A research guide to the structure of 49 CFR 195.452, paragraph by paragraph, with the citations a reviewer needs and the edition each was checked against.

Which text this guide reads.

The paragraph citations below were read against the eCFR current text of § 195.452, the in-force version of the section, and checked for this guide on 2026-09-13. Section 195.452 was last amended effective 2026-03-16, and the citations here reflect that in-force text. If you want a frozen, citable snapshot, the October 1, 2024 annual edition of 49 CFR 195.452 is the government print; it predates the 2026-03-16 amendment, so it is not the current text for any paragraph that amendment changed. Before you rely on any paragraph for a real segment, confirm the current text and its effective date in the eCFR: § 195.452 has been amended more than once. An edit date on this page is not a legal-currentness check, and this guide is not an applicability determination for any pipeline.

The question the section answers.

Section 195.452 sets out integrity management for hazardous liquid and carbon dioxide pipelines that could affect a high consequence area. The heading is "Pipeline integrity management in high consequence areas." The paragraphs below are its own structure, in order, with the citation for each so a reviewer can go straight to the source passage.

Which pipelines are covered - paragraph (a).

Paragraph (a) applies the section to each hazardous liquid and carbon dioxide pipeline that could affect a high consequence area, including any pipeline located in one, unless the operator effectively demonstrates by risk assessment that it could not affect the area. Appendix C to Part 195 provides guidance on the could-affect determination. Paragraph (a) then sorts covered pipelines into Category 1, Category 2 and Category 3 by whether they existed on May 29, 2001 and the operator's total mileage, with low-stress pipelines in rural areas handled under § 195.12. The high consequence area definition itself is at § 195.450, not in 195.452.

The written program and industry practice - paragraph (b).

Paragraph (b) requires each covered operator to develop and follow a written integrity management program by the dates in its tables (for example, Category 1 programs by March 31, 2002; Category 2 by February 18, 2003). Under § 195.452(b)(6), an operator must follow recognized industry practices unless the section specifies otherwise or the operator demonstrates that an alternative practice is supported by a reliable engineering evaluation and provides an equivalent level of public safety and environmental protection. When you review a program document, that "reliable engineering evaluation, equivalent protection" test at (b)(6) is the standard an alternative has to meet.

The baseline assessment plan - paragraph (c).

Paragraph (c) governs the written baseline assessment plan. Under § 195.452(c)(1)(i), the operator assesses line-pipe integrity by in-line inspection tool(s) for the range of relevant threats, and may use another method only where in-line inspection is impracticable for stated reasons. The alternative methods are set out in the same paragraph: pressure test under subpart E of Part 195 (c)(1)(i)(B), external corrosion direct assessment under § 195.588 (c)(1)(i)(C), or other technology that provides an equivalent understanding, which requires notice to the Office of Pipeline Safety 90 days beforehand (c)(1)(i)(D). An assessment run with an in-line inspection tool must comply with § 195.591, and the seam-integrity requirement in (c)(1)(i) points to the seam-factor definition at § 195.106(e).

When the baseline must be complete - paragraph (d).

Paragraph (d) sets the timing. For newly identified areas, § 195.452(d)(2) requires that when an operator obtains information showing an area has changed to meet the high consequence area definition, that area is incorporated into the baseline assessment plan within 1 year, and the baseline assessment of any segment that could affect the newly identified area is completed within 5 years of identification. Those two clocks - one year to incorporate, five years to assess - are a common review point.

Risk factors for the schedule - paragraph (e).

Paragraph (e) lists the risk factors an operator must consider in prioritizing segments for both baseline and continual assessment. The section says the operator must base the schedule on all risk factors that reflect the segment's risk conditions, and its list "includes, but is not limited to" prior assessment results, pipe attributes and seam type, leak and repair history, product transported, operating stress level, activities in the area, local environmental factors, geotechnical hazards, and physical support such as a cable suspension bridge. Appendix C provides further guidance on these factors.

The program's required elements - paragraph (f).

