Louisiana Administrative Code › Title 43 - NATURAL RESOURCES › Part XIII - Office of Conservation-Pipeline Safety › Subpart 3 - Transportation of Natural Gas or Other Gas by Pipeline: Minimum Safety Standards [49 CFR Part 192] › Chapter 33 - Gas Transmission Pipeline Integrity Management [49 CFR Part 192 Subpart O] › Section XIII-3335 - What Additional Preventive and Mitigative Measures Must an Operator Take? [49 CFR 192.935]

Current through Register Vol. 50, No. 6, June 20, 2024
A. General
				  Requirements. An operator must take additional measures beyond those already
				  required by this Subpart to prevent a pipeline failure and to mitigate the
				  consequences of a pipeline failure in a high consequence area. An operator must
				  base the additional measures on the threats the operator has identified to each
				  pipeline segment (see §3317). An operator must conduct, in accordance with
				  one of the risk assessment approaches in ASME/ANSI B31.8S (incorporated by
				  reference, see §507), Section 5, a risk analysis of its pipeline to
				  identify additional measures to protect the high consequence area and enhance
				  public safety. Such additional measures include, but are not limited to,
				  installing automatic shut-off valves or remote control valves, installing
				  computerized monitoring and leak detection systems, replacing pipe segments
				  with pipe of heavier wall thickness, providing additional training to personnel
				  on response procedures, conducting drills with local emergency responders and
				  implementing additional inspection and maintenance programs [
				49
				  CFR 192.935(a)].
B. Third Party Damage and Outside Force
				  Damage [
				49
				  CFR 192.935(b)]
1. Third Party Damage. An operator must
				  enhance its damage prevention program, as required under
				  §2714 of this
				  Subpart, with respect to a covered segment to prevent and minimize the
				  consequences of a release due to third party damage. Enhanced measures to an
				  existing damage prevention program include, at a minimum [
				49
				  CFR 192.935(b)(1)]:
a. using qualified personnel (see §3315)
				  for work an operator is conducting that could adversely affect the integrity of
				  a covered segment, such as marking, locating, and direct supervision of known
				  excavation work; [
				49
				  CFR
				  192.935(b)(1)(i)]
b. collecting in a central database
				  information that is location specific on excavation damage that occurs in
				  covered and non covered segments in the transmission system and the root cause
				  analysis to support identification of targeted additional preventative and
				  mitigative measures in the high consequence areas. This information must
				  include recognized damage that is not required to be reported as an incident
				  under Subparts 1 and 2; [
				49
				  CFR 192.935(b)(1)(ii)
				  ]
c. participating in one-call
				  systems in locations where covered segments are present; [
				49
				  CFR 192.935(b)(1)(iii)
				  ]
d. monitoring of excavations
				  conducted on covered pipeline segments by pipeline personnel. If an operator
				  finds physical evidence of encroachment involving excavation that the operator
				  did not monitor near a covered segment, an operator must either excavate the
				  area near the encroachment or conduct an above ground survey using methods
				  defined in NACE SP0502 (incorporated by reference, see §507). An operator
				  must excavate, and remediate, in accordance with ANSI/ASME B31.8S and
				  §3333 any
				  indication of coating holidays or discontinuity warranting direct examination [
				49
				  CFR 192.935(b)(1)(iv)
				  ].