Terms

Question 1

• a method of measuring the change in electrical voltage current in the soil along and around the pipeline to locate coating holidays and characterize corrosion activity.

Answer 1

Alternating Current Voltage Gradient (ACVG)

Question 2

accurate location of defects. uses difference of 2 reference electrodes. a method of measuring the change in electrical voltage current in the soil along and around the pipeline to locate coating holidays and characterize corrosion activity.

Answer 2

Direct Current Voltage Gradient (DCVG)

Question 3

Proof testing of sections of a pipeline by filling the line with water and pressurizing it until the nominal hoop stresses in the pipe reach a specified value.

Answer 3

Hydrostatic test (hydrotest)

Question 4

Means the maximum pressure at which a pipeline or segment of a pipeline may be operated

Answer 4

Maximum allowable operating pressure (MAOP)

Question 5

The minimum yield strength, expressed in pounds per square inch, prescribed by the specification under which the material is purchased from the manufacturer.

Answer 5

Specified minimum yield strength (SMYS)

Question 6

A general term denoting land, property or interest therein, usually in a strip, acquired for or devoted to a specific purpose such as a highway or pipeline.

Answer 6

Right-of-way (ROW)

Question 7

The Pipeline and Hazardous Materials Safety Administration of the United States Department of Transportation.

Answer 7

PHMSA

Question 8

A set of safety management, analytical, operations, and maintenance processes that are implemented in an integrated and rigorous manner to assure operators provide protection for HCAs. While the rules provide some flexibility for an operator to develop a program best suited for its pipeline system(s) and operations, there are certain required features – called “program elements” – which each integrity management program must have.

Answer 8

Integrity management program

Question 9

A written explanation of the mechanisms or procedures the operator will use to implement its integrity management program and to ensure compliance with this subpart.

Answer 9

Integrity management plan (IM Plan)

Question 10

For integrity management, a written plan that identifies for each covered segment, the potential threats, the methods of assessment for the threats, and a schedule for completing the integrity assessments.

Answer 10

Baseline Assessment Plan (BAP)

Question 11

Testing in which the part being tested is not rendered unusable. these techniques include radiography (X-ray), ultrasonic, magnetic particles, dye penetrant, or ammonium persulfate.

Answer 11

Non-destructive testing (NDT)

Question 12

Any of a variety of inspection devices designed to be run while the pipeline remains in service. These devices, measure and record the internal geometry, external or internal corrosion as well as provide information about pipe characteristics such as wall thickness and other pipe defects. Magnetic flux leakage, ultrasonic, calipers, and geometry are examples of smart tools; also referred to as ILI tools.

Answer 12

Smart pig

Question 13

The type of inspection of a steel pipeline using an electronic instrument or tool that travels along the interior of the pipeline in order to locate corrosion and/or material defects.

Answer 13

ILI or Inline inspection

Question 14

An integrity assessment method using more focused application of the principles and techniques of direct assessment to identify internal and external corrosion in a covered transmission pipeline segment

Answer 14

Confirmatory direct assessment (CDA)

Question 15

Process an operator uses to identify areas along the pipeline where fluid or other electrolyte introduced during normal operation or by an upset condition may reside, and then focuses direct examination on the locations in covered segments where internal corrosion is most likely to exist. The process identifies the potential for internal corrosion caused by microorganisms, or fluid with CO2, O2, hydrogen sulfide or other contaminants present in the gas.

Answer 15

Internal corrosion direct assessment (ICDA)

Question 16

A four-step process that combines pre-assessment, indirect inspection, direct examination, and post-assessment to evaluate the threat of external corrosion to the integrity of a pipeline.

Answer 16

External corrosion direct assessment (ECDA)

Question 17

Equipment and practices used to take measurements at ground surface above or near a pipeline to locate or characterize corrosion activity, coating holidays, or other anomalies.

