External Corrosion Control: Monitoring [49 CFR 192.465]

(A)A. Each pipeline that is under cathodic protection must be tested at least once each calendar year, but with intervals not exceeding 15 months, to determine whether the cathodic protection meets the requirements of §2115. However, if tests at those intervals are impractical for separately protected short sections of mains or transmission lines, not in excess of 100 feet (30 meters), or separately protected service lines, these pipelines may be surveyed on a sampling basis. At least 10 percent of these protected structures, distributed over the entire system must be surveyed each calendar year, with a different 10 percent checked each subsequent year, so that the entire system is tested in each 10-year period. [49 CFR 192.465(a)]#

(B)B. Cathodic protection rectifiers and impressed current power sources must be periodically inspected as follows: [49 CFR 192.465(b)]#

(1)1. Each cathodic protection rectifier or impressed current power source must be inspected 6 times each calendar year, but with intervals not exceeding 2 1/2 months between inspections, to ensure adequate amperage and voltage levels needed to provide cathodic protection are maintained. This may be done either through remote measurement or through an onsite inspection of the rectifier. [49 CFR 192.465(b)(1)]#

(2)2. After January 1, 2022, each remotely inspected rectifier must be physically inspected for continued safe and reliable operation at least once each calendar year, but with intervals not exceeding 15 months. [49 CFR 192.465(b)(2)]#

(C)C. Each reverse current switch, each diode, and each interference bond whose failure would jeopardize structure protection must be electrically checked for proper performance six times each calendar year, but with intervals not exceeding two and one-half months. Each other interference bond must be checked at least once each calendar year, but with intervals not exceeding 15 months. [49 CFR 192.465(c)]#

(D)D. Each operator must promptly correct any deficiencies indicated by the inspection and testing required by Subsections A - C of this Section. Remedial action must be completed promptly, but no later than the earliest of the following: prior to the next inspection or test interval or within 90 days from the date the deficiency was discovered. The Commissioner may approve an alternative time period depending on the nature of the deficiency. [49 CFR 192.465(d)]#

(E)E. After the initial evaluation required by of §2107.B and C and §2109.B, each operator must, not less than every 3 years at intervals not exceeding 39 months, reevaluate its unprotected pipelines and cathodically protect them in accordance with this Chapter in areas in which active corrosion is found. The operator must determine the areas of active corrosion by electrical survey. However, on distribution lines and where an electrical survey is impractical on transmission lines, areas of active corrosion may be determined by other means that include review and analysis of leak repair and inspection records, corrosion monitoring records, exposed pipe inspection records, and the pipeline environment. [49 CFR 192.465(e)]#

(F)F. An operator must determine the extent of the area with inadequate cathodic protection for onshore gas transmission pipelines where any annual test station reading (pipe-to-soil potential measurement) indicates cathodic protection levels below the required levels in appendix D to this Part. [49 CFR 192.465(f)]#

(1)1. Gas transmission pipeline operators must investigate and mitigate any non-systemic or location-specific causes. Remedial action must be in accordance with Subsection D of this Section. [49 CFR 192.465(f)(1)]#

(2)2. To address systemic causes, an operator must conduct close interval surveys in both directions from the test station with a low cathodic protection reading at a maximum interval of approximately 5 feet or less. An operator must conduct close interval surveys unless it is impractical based upon geographical, technical, or safety reasons. An operator must complete close interval surveys required by this section with the protective current interrupted unless it is impractical to do so for technical or safety reasons. An operator must remediate areas with insufficient cathodic protection levels, or areas where protective current is found to be leaving the pipeline. For onshore gas transmission pipelines, each operator must develop a remedial action plan and apply for any necessary permits within six months of completing the inspection or testing that identified the deficiency. Remedial action must be completed promptly, but no later than the earliest of the following: prior to the next inspection or test interval required by this section; within 1 year, not to exceed 15 months, of the inspection or test that identified the deficiency; or as soon as practicable, not to exceed 6 months, after obtaining any necessary permits. An operator must confirm the restoration of adequate cathodic protection following the implementation of remedial actions undertaken to mitigate systemic causes of external corrosion. [49 CFR 192.465(f)(2)]#

AUTHORITY NOTE: Promulgated in accordance with R.S. 30:501 et seq.#

HISTORICAL NOTE: Promulgated by the Department of Natural Resources, Office of Conservation, LR 9:236 (April 1983), amended LR 10:528 (July 1984), LR 27:1545 (September 2001), LR 30:1253 (June 2004), LR 38:116 (January 2012), LR 47:1144 (August 2021), LR 50:1250 (September 2024), amended by the Department of Conservation and Energy, Office of Enforcement, LR 51:1833 (November 2025).#