{"operation":"document","citation":"LAC 43:XIII §5109","title":"Appendix E―Guidance on Determining High Consequence Areas and on Carrying out Requirements in the Integrity Management Rule","source_type":"regulation","agency":"Louisiana Office of Conservation","status":"current","official":true,"published_on":null,"effective_on":null,"summary":"I. Guidance on Determining a High Consequence Area To determine which segments of an operator's transmission pipeline system are covered for purposes of the integrity management program requirements, an operator must identify the high consequence areas. An operator must use Method (1) or (2) from th","machine_formats":{"json":"https://regulus.evalyn.ai/document/la-lac-43-xiii-5109.json","markdown":"https://regulus.evalyn.ai/document/la-lac-43-xiii-5109.md"},"app_url":"https://regulus.evalyn.ai/document/la-lac-43-xiii-5109","source_url":"https://www.doa.la.gov/doa/osr/louisiana-administrative-code/","body":"I. Guidance on Determining a High Consequence Area\n\nTo determine which segments of an operator's transmission pipeline system are covered for purposes of the integrity management program requirements, an operator must identify the high consequence areas. An operator must use Method (1) or (2) from the definition in §3303 to identify a high consequence area. An operator may apply one method to its entire pipeline system, or an operator may apply one method to individual portions of the pipeline system. (Refer to Figure E.I.A for a diagram of a high consequence area).\n\nII.Guidance on Assessment Methods and Additional Preventive and Mitigative Measures for Transmission Pipelines\n\n1. Table E.II.1 gives guidance to help an operator implement requirements on additional preventive and mitigative measures for addressing time dependent and independent threats for a transmission pipeline operating below 30 percent SMYS not in an HCA (i.e., outside of potential impact circle) but located within a Class 3 or Class 4 Location.\n\n2. Table E.II.2 gives guidance to help an operator implement requirements on assessment methods for addressing time dependent and independent threats for a transmission pipeline in an HCA.\n\n3. Table E.II.3 gives guidance on preventative and mitigative measures addressing time dependent and independent threats for transmission pipelines that operate below 30 percent SMYS, in HCAs.\n\nTable E.II.1: Preventative and Mitigative Measures for Transmission Pipelines Operating below 30 Percent SMYS Not in an HCA but in a Class 3 or Class 4 Location\n\n(Column 1)\n\nThreat\n\nExisting Subpart 3 Requirements\n\n(Column 4)\n\nAdditional (to Subpart 3 requirements)\n\nPreventive and Mitigative Measures\n\n(Column 2)\n\nPrimary\n\n(Column 3)\n\nSecondary\n\nExternal Corrosion\n\n2107(Gen. Post 1971)\n\n2109(Gen. Pre1971)\n\n2111(Examination)\n\n2113(Ext. coating)\n\n2115(CP)\n\n2117(Monitoring)\n\n2119(Elect isolation)\n\n2121Test stations)\n\n2123(Test leads)\n\n2125(Interference)\n\n2131(Atmospheric)\n\n2133-(Atmospheric)\n\n2137(Remedial)\n\n2905(Patrol)\n\n2906(Leak survey)\n\n2911 (Repairgen.)\n\n2917(Repairperm.)\n\n2703(Gen Operation)\n\n2713(Surveillance)\n\nFor Cathodically Protected Transmission Pipeline:\n\nPerform semi-annual leak surveys.\n\nFor Unprotected Transmission Pipelines or for Cathodically Protected Pipe where Electrical Surveys are Impractical:\n\nPerform quarterly leak surveys\n\nInternal Corrosion\n\n2127(Gen IC),\n\n2129(IC monitoring)\n\n2137(Remedial),\n\n2905(Patrol)\n\n2906(Leak survey),\n\n2911-(Repair gen.)\n\n2917(Repair perm.)\n\n703(A)(Materials)\n\n2703(Gen Operation)\n\n2713(Surveillance)\n\nPerform semiannual leak surveys.\n\n3rd Party Damage\n\n903(Gen. Design),\n\n911(Design factor)\n\n1717(Hazard prot),\n\n1727(Cover)\n\n2714(Dam. Prevent),\n\n2716(Public education)\n\n2905(Patrol),\n\n2907(Line markers)\n\n2911-(Repair gen.),\n\n2917(Repair perm.)\n\n2715(Emerg. Plan)\n\nParticipation in state onecall system,\n\nUse of qualified operator employees and contractors to perform marking and locating of buried structures and in direct supervision of excavation work, AND\n\nEither monitoring of excavations near operator's transmission pipelines, or bimonthly patrol of transmission pipelines in class 3 and 4 locations. Any indications of unreported construction activity would require a follow up investigation to determine if mechanical damage occurred.\n\nTable E.II.2 Assessment Requirements for Transmission Pipelines in HCAs (Reassessment intervals are maximum allowed.)