Gas utilities cannot wait for the pipe records rule

Across the US, gas utilities operate distribution pipe laid decades ago. For much of it, staff cannot prove the material, thickness, or strength. They may find an answer in a database, but the source document may be missing, incomplete, or wrong.

Federal regulators have proposed requiring operators to hold traceable, verifiable, and complete records for pipe characteristics that affect pressure control. They withdrew the final version during the January 2025 regulatory freeze. As of 2026, the proposal is stalled and is not law.

Operators may reasonably want to avoid spending against an uncertain requirement. They still fall into a trap when they wait because they cannot recreate decades of missing proof on a deadline. Records teams can recover surviving documents, but crews can often establish what is buried only when they expose the pipe. Once a crew closes a trench without documenting the pipe, the operator may lose that opportunity for years.

Where the proposed rule stands

Federal officials have given operators room to wait on formal compliance. The Pipeline and Hazardous Materials Safety Administration (PHMSA) published the proposal on September 7, 2023, and industry participants commonly call it the gas distribution “mega rule.” PHMSA does not use that name. Agency staff prepared a final version, but federal officials withdrew it under the 2025 regulatory freeze.

PHMSA may revise the proposal, finalize it, or leave it stalled. Under the proposal, operators would have to identify missing records, create them where possible, and retain them for the life of the pipe. PHMSA already applies the same records standard to gas transmission, and state inspectors who audit most distribution systems already examine the quality of operators' records.

PHMSA will decide when any new federal duty takes effect. Crews can close legacy gaps only as field activity gives them access to buried assets, so operators that postpone the work also give up verification opportunities.

What traceable, verifiable, and complete means

An operator needs proof tied to each pipe segment. Inspectors describe that standard as traceable, verifiable, and complete, or TVC.

For a traceable attribute, staff can link the value to an original source for one segment, such as a mill certificate, purchase order, or signed as-built drawing. Inspectors cannot accept a utility's general practice of installing Grade X42 pipe as proof for one location. Staff verify the attribute with separate evidence, such as a pressure-test chart and the corresponding field log. They complete the file with the required details, signature, date, and approval.

Records staff can use software to organize evidence, but they cannot use it to manufacture provenance. When they scan a flawed as-built, they make the flaw easier to find without proving a pipe's grade or wall thickness. An inspector who sees a value in the geographic information system can still ask where it came from and how the operator confirmed it.

Operators also face consequences under existing rules when they cannot support records that inspectors already require. A state or federal inspector can issue a notice of probable violation, propose a compliance order, and seek civil penalties. In 2026, inspectors can still seek up to $272,926 for each violation per day and $2,729,245 for a related series. Staff cannot create valid source evidence after an inspector asks for it.

Verifying buried pipe in the field

Records teams eventually reach the point where no more documents can be found. They can reconcile systems and identify conflicts, but they cannot prove the material, seam type, or wall thickness of buried pipe from an unsupported entry.

Crews can establish those attributes when they expose the asset during a repair, replacement, defect investigation, or planned inspection hole. They must identify the exact segment, record what they observe, and attach the evidence before they close the job. If crews cannot reach the pipe, engineers can use the most conservative credible attribute to calculate the maximum allowable operating pressure, or MAOP. Engineers then protect safety by running the pipe at a lower pressure, leaving the utility with less operating headroom.

Crews can verify buried pipe only as fieldwork exposes it. PHMSA gave affected transmission operators until July 3, 2028, to reconfirm records for half of the mileage in scope and until July 2, 2035, to finish the rest. Distribution operators manage a far larger network of mains and service lines. Even with a generous compliance period, records teams would still depend on excavations and the pace of planned work.

Operators therefore cannot treat field verification as a project to launch after PHMSA publishes a final rule. By then, crews may have opened and closed thousands of useful trenches without capturing the evidence.

Records and public safety

Crews and engineers rely on accurate records before any inspector arrives. In September 2018, a construction crew on the Columbia Gas distribution system in Massachusetts disconnected an old main during a replacement project. The field engineer could not find the regulator sensing-line locations in the engineering records, and a professional engineer had not reviewed the abandonment package.

When the crew depressurized the old main, the regulators allowed high-pressure gas into the low-pressure system. Residents across Lawrence, Andover, and North Andover faced fires and explosions that killed one person, injured many others, and destroyed homes. The National Transportation Safety Board found weak engineering management alongside incomplete records. Merrimack Valley was an engineering-review failure and a records-completeness failure.

Investigators found a related problem after the 2010 San Bruno transmission-pipeline explosion. They read company records that described the failed pipe as Grade X42 without a longitudinal seam, then found seam-welded sections with different characteristics. Engineers could not manage the pipe's integrity effectively because staff had recorded the wrong attributes.

Operators should not treat every missing document as evidence of an imminent accident. Their engineers still need source-backed facts to design work, set pressure, and assess risk. PHMSA drew on this safety history when it developed the distribution proposal, and operators still face the same problem while the proposal remains stalled.

Continuous verification during fieldwork

Operators that start now can use everyday fieldwork to reduce the backlog. Records staff can reconcile the geographic information system, asset-management system, and document store into one authoritative record for each asset. They can then separate conflicts that staff can resolve from gaps that require a crew to inspect the pipe.

Crews should capture material, dimensions, location, and identifying marks whenever they expose a pipe. Project teams should attach source documents when they install new assets and use component barcodes where appropriate. Training managers should also connect each operator qualification, or OQ record, to the named person, safety-critical task, evaluation method, and date.

Leaders cannot resolve decades of uncertainty at once. They can use the distribution integrity management program to prioritize areas where a wrong assumption could have the greatest consequence. They can also track which assets have source-backed attributes, which use conservative assumptions, and which planned jobs give crews the next opportunity to verify them.

Starting before PHMSA acts

PHMSA may never finalize the proposal in its current form. Operators will still run the same buried assets and make the same engineering decisions. They can preserve reliable evidence for every new installation and improve legacy records whenever crews expose pipe.

Utilities that wait for a final rule will begin a decade-long field program years after they could have started. Utilities that treat records as continuous fieldwork now will be ready whenever PHMSA acts.