27 terms — 2 defined directly in 49 CFR Parts 192 and 195, plus 25 operator-grade industry terms.
CFR-sourced definitions are parsed live from the regulation text and refresh on every CFR sync. Industry terms are curated from PHMSA, API, INGAA, and AGA usage. Scoped definitions (subpart- or section-specific) are planned for a future expansion.
Terms defined in §192.3, the definitions section of Part 192.
Any portion of the paved surface, including shoulders, of a designated interstate, other freeway, or expressway, as well as any other principal arterial roadway with 4 or more lanes, (See appendix G to this part), and that does not meet the definition of high consequence area, as defined in § 192.903.
A solution-mined salt cavern.
Operator-grade acronyms and concepts that appear throughout pipeline practice but are not defined directly in the CFR.
An order issued by PHMSA that imposes requirements on a pipeline operator. Can be a corrective action order after an incident, a consent agreement following enforcement, or an amendment to a special permit. Context determines the specific meaning.
Consensus technical standards developed by the American Petroleum Institute, many incorporated by reference into 49 CFR Parts 192 and 195. Common examples include API 1163 (in-line inspection), API 1160 (integrity management for hazardous liquid pipelines), API 5L (line pipe specification).
An emergency order issued by PHMSA under 49 CFR 190.233 requiring an operator to take specified corrective actions when a pipeline facility is determined to be hazardous. Usually issued after incidents; typically includes pressure restrictions and mandatory inspections.
A written program required under 49 CFR 192 Subpart P for operators of gas distribution pipelines. DIMP programs identify threats, assess and rank risks, and implement measures to address those risks. Distinct from transmission integrity management (TIMP) under Subpart O.
A four-step process (pre-assessment, indirect inspection, direct examination, post-assessment) used to assess external corrosion threats on a pipeline segment. One of the integrity assessment methods permitted under the integrity management regulations.
A statutorily chartered advisory committee that reviews and makes recommendations on proposed PHMSA rulemakings affecting natural gas pipeline safety. Membership draws from industry, state regulators, and public safety representatives. Meetings are public and on the record.
The regulatory mechanism by which external consensus standards (API, ASME, ANSI, etc.) acquire the force of law in the CFR. Listed in 49 CFR 192.7 and 195.3, IBR'd standards must be complied with as if written into the regulation itself.
Assessment methodology for internal corrosion, analogous in structure to ECDA but targeting internal threats. Used for dry gas systems (DG-ICDA), liquid petroleum systems (LP-ICDA), and wet gas systems (WG-ICDA). Not permitted for all pipeline types.
Inspection of a pipeline's internal surface using an instrumented tool (a "pig") that traverses the line during operation. Common tool types include magnetic flux leakage (MFL) for metal loss and ultrasonic tools for crack detection. Results feed integrity management decisions.
An operator's documented program for assessing and managing the integrity of pipeline segments in high consequence areas. Required under 49 CFR 192 Subpart O (gas transmission) and 195.452 (hazardous liquid). Programs address threat identification, assessment methods, risk analysis, and preventive/mitigative measures.
Formerly used interchangeably with "IVP" for the integrity verification requirements under the Mega Rule. Now less common — current references typically use "IVP." Also used in some operator documents to mean "Internal Qualification Program" for operator qualification under Subpart N.
The set of requirements in 49 CFR 192 that mandate reconfirmation of maximum allowable operating pressure (MAOP) for gas transmission pipelines using one of six specified methods. Added by the Gas Mega Rule; phased compliance deadlines run through 2035.
Statutorily chartered advisory committee that reviews and makes recommendations on proposed PHMSA rulemakings affecting hazardous liquid pipeline safety. Parallel to GPAC for liquid pipelines. Meetings are public and on the record.
A geographic area introduced by the Mega Rule (Phase 1) where a pipeline failure would have moderate — but not high — consequences to public safety. Triggers a subset of integrity management requirements less stringent than HCA but above general compliance.
Industry shorthand for PHMSA's omnibus 2019 rulemaking (RIN 2137-AE72) revising 49 CFR Part 192, published in three phases. Added MAOP reconfirmation (IVP), expanded integrity management to non-HCA moderate consequence areas, and updated gathering line definitions. Often referenced as "Mega Rule Part 1/2/3" for the three phases.
A formal PHMSA enforcement document issued under 49 CFR 190.207 alleging that an operator violated one or more pipeline safety regulations. Includes proposed civil penalties and proposed corrective actions. Operators have 30 days to respond and may contest allegations.
The regulatory program in 49 CFR 192 Subpart N (gas) and 195 Subpart G (liquid) requiring operators to qualify individuals who perform covered tasks on pipelines. Covers training, testing, evaluation, and reevaluation intervals for those tasks.
The U.S. Department of Transportation agency responsible for regulating pipeline safety (Office of Pipeline Safety) and hazardous materials transportation. Publishes and enforces 49 CFR Parts 190–199 for pipelines.
PHMSA's public-facing pipeline safety data portal (primis.phmsa.dot.gov). Hosts incident reports, annual reports, enforcement actions, and the pipeline mileage database. Many compliance professionals use "PRIMIS" and "PHMSA's public data" interchangeably.
A valve placed on certain gas transmission pipeline segments required by the Mega Rule to automatically or remotely isolate the segment within 30 minutes of a rupture. Spacing and placement requirements depend on pipe diameter and location class.
The computerized control system used by pipeline operators to remotely monitor and control pipeline operations — valves, pressures, flow rates, leak detection inputs. Referenced throughout 49 CFR 195 for hazardous liquid pipelines (sections 195.446 and related).
Assessment methodology specifically for stress corrosion cracking threats. Requires more specialized application than ECDA/ICDA because SCC is environmentally dependent on coating condition, soil chemistry, and operating stress levels.
The minimum yield strength (in psi) specified in the line pipe specification for a particular steel grade. Used throughout 49 CFR 192 and 195 to calculate maximum allowable operating pressure (MAOP) via the Barlow formula and design factor.
The integrity management program required for gas transmission pipelines under 49 CFR 192 Subpart O. Covers threat identification, baseline assessment, periodic reassessment, and preventive/mitigative measures for segments in HCAs (and, post-Mega-Rule, MCAs).
A high-authority PHMSA interpretation letter that establishes enforcement policy on a specific regulatory question. Treated as authoritative source guidance in audit and compliance contexts. Tracked in Kondwit's PolicyDocument model with source-authority hierarchy.