\n\nReAssessment Requirements (see Note 3)\n\nAt or above 50 Percent SMYS\n\nAt or above 30 Percent SMYS\n\nup to 50 Percent SMYS\n\nBelow 30 Percent SMYS\n\nBaseline Assessment Method (see Note 3)\n\nMax Re-Assessment Interval\n\nAssessment Method\n\nMax Re-Assessment Interval\n\nAssessment Method\n\nMax Re-Assessment Interval\n\nAssessment Method\n\nPressure Testing\n\n7\n\nCDA\n\n7\n\nCDA\n\nOngoing\n\nPreventative & Mitigative (P&M) Measures (see Table E.II.3), (see Note 2)\n\n10\n\nPressure Test or ILI or DA\n\nRepeat inspection cycle every 10 years\n\n15 (see Note 1)\n\nPressure Test or ILI or DA (see Note 1)\n\nRepeat inspection cycle every 15 years\n\n20\n\nPressure Test or ILI or DA\n\nRepeat inspection cycle every 20 years\n\nIn-Line Inspection\n\n7\n\nCDA\n\n7\n\nCDA\n\nOngoing\n\nPreventative & Mitigative (P&M) Measures (see Table E.II.3), (see Note 2)\n\n10\n\nILI or DA or Pressure Test\n\nRepeat inspection cycle every 10 years\n\n15 (see Note 1)\n\nILI or DA or Pressure Test (see Note 1)\n\nRepeat inspection cycle every 15 years\n\n20\n\nILI or DA or Pressure Test\n\nRepeat inspection cycle every 20 years\n\nDirect Assessment\n\n7\n\nCDA\n\n7\n\nCDA\n\nOngoing\n\nPreventative & Mitigative (P&M) Measures (see Table E.II.3), (see Note 2)\n\n10\n\nDA or ILI or Pressure Test\n\nRepeat inspection cycle every 10 years\n\n15 (see Note 1)\n\nDA or ILI or Pressure Test (see Note 1)\n\nRepeat inspection cycle every 15 years\n\n20\n\nDA or ILI or Pressure Test\n\nRepeat inspection cycle every 20 years\n\nNote 1: Operator may choose to utilize CDA at year 14, then utilize ILI, Pressure Test, or DA at year 15 as allowed under ASME B31.8S\n\nNote 2: Operator may choose to utilize CDA at year 7 and 14 in lieu of P&M\n\nNote 3: Operator may utilize \"other technology that an operator demonstrates can provide an equivalent understanding of the condition of line pipe\"\n\nTable E.II.3\n\nPreventative and Mitigative Measures addressing Time Dependent and Independent Threats for Transmission Pipelines that Operate below 30 Percent SMYS, in HCAs\n\nThreat\n\nExisting Subpart 3 Requirements\n\nAdditional (to Subpart 3 requirements) Preventive and Mitigative Measures\n\nPrimary\n\nSecondary\n\nExternal Corrosion\n\n2107(Gen. Post 1971)\n\n2109(Gen. Pre1971)\n\n2111(Examination)\n\n2113(Ext. coating)\n\n2115(CP)\n\n2117(Monitoring)\n\n2119(Elect isolation)\n\n2121Test stations)\n\n2123(Test leads)\n\n2125(Interference)\n\n2131(Atmospheric)\n\n2133(Atmospheric)\n\n2137(Remedial)\n\n2905(Patrol)\n\n2906(Leak survey)\n\n2911-(Repairgen.)\n\n2917(Repairperm.)\n\n2703(Gen Oper)\n\n2713(Surveil)\n\nFor Cathodically Protected Trmn. Pipelines\n\nPerform an electrical survey (i.e., indirect examination tool/method) at least every seven years. Results are to be utilized as part of an overall evaluation of the CP system and corrosion threat for the covered segment. Evaluation shall include consideration of leak repair and inspection records, corrosion monitoring records, exposed pipe inspection records, and the pipeline environment.\n\nFor Unprotected Trmn. Pipelines or for Cathodically Protected Pipe where Electrical Surveys are Impracticable\n\nConduct quarterly leak surveys AND\n\nEvery 1 1/2 years, determine areas of active corrosion by evaluation of leak repair and inspection records, corrosion monitoring records, exposed pipe inspection records, and the pipeline environment.\n\nInternal Corrosion\n\n2127(Gen IC)\n\n2129(IC monitoring)\n\n2137(Remedial)\n\n2905(Patrol)\n\n2906(Leak survey)\n\n2911-(Repairgen.)\n\n2917(Repairperm.)\n\n703(A)(Materials)\n\n2703(Gen Oper)\n\n2713(Surveil)\n\nObtain and review gas analysis data each calendar year for corrosive agents from transmission pipelines in HCAs,\n\nPeriodic testing of fluid removed from pipelines. Specifically, once each calendar year from each storage field that may affect transmission pipelines in HCAs, AND\n\nAt least every seven years, integrate data obtained with applicable internal corrosion leak records, incident reports, safety related condition reports, repair records, patrol records, exposed pipe reports, and test records.\n\n3rd Party Damage\n\n903(Gen. Design)\n\n911(Design factor)\n\n1717(Hazard prot)\n\n1727(Cover)\n\n2714(Dam. Prevent)\n\n2716(Public educat)\n\n2905(Patrol)\n\n2909(Line markers)\n\n2911-(Repairgen.)\n\n2917(Repairperm.)\n\n2715(Emerg Plan)\n\nParticipation in state onecall system,\n\nUse of qualified operator employees and contractors to perform marking and locating of buried structures and in direct supervision of excavation work, AND\n\nEither monitoring of excavations near operator's transmission pipelines, or bimonthly patrol of transmission pipelines in HCAs or Class 3 and 4 locations. Any indications of unreported construction activity would require a follow up investigation to determine if mechanical damage occurred.\n\nAUTHORITY NOTE: Promulgated in accordance with R.S. 30:501 et seq.\n\nHISTORICAL NOTE: Promulgated by the Department of Natural Resources, Office of Conservation, Pipeline Division, LR 30:1289 (June 2004), amended LR 31:690 (March 2005).","truncated":false,"body_characters":8313}