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 (SCCDA)?
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
[Removed]
192.951
Where does an operator file a report?
[Amdt. 192 95, 69 FR 2307, December 22, 2003]