How PHMSA’s Final Rule Affects Class Location Requirements for Gas Transmission Operators

PHMSA has issued a Final Rule updating how operators may respond to gas transmission pipeline class location changes under 49 CFR Part 192 (Federal Register Document No. 2026-00566). The rule is especially significant for operators managing pipelines that transition into Class 3 locations due to development and population growth.

The update introduces a new compliance pathway that gives operators more flexibility but with added integrity management obligations. Here’s what it means and what you should be doing now to maintain compliance.

A New Option for Class 3 Location Changes

Historically, when a pipeline segment changed to a Class 3 location, operators typically complied by reducing MAOP, pressure testing or replacing or upgrading pipe under §192.611.

PHMSA’s Final Rule adds a new, codified compliance option at §192.611(a)(4). Known as the Integrity Management (IM) Alternative, it allows eligible operators to confirm and maintain MAOP for certain Class 3 change segments without immediately lowering pressure or replacing pipe, provided enhanced integrity management requirements are met.

How the IM Alternative Works

Under §192.611(a)(4), an operator may address a Class 3 location change by:

• Applying Subpart O (Integrity Management) requirements, and
• Implementing additional initial and recurring controls specific to this rule

PHMSA has also clarified that any segment managed under this option is treated as a High Consequence Area (HCA) for Integrity Management purposes, regardless of its prior classification.

Eligibility

To use the IM Alternative, a segment must qualify as an Eligible Class 3 segment, meaning it must be in a Class 3 location (or newly reclassified as Class 3) and capable of assessment using an instrumented in-line inspection (ILI) tool.

PHMSA also defines the Eligible Class 3 inspection area, which includes not just the Class 3 segment itself but the full ILI-inspectable run between the nearest launcher and receiver.

A segment is not eligible if it includes any of the following:

• Bare pipe
• Wrinkle bends
• Lap-weld seam pipe
• Pipe with a longitudinal joint factor less than 1.0
• Any history of an in-service leak or rupture due to cracking (pipe body, seam or girth weld) on the segment or on similar pipe within five miles

If any disqualifier is present, the IM Alternative cannot be used.

Important Clarification for Previously Addressed Segments

PHMSA’s Rule clarifies that segments previously brought into compliance using traditional Class 3 methods, including MAOP reductio, may later be re-evaluated for eligibility under §192.611(a)(4).

If the segment qualifies and the operator completes all required initial program elements, MAOP may potentially be restored. This creates a new opportunity for operators to reassess past Class 3 changes.

The Tradeoff: Flexibility in Exchange for Enhanced Controls

The IM Alternative offers flexibility, but it is not a free pass.

What You Get

• The ability to confirm and maintain MAOP for an Eligible Class 3 segment
• Avoidance of immediate pressure reduction, pressure testing or pipe replacement

What PHMSA Expects in Return

Operators electing §192.611(a)(4) must:

• Treat the segment as an Integrity Management segment under Subpart O
• Complete initial program requirements by March 16, 2028 or within 24 months of the class location change, whichever is later
• Implement enhanced recurring requirements, including:
  • Monthly patrols (no more than 45 days apart)
  • Leak surveys four times per year (no more than 4.5 months apart)
  • Annual class location studies
  • Prescriptive corrosion control and CIS requirements
  • Enhanced marker, casing and crack NDE controls
• Maintain extensive records, including life-of-pipe retention for compliance actions
• Notify PHMSA of election and implementation

In plain terms: maintaining MAOP is allowed, but only with significantly increased surveillance, integrity controls and documentation in higher-population areas.

Notification: When and What to Submit

If you address a Class 3 change using traditional methods under §192.611, no new notification requirement is created by this rule. Standard compliance records apply. If you elect the IM Alternative, notification to PHMSA is required.

At a minimum, the notification should include:

• Identification of the affected pipeline segment (system or line name, endpoints and mileposts or stationing)
• Confirmation that the segment experienced a Class 3 location change
• A statement electing compliance under §192.611(a)(4)
• The basis for eligibility (ILI-capable with no disqualifying conditions)
• The planned schedule for completing initial program requirements
• A point of contact for follow-up

What Operators Should Do Now

This Final Rule creates new flexibility, but it also raises the bar for integrity management. Early evaluation and planning will be critical to making informed, defensible compliance decisions. Operators should:

• Inventory recent and anticipated Class 3 location changes
• Screen segments for eligibility and disqualifiers
• Evaluate whether maintaining MAOP justifies the added IM obligations
• Review prior Class 3 change segments for potential re-evaluation
• Align ILI, IM and compliance programs with the new requirements
• Prepare notification and documentation processes if electing the IM Alternative