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1

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 pipeline segment. This process usually requires direct examination of the pipeline to confirm damage or absence of damage.

CDA (Confirmatory Direct Assessment)

2

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

Assessment

3

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

SCCDA (Stress Corrosion Cracking Direct Assessment)

4

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

Covered Segment

5

The DOT department that governs regulations related to the transportation and storage of hazardous materials.

PHMSA (Pipeline & Hazardous Material Safety Administration)

6

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

Direct Examination (DE)

7

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.

Indirect Inspection

8

A section or sections of a pipeline that have similar physical characteristics and operating history and in which the same indirect inspection tools are used.

ECDA Region

9

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

SMYS (Specified Minimum Yield Strength)

10

A section or sections 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.

ICDA Region

11

The maximum pressure at which a pipeline or segment of a pipeline may be operated under Part 192.

MAOP (Max. Allowable Operating Pressure)

12

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.

ROW (Right of Way)

13

The Office of Pipeline Safety, which is part of the Pipeline and Hazardous Materials Safety Administration, U.S. Department of Transportation.

OPS (Office of Pipeline Safety)

14

The radius of impact determined by the formula r = 0.69 x Root (pxd^2) , where ‘r’ is the radius (ft) of a circular area surrounding the point of failure, ‘p’ is the maximum allowable operating pressure (psi) in the pipeline segment, and ‘d’ is the nominal diameter (in) of the pipeline.

PIR ((Potential Impact Radius)

15

An integrity assessment method that utilizes a process to evaluate certain threats (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 theses areas, and post assessment evaluation.

Direct Assessment

16

A process to identify areas along the pipeline where fluid or other electrolyte introduced during normal operation or by an upset condition may reside. This process identifies the potential for corrosion caused by microorganisms, or fluid with CO2, O2, H2S or other contaminants present in the gas.

ICDA (Internal Corrosion Direct Assessment)

17

process that is used to evaluate the threat of external corrosion to the integrity of the pipe.

ECDA (External Corrosion Direct Assessment)

18

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

Class 1 Location

19

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

Class 2 Location

20

Any class location unit that has 46 or more buildings intended for human occupancy or an area where the pipeline lies within 100 yards of either a building or a small, well-defined area that is occupied by 20 or more persons on at least 5 days a week for 10 weeks in any 12-month period.

Class 3 Location

21

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

Class 4 Location

22

An area defined by certain Class locations or a potential impact radius that must be covered by an gas operator’s integrity management program.

HCA (High consequences Area)

23

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.

BAP (Baseline Assessment Plan)

24

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.

Integrity Management Program

25

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.

Integrity Management Plan

26

Software that calculates the remaining strength of corroded pipe. It utilizes a less conservative than the ASME standard.

RSTRENG

27

ASME standard used to determine the remaining strength of corroded pipe.

B31G

28

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.

Hydrotest

29

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

ACVG (Alternate Current Voltage Gradient)

30

The 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.

ILI (In-Line Inspection)