2026 Class Change Rule Fact Sheet
Rule Fact Sheet
Class locations are used in the natural gas Federal Pipeline Safety Regulations in a graded approach to provide conservative safety margins and safety standards commensurate with the potential consequences of pipeline incidents and associated population density near a pipeline. As class locations are defined with relation to the number of dwellings for human occupancy in the area, an onshore gas transmission pipeline's class location can change as the population living or working near a pipeline changes. An increase in population that results in a change in class location requires operators to confirm design factors and to recalculate the maximum allowable operating pressure (MAOP) of the pipeline. If a class location changes and the hoop stress corresponding to the established MAOP of a segment of pipeline is not commensurate with the MAOP of the newly determined class location, § 192.611 currently requires that the pipeline operator (1) lower the pipeline's MAOP to reduce stress levels in the pipe, (2) replace the existing pipe with pipe that has thicker walls or higher yield strength resulting in lower operating stress at the same MAOP, or (3) pressure test the pipeline at a higher test pressure.
The amended regulation creates a fourth option under § 192.611 giving gas transmission pipeline Operators a critical alternative to the costly and disruptive requirements of pressure reduction, re-testing, or replacing of pipe segments. A summary of the major regulatory provisions is provided in the table below:
| SUBJECT | FINAL RULE |
|---|---|
| Applicability |
Section 192.611(a)(4) authorizes an integrity management (IM) alternative for managing class location changes that affect certain eligible gas transmission line segments in Class 3 locations. |
| Eligibility |
Section 192.3 defines the eligible Class 3 segments that may use the IM alternative. That definition excludes segments that 1) contain bare pipe; 2) contain wrinkle bends; 3) have a longitudinal seam formed by lap welding or another method with a joint factor below 1.0; or 4) have experienced an in-service leak or rupture due to cracking on the segment or a pipe with similar characteristics within 5 miles. A segment that experiences an in-service rupture or leak from the pipe cannot continue using the IM alternative. |
| Subpart O Compliance |
An eligible Class 3 segment applying the IM alternative must be designated as a high consequence area and comply with the requirements in Subpart O. |
| Initial Programmatic Requirements |
An operator must comply with certain initial programmatic requirements within 24 months to use the IM alternative. Those requirements address: 1) integrity assessments and remediation, 2) pressure testing, 3) material records verification, 4) rupture mitigation valves, 5) cathodic protection and coating, and 6) depth of cover. An operator must also provide a notification to PHMSA. |
| Recurring Programmatic Requirements |
An operator must comply with certain recurring programmatic requirements to use the IM alternative. Those requirements address: 1) gas quality, 2) close interval surveys, 3) patrolling, 4) leak surveys, 5) line markers, 6) class location studies, 7) shorted casings, 8) exposed pipe and weld surface examinations, and 9) reassessments and remediation. |
| Other Requirements |
MAOP of a segment using the IM alternative may not exceed a hoop stress corresponding to 72 percent of SMYS for pipe with a Class 1 design factor or 60 percent of SMYS for pipe with a Class 2 design factor. An operator of an eligible Class 3 segment may use the IM alternative to restore a previously established MAOP after complying with certain Subpart K and initial programmatic requirements. |
Last updated: Thursday, January 22, 2026