Subpart O. Subpart O—Gas Transmission Pipeline Integrity Management
- § 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?
- § 192.907 - What must an operator do to implement this subpart?
- § 192.909 - How can an operator change its integrity management program?
- § 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?
- § 192.915 - What knowledge and training must personnel have to carry out an integrity management program?
- § 192.917 - How does an operator identify potential threats to pipeline integrity and use the threat identification in its integrity program?
- § 192.919 - What must be in the baseline assessment plan?
- § 192.921 - How is the baseline assessment to be conducted?
- § 192.923 - How is direct assessment used and for what threats?
- § 192.925 - What are the requirements for using External Corrosion Direct Assessment (ECDA)?
- § 192.927 - What are the requirements for using Internal Corrosion Direct Assessment (ICDA)?
- § 192.929 - What are the requirements for using Direct Assessment for Stress Corrosion Cracking?
- § 192.931 - How may Confirmatory Direct Assessment (CDA) be used?
- § 192.933 - What actions must be taken to address integrity issues?
- § 192.935 - What additional preventive and mitigative measures must an operator take?
- § 192.937 - What is a continual process of evaluation and assessment to maintain a pipeline's integrity?
- § 192.939 - What are the required reassessment intervals?
- § 192.941 - What is a low stress reassessment?
- § 192.943 - When can an operator deviate from these reassessment intervals?
- § 192.945 - What methods must an operator use to measure program effectiveness?
- § 192.947 - What records must an operator keep?
- § 192.949 - [Reserved]
- § 192.951 - Where does an operator file a report?