49 CFR Subpart O
Gas Transmission Pipeline Integrity Management
November 18, 2020
§
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)?
§
192.901
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?
§
192.929
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
[Reserved]
§
192.951
Where does an operator file a report?