 of API 570
127
What are Hammer liquid slugging in vapor lines abnormal thermal expansion can calls
Excessive line movement
128
This portion of the piping is subjected to accelerated or localize corrasion
Injection points
129
When selecting inspection points at injection points the upstream limit is
12 inches or three times the pipe diameter downstream of injection point or whichever is greater
130
Recommended downstream limit when inspecting an injection point is
Second change in flow direction pass inspection point or 25 feet beyond first change and flow direction
131
More extensive inspection of injection points can be applied to an area
12 inches upstream of injection nozzle and and at least 10 pipe diameters downstream
132
5.6.2 CML Monitoring: Corrasion rates remaining life and next inspection interval should be calculated to determine
Limiting component of pipe circuit
133
5.6.2 CML Monitoring: inspection intervals are stab Lish based on
Remaining life were RBI analysis
134
Ultrasonic measurements taken above 150°F ir 65°C should have ??
Appropriate temperature correction factor
135
Improper instrument calibration
External coatings or scale
Significant surface roughness
Rocking of the prove on curved surfaces
Sub surface material flows such as laminations
Temperature affects at temperatures above 150°F or 65°C
Improper resolution on the detector screens
Thicknesses of less than 1/8 inch or 3.2 mm
Improper coupling of prove such as too much or too little
UT thickness measurement in accuracies
136
Referred to API 571 for guidance on inspection techniques that are appropriate for
Damage mechanisms
137
Magnetic particle examination can be to detect
Cracks and other linear discontinuities that extend to the surface of the material and ferromagnetic materials
138
ASME be PVC section 5 article 7 provides guidance on performing
MT examination
139
5.7.2 NDE this technique can displays cracks prosody or pinholes the extent to surface especially in nonmagnetic materials
Liquid penetrant
140
5.7.2 NDE this technique can detect Interno imperfections such as prosody weld slag inclusions cracks and thickness of components
Radiography
| ASME BPVC sec V Art 2
141
5.7.2 NDE This technique can detect internal and surface breaking cracks and other elongated discontinuities
Ultrasonic flawed detection
| ASME be PVC section 5 article for article 5 in article 23 provide guidance
142
5.7.2 NDE this technique is used for detecting subsurface breaking cracks and elongated discontinuities
Alternating current flux leakage
143
This technique to text localize metal loss cracks and elongated discontinuities
Eddy current
| ASME BPVC section 5 article 8
144
5.7.2 NDE This is used in Identiying metallurgical changes
Field metallographic replication
145
5.7.2 NDE this technique the tux structurally significant defects
Acoustic emission examination
| ASME BPVC section 5 article 11 and 12
146
5.7.2 NDE This technique detects temperature of components
Thermography
147
5.7.2 NDE this technique detects through sickness defects
Leak testing
| ASME BPVC section 5 article 10
148
5.7.4 UT shear wave
Detects interior surface ID breaking flaws when inspecting from interior surface
Detects characterization and or thru wall sizing of defects
149
5.8.1 pressure test fluid - When pressure testing 300 series stainless steel the total chloride concentration should be less then ??
Less then 50 ppm
150
5.8.1 pressure test fluid if using a liquid that is flammable it's flashpoint shall be at least
120°F or 49°C or greater
151
5.8.1 pressure test fluid
When referring to partible water in the context that was US practice with blank parts per million maximum chloride sanitize with chlorine were ozone
250 ppm
152
A point where smallbore pipe containing high velocity fluid and there's a large diameter pipe Norlee at a 90° angle causing swirling and turbulence
Injection point
Not tees of similar sizes
Not Ys of similar size
Orifice plates control valves reducers
