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Pipeline and Hazardous Materials Safety Administration, DOT
the strength of the pipe based on actual remaining wall thickness in the pits. § 195.587 What methods are available to determine the strength of corroded pipe? Under § 195.585, you may use the procedure in ASME B31G, ‘‘Manual for Determining the Remaining Strength of Corroded Pipelines,’’ or the procedure developed by AGA/Battelle, ‘‘AModified Criterion for Evaluating the Remaining Strength of Corroded Pipe (with RSTRENG disk),’’ to determine the strength of corroded pipe based on actual remaining wall thickness. These procedures apply to corroded regions that do not penetrate the pipe wall, subject to the limitations set out in the respective procedures. § 195.589 What corrosion control information do I have to maintain? (a)You must maintain current records or maps to show the location of— (1) Cathodically protected pipelines; (2) Cathodic protection facilities, including galvanic anodes, installed after January 28, 2002; and (3) Neighboring structures bonded to cathodic protection systems. (b) Records or maps showing a stated number of anodes, installed in a stated manner or spacing, need not show specific distancesto each buried anode. (c) You must maintain a record of each analysis, check, demonstration, examination, inspection, investigation, review, survey, and test required by this subpart in sufficient detail to demonstrate the adequacy of corrosion control measures or that corrosion requiring control measures does not exist. You must retain these records for at least 5 years, except that recordsrelated to §§ 195.569, 195.573(a) and (b), and 195.579(b)(3) and (c) must be retained for as long as the pipeline remains in service. APPENDIX A TO PART 195—DELINEATION BETWEEN FEDERAL AND STATE JURISDICTION—STATEMENT OF AGENCY POLICY AND INTERPRETATION
In 1979, Congress enacted comprehensive safety legislation governing the transportation of hazardous liquids by pipeline, the

Pt. 195, App. AHazardous Liquids Pipeline Safety Act of 1979, 49 U.S.C. 2001 et seq. (HLPSA). The HLPSA expanded the existing statutory authority for safety regulation, which was limited to transportation by common carriers in interstate and foreign commerce, to transportation through facilities used in or affecting interstate or foreign commerce. It also added civil penalty, compliance order, and injunctiveenforcement authorities to the existing criminal sanctions. Modeled largely on the Natural Gas Pipeline Safety Act of 1968, 49 U.S.C. 1671 et seq. (NGPSA), the HLPSA provides for a national hazardous liquid pipeline safety program with nationally uniform minimal standards and with enforcement administered through a FederalState partnership. The HLPSA leaves to exclusive Federal regulation andenforcement the ‘‘interstate pipeline facilities,’’ those used for the pipeline transportation of hazardous liquids in interstate or foreign commerce. For the remainder of the pipeline facilities, denominated ‘‘intrastate pipeline facilities,’’ the HLPSA provides that the same Federal regulation and enforcement will apply unless a State certifies that it will assume those responsibilities. A certifiedState must adopt the same minimal standards but may adopt additional more stringent standards so long as they are compatible. Therefore, in States which participate in the hazardous liquid pipeline safety program through certification, it is necessary to distinguish the interstate from the intrastate pipeline facilities. In deciding that an administratively practical approach was necessary indistinguishing between interstate and intrastate liquid pipeline facilities and in determining how best to accomplish this, DOT has logically examined the approach used in the NGPSA. The NGPSA defines the interstate gas pipeline facilities subject to exclusive Federal jurisdiction as those subject to the economic regulatory jurisdiction of the Federal Energy Regulatory Commission (FERC). Experience has...
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