Paragraph (f) is the list a reviewer checks a program against. Section 195.452(f) requires, at minimum, each of eight written elements: a process to identify which segments could affect a high consequence area (f)(1); a baseline assessment plan meeting paragraph (c) (f)(2); an information analysis integrating all available integrity information (f)(3); criteria for remedial action (f)(4); a continual process of assessment and evaluation (f)(5); identification of preventive and mitigative measures (f)(6); methods to measure program effectiveness (f)(7); and a process for review of results by a qualified person (f)(8).

The information analysis - paragraph (g).

Paragraph (g) defines the information analysis: the operator must analyze all available information about the integrity of its entire pipeline and the consequences of a possible failure, and § 195.452(g)(1) lists the attributes to integrate (pipe diameter, wall thickness, grade and seam type; coating; maximum operating pressure and temperature; assessment and survey results; cracking findings; and more). Paragraph (g)(4) is explicit that storing the data in a geographic information system alone is not sufficient - the operator must analyze for interrelationships among the data. The data-integration phase-in dates are stated in (g) itself.

Addressing integrity issues - paragraph (h).

Paragraph (h) governs what the operator does with what it finds. "Discovery of a condition" is defined in § 195.452(h)(2), which requires the operator to obtain enough information to make that determination promptly, but no later than 180 days after an assessment, unless it can demonstrate that interval is impracticable and notifies PHMSA. The scheduling rules at (h)(4) set the categories every reviewer should know: immediate repair conditions (h)(4)(i), including metal loss greater than 80% of nominal wall; 60-day conditions (h)(4)(ii); and 180-day conditions (h)(4)(iii). Remaining-strength calculations reference ASME/ANSI B31G and PRCI PR-3-805 (R-STRENG), incorporated by reference at § 195.3.

Preventive and mitigative measures - paragraph (i).

Paragraph (i) requires measures to prevent and mitigate the consequences of a failure that could affect a high consequence area. Leak detection is its own requirement at § 195.452(i)(3): the operator must have a means to detect leaks and must evaluate and, as necessary, modify that means, considering length and size of the pipeline, product carried, proximity to the high consequence area, and other stated factors. Emergency flow restricting devices are addressed at (i)(4), and the rupture-mitigation requirements added for certain segments after April 10, 2023 cross-reference §§ 195.258, 195.260, 195.402, 195.418, 195.419 and 195.420.

The continual assessment process - paragraph (j).

Paragraph (j) is the ongoing cycle after the baseline. Section 195.452(j)(2) requires verifying the risk factors used to identify covered segments at least annually, not to exceed 15 months. Section 195.452(j)(3) requires five-year reassessment intervals, not to exceed 68 months, based on the risk the line pipe poses. The reassessment methods are listed at (j)(5) and mirror the baseline methods in paragraph (c).

Effectiveness, records and notifications - paragraphs (k) through (n).

Paragraph (k) requires methods to measure whether the program is effective. Paragraph (l) requires records that demonstrate compliance to be kept for the useful life of the pipeline, including the written program (l)(1)(i) and the documents supporting the decisions and analyses behind each element (l)(1)(ii). Paragraph (m) states how an operator notifies PHMSA. Paragraph (n) requires most covered pipelines to be modified to accommodate an instrumented internal inspection device by July 2, 2040, with its own rules for newly identified areas and for petitions under § 190.9.

Distinguish the regulation from the guidance.

Appendix C to Part 195 is guidance that the section points to in several paragraphs; it informs a determination but the binding requirement is the text of 195.452 itself. PHMSA interpretation letters and the Hazardous Liquid Integrity Management enforcement guidance have different roles again - they explain how the agency reads a paragraph, and they can quote older code text, but they do not replace the current regulation. When you hand a source to a client, keep the regulation, its appendix guidance, and any interpretation in separate entries with their editions and roles marked.

Check the source and date

Use the cited government regulation or case document to establish what it says. Check the relevant date, scope and later amendments before applying it. Related interpretation letters, guidance, summaries and case allegations have different roles; they do not all state a binding requirement.

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Researching 49 CFR 195.452: integrity management.