Rule Outline

§ 192.901 What do the regulations in this subpart cover?

§ 192.903 What definitions apply to this subpart?

§ 192.905 How does an operator identify a high consequence area?

• (a) General.
• (b) Identified sites.
• (c) Newly-identified areas.

§ 192.907 What must an operator do to implement this subpart?

• (a) General.
• (b) Implementation Standards.

§ 192.909 How can an operator change its integrity management program?

• (a) General.
• (b) Notification.

§ 192.911 What are the elements of an integrity management program?

§ 192.913 When may an operator deviate its program from certain requirements of this subpart?

• (a) General.
• (b) Exceptional performance.
• (c) Deviation.

§ 192.915 What knowledge and training must personnel have to carry out an integrity management program?

• (a) Supervisory personnel.
• (b) Persons who carry out assessments and evaluate assessment results.
• (c) Persons responsible for preventive and mitigative measures.

§ 192.917 How does an operator identify potential threats to pipeline integrity and use the threat identification in its integrity program?

• (a) Threat identification.
• (b) Data gathering and integration.
• (c) Risk assessment.
• (d) Plastic Transmission Pipeline.
• (e) Actions to address particular threats.
• (e)(1) Third party damage.
• (e)(2) Cyclic fatigue.
• (e)(3) Manufacturing and construction defects.
• (e)(4) ERW pipe.
• (e)(5) Corrosion.

§ 192.919 What must be in the baseline assessment plan?

• (a) Threats.
• (b) Methods.
• (c) Schedule.
• (d) Direct assessment plan.
• (e) Risk minimization procedure.

§ 192.921 How is the baseline assessment to be conducted?

• (a) Assessment methods.
• (a)(1) Internal inspection.
• (a)(2) Pressure test.
• (a)(3) Direct assessment.
• (a)(4) Other technology.
• (b) Prioritizing segments.
• (c) Assessment for particular threats.
• (d) Time period.
• (e) Prior assessment.
• (f) Newly-identified areas.
• (g) Newly-installed pipe.
• (h) Plastic transmission pipeline.

§ 192.923 How is direct assessment used and for what threats?

• (a) General.
• (b) Primary Method.
• (c) Supplemental method.

§ 192.925 What are the requirements for using External Corrosion Direct Assessment (ECDA)?

• (a) Definition.
• (b) General requirements.
• (b)(1) Preassessment.
• (b)(2) Indirect Examination.
• (b)(3) Direct Examination.
• (b)(4) Post assessment and continuing evaluation.

§ 192.927 What are the requirements for using Internal Corrosion Direct Assessment (ICDA)?

• (a) Definition.
• (b) General requirements.
• (c) The ICDA plan.
• (c)(1) Preassessment.
• (c)(1)(i) All data elements listed in Appendix A2 of ASME/ANSI B31.8S;
• (c)(1)(ii) Model data.
• (c)(1)(iii) Operating experience data.
• (c)(1)(iv) Other data.
• (c)(2) ICDA region identification.
• (c)(3) Identification of locations for excavation and direct examination.
• (c)(3)(i) Evaluate severity.
• (c)(3)(ii) Additional excavation or assessment method.
• (c)(3)(iii) Evaluate system-wide implications.
• (c)(4) Post-assessment evaluation and monitoring.
• (c)(5) Other requirements.

§ 192.929 What are the requirements for using Direct Assessment for Stress Corrosion Cracking (SCCDA)?

• (a) Definition.
• (b) General Requirements.
• (b)(1) Data gathering and integration.
• (b)(2) Assessment method.

§ 192.931 How may Confirmatory Direct Assessment (CDA) be used?

• (a) Threats.
• (b) External corrosion plan.
• (c) Internal corrosion plan.
• (d) Defects requiring near-term remediation.

§ 192.933 What actions must be taken to address integrity issues?

• (a) General requirements.
• (b) Discovery of condition.
• (c) Schedule for evaluation and remediation.
• (d) Special requirements for scheduling remediation.

§ 192.935 What additional preventive and mitigative measures must an operator take?

• (a) General Requirements.
• (b) Third Party Damage and Outside Force Damage.
• (c) Automatic shut-off valves (ASV) or Remote control valves (RCV).
• (d) Pipelines operating below 30% SMYS.
• (e) Plastic transmission pipeline.

§ 192.937 What is a continual process of evaluation and assessment to maintain a pipeline's integrity?

• (a) General.
• (b) Evaluation.
• (c) Assessment methods.
• (c)(1) Internal inspection tools.
• (c)(2) Pressure test.
• (c)(3) Direct assessment.
• (c)(4) Other technology.
• (c)(5) Confirmatory direct assessment.

§ 192.939 What are the required reassessment intervals?

• (a) Pipelines operating at or above 30% SMYS.
• (b) Pipelines Operating Below 30% SMYS.

§ 192.941 What is a low stress reassessment?

• (a) General.
• (b) External Corrosion.
• (b)(1) Cathodically Protected Pipe.
• (b)(2) Unprotected Pipe or Cathodically Protected Pipe Where Electrical Surveys are Impractical.
• (c) Internal Corrosion.

§ 192.943 When can an operator deviate from these reassessment intervals?

• (a) Waiver from reassessment interval in limited situations.
• (b) How to apply.

§ 192.945 What methods must an operator use to measure program effectiveness?

• (a) General.
• (b) External Corrosion Direct Assessment.

§ 192.947 What records must an operator keep?

§ 192.949 How does an operator notify OPS?

§ 192.951 Where does an operator file a report?