Answer 17

Indirect inspection

Question 18

Inspections and measurements made on the pipe surface at excavations as part of external corrosion direct assessment

Answer 18

Direct examination

Question 19

An integrity assessment method that utilizes a process to evaluate certain threats (i.e., external corrosion, internal corrosion and stress corrosion cracking) to a covered pipeline segment’s integrity. The process includes the gathering and integration of risk factor data, indirect examination or analysis to identify areas of suspected corrosion, direct examination of the pipeline in these areas, and post assessment evaluation.

Answer 19

Direct assessment (DA

Question 20

the use of testing techniques to ascertain the condition of a covered pipeline segment.

Answer 20

Assessment

Question 21

is the distance beyond which a person standing outside in the vicinity of a pipeline rupture and fire would have a 99% chance of surving. PIR increase as diameter and pressure increase.

Answer 21

Potential impact radius (PIR)

Question 22

outside areas occupied by 20 or more people on at least 50 days in any 12 month period. Buildings occupied by 20 or more people on al least 5 days a week for 10 weeks in any 12 month period. A facility such as a hospital where evacuation would be difficult.

Answer 22

Identified sites

Question 23

A segment of gas transmission pipeline located in a high consequence area.

Answer 23

• Covered segment or covered pipeline segment

Question 24

An area defined by certain Class locations or a potential impact radius that must be covered by an gas operator’s integrity management program (see §192.903 for a complete definition) A class 3 or class 4 location. Or a class 1 or class 2 where the potential impact radius is greater than 660 ft (220yds) and the potential impact circle contains 20 or more buildigs.

Answer 24

• High consequence area (HCA) – Gas

Question 25

An onshore area that extends 220 yards (200 meters) on either side of the centerline of any continuous 1-mile (1.6 kilometers) of a pipeline.

Answer 25

Class location unit -

Question 26

A class location unit where buildings with four or more stories above ground are prevalent.

Answer 26

Class 4 location

Question 27

A class location unit that has 46 or more buildings intended for human occupancy; or An area where the pipeline lies within 100 yards (91 meters) of either a building or a small, well-defined area (such as a playground, recreation are, outdoor theater, or other place of public assembly) that is occupied by 20 or more persons on at least 5 days a week for 10 weeks in any 12-month period. (the days and weeks need not be consecutive.)

Answer 27

Class 3 location

Question 28

A class location unit that has more than 10 but fewer than 46 building intended for human occupancy.

Answer 28

Class 2 location

Question 29

An offshore area; or Any class location unit that has 10 or fewer building intended for human occupancy.

Answer 29

Class 1 location

Question 30

Administers Pipeline Safety regulatory programs and establishes the regulatory agenda.

Answer 30

OPS office of pipeline safety

Question 31

Any of a variety of in line tools designed to measure the internal geometry and configuration of a pipeline, including dents, ovality and wrinkles, bend radius and angle and changes in wall thickness.

Answer 31

geometry pig

Question 32

located in the transmission system, in which covered segments are located. It extends from the location where liquid may first enter the pipeline and encompasses the entire area along the pipeline where internal corrosion may occur and where further evaluation is needed. may encompass one or more covered segments.

Answer 32

icda region

Question 33

subset of one segment

characterized by common attributes

pipe with similar construction and environmental characteristics

use of same indirect inspection tools

Answer 33

ecda region

Question 34

is an instrument for which an extremely low, “near d.c.” frequency (4 Hz) is used to mirror as closely as possible the d.c. current generated by the cathodic
protection. Integral datalogging functions store the current data so that current loss versus distance can be plotted.

Answer 34

pipeline current mapper

Question 35

is a process to assess a covered pipe segment for the presence of SCC primarily by systematically gathering and analyzing excavation data for pipe having similar operational characteristics and residing in a similar physical environment.

Answer 35

Stress Corrosion Cracking Direct Assessment (SCCDA)

Question 36

A calculation of the remaining strength of the pipe shows a predicted burst pressure less than the established maximum operating pressure at the location of the anomaly. Suitable remaining strength calculation methods

Answer 36

B31G

Question 37

remaining strength of pipeline

Answer 37

rstreng