Appendix E to Part 192 - Guidance on determining high consequence areas and integrity management

Current as of source date Government source

Arkansas Public Service CommissionOfficial agency material

APPENDIX E TO PART 192 - GUIDANCE ON DETERMINING HIGH CONSEQUENCE AREAS AND ON CARRYING OUT REQUIREMENTS IN THE INTEGRITY MANAGEMENT RULE 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 the definition in § 192.903 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.1.A for a diagram of a high consequence area). Determining High Consequence Area School ABC Pipeline HCA Figure E.l.A II. Guidance on Assessment Methods and Additional Preventive and Mitigative Measures for Transmission Pipelines#

(a)Table E.11.1 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% SMYS not in an HCA (i.e. outside of potential impact circle) but located within a Class 3 or Class 4 Location.#

(b)Table E.11.2 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.#

(c)Table E.11.3 gives guidance on preventative & mitigative measures addressing time dependent and independent threats for transmission pipelines that operate below 30% SMYS, in HCAs. Table E.II.1 Preventive and Mitigative Measures for Transmission Pipelines Operating Below 30% SMYS not in an HCA but in a Class 3 or Class 4 Location (Column 1) Threat Existing 192 Requirements (Column 4) Additional (to 192 requirements) Preventive and Mitigative External Corrosion…….. 455-(Gen. Post 1971), 457-(Gen. Pre-1971). 459-(Examination), 461-(Ext. coating). 463-(CP), 465-(Monitoring). 467-(Elect isolation), (469-Test stations). 471-(Test leads), 473- (Interference). 479-(Atmospheric), 481- (Atmospheric). 485-(Remedial), 705-(Patrol). 706-(Leak survey), 711 -(Repair-gen.) 717-(Repair-perm.) ……. 603 - (Gen Operation)…… 613 - (Surveillance)………… …………………………… ….. • For Cathodically Protected Transmission Pipeline: • Perform semi-annual leak surveys. • For Unprotected Transmission Pipelines or for Cathodically Protected Pipe where Electrical Surveys are Impractical: • Perform quarterly leak surveys Internal Corrosion 475-(Gen IC), 477-(IC monitoring). 485-(Remedial), 705-(Patrol). 706-(Leak survey), 711-(Repair- gen.). 717-(Repair - perm.). 53(a)-(Materials). 6 0 3 - ( G e n. O p e r ' n). 613-(Surveillance). • Perform quarterly leak surveys. Perform semi-annual leak surveys. 103-(Gen. Design), 111-(Design factor). •Participation in state one-call system, 317-(Hazard prot), 327-(Cover). 3rd Party Damage 614-(Dam. Prevent), 616-(Public education). 615 (Emerg. Plan) •Use of qualified operator employees and contractors to perform marking and locating of buried structures and in direct supervision of excavation work, AND 705-(Patrol), 707-(Line markers). 711 (Repair-gen.), 717-(Repair- perm.). •Either monitoring of excavations near operator's transmission pipelines, or bi-monthly 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. Table E.II.2 Assessment Requirements for Transmission Pipelines in HCAs (Re-assessment intervals are maximum allowed) [table on next page] Re-Assessment Requirements (see Note 3) At or above 50% SMYS At or above 30% SMYS Below 30% SMYS Baseline Assessment Method Max Re-Assessment Interval Assessment Method (see Note 3) Max Re- Assessment Interval Assessment Method Max Re-Assessment Interval Assessment Method 7 CDA 7 CDA 10 Pressure Test or ILI or DA Ongoing Preventative & Mitigative (P&M) Measures (see Table E.II.3), (see Note 2) Pressure Testing 15 (see Note 1) Repeat inspection cycle every 10 years Pressure Test or ILI or DA (see Note 1) Repeat inspection cycle every 15 years 20 Pressure Test or ILI or DA Repeat inspection cycle every 20 years 7 CDA 7 CDA 10 ILI or DA or Pressure Test Ongoing Preventative & Mitigative (P&M) Measures (see Table E.II.3), (see Note 2) In-Line Inspection 15 (see Note 1) Repeat inspection cycle every 10 years ILI or DA or Pressure Test (see Note 1) Repeat inspection cycle every 15 years 20 ILI or DA or Pressure Test Repeat inspection cycle every 20 years 7 CDA 7 CDA Ongoing Preventative & Mitigative (P&M) Measures (see Table E.II.3), (see Note 2) 10 Direct DA or ILI or Pressure Test Assessment 15 (see Note 1) DA or ILI or Pressure Test (see Note 1) Repeat inspection cycle every 10 years Repeat inspection cycle every 15 years 20 DA or ILI or Pressure Test Repeat inspection cycle every 20 years Note 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. Note 2: Operator may choose to utilize CDA at year 7 and 14 in lieu of P&M. Note 3: Operator may utilize "other technology that an operator demonstrates can provide an equivalent understanding of the condition of line pipe." Table E.II.3 Preventative & Mitigative Measures addressing Time Dependent and Independent Threats for Transmission Pipelines that Operate Below 30% SMYS, in HCAs Existing 192 Requirements Additional (to 192 requirements) Preventive & Threat Mitigative Measures Primary Secondary External Corrosion 455 - (Gen. Post 1971) 457 - (Gen. pre1971) 459 -#

(Examination)461 - (Ext. coating) 463 -#

(CP)465 -#

(Monitoring)467 - (Elect isolation) 603 - (Gen Oper) 613 -#

(Surveil)For Cathodically protected Trmn. Pipelines •Perform an electrical survey (i.e. indirect examination tool/method) at least every 7 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 ispection records, corrosion monitoring records, exposed pipe inspection records, and the pipeline environment. External Corrosion 469 - (Test stations) 471 - (Test leads) 473 -#

(Interference)479 -#

(Atmospheric)481 -#

(Atmospheric)485 -#

(Remedial)705 -#

(Patrol)706 - (Leak survey) 711 - (repair - gen.) 717 - (Repair perm.) For Unprotected Trmn. Pipelines or for Cathodically protected Pipe where Electrical Surveys are Impracticable •Conduct quarterly leak surveys AND •Every 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. Internal Corrosion 475 - (Gen IC) 477 - (IC monitoring) 485 -#

(Remedial)705 -#

(Patrol)706 - (Leak survey) 711 - (repair - gen.) 717 - (Repair perm.) 53#

(a)-#

(Materials)603 - (Gen Oper) 613 -#

(Surveil)•Obtain and review gas analysis data each calendar year for corrosive agents from transmission pipelines in HCAs, •Periodic testing of fluid removed from pipelines. Specifically, once each calendar year from each storage field that may affect transmission pipelines in HCAs, AND •At least every 7 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. •Participation in state one-call system, •Use of qualified operator employees and contractors to perform making and locating of buried structures and in direct supervision of excavation work, AND 615 - (Emerg Plan) 3rd Party Damage 103 - (Gen. Design) 111 - (Design factor) 317 - (Hazard prot) 327 -#

(cover)614 - (Dam. Prevent) 616 - (Public educat) 705 -#

(Patrol)707 - (Line markers) 711 - (repair - gen.) 717 - (Repair-perm.) •Either monitoring of excavations near operator's transmission pipelines, or bi-monthly patrol of transmission pipelines in HCAs or class 3 or 4 locations. Any indications of unreported construction activity would require a follow up investigation to determine if mechanical damage occurred.#