What Is a Low Stress Reassessment? [49 CFR 192.941]

(A)A. General. An operator of a transmission line that operates below 30 percent SMYS may use the following method to reassess a covered segment in accordance with §3339. This method of reassessment addresses the threats of external and internal corrosion. The operator must have conducted a baseline assessment of the covered segment in accordance with the requirements of §§3319 and 3321. [49 CFR 192.941(a)]#

(B)B. External Corrosion. An operator must take one of the following actions to address external corrosion on the low stress covered segment. [49 CFR 192.941(b)]#

(1)1. Cathodically Protected Pipe. To address the threat of external corrosion on cathodically protected pipe in a covered segment, an operator must perform an indirect assessment on the covered segment at least once every 7 calendar years. The indirect assessment must be conducted using one of the following means: indirect examination method, such as a close interval survey; alternating current voltage gradient survey; direct current voltage gradient survey; or the equivalent of any of these methods. An operator must evaluate the cathodic protection and corrosion threat for the covered segment and include the results of each indirect assessment as part of the overall evaluation. This evaluation must also include, at a minimum, the leak repair and inspection records, corrosion monitoring records, exposed pipe inspection records, and the pipeline environment. [49 CFR 192.941(b)(1)]#

(2)2. Unprotected Pipe or Cathodically Protected Pipe Where Electrical Surveys Are Impractical. If an external corrosion assessment is impractical on the covered segment an operator must: [49 CFR 192.941(b)(2)]#

(a)a. conduct leakage surveys as required by §2906 at 4-month intervals; and [49 CFR 192.941(b)(2)(i)]#

(b)b. every 18 months, identify and remediate areas of active corrosion by evaluating leak repair and inspection records, corrosion monitoring records, exposed pipe inspection records, and the pipeline environment. [49 CFR 192.941(b)(2)(ii)]#

(C)C. Internal Corrosion. To address the threat of internal corrosion on a covered segment, an operator must: [49 CFR 192.941(c)]#

(1)1. conduct a gas analysis for corrosive agents at least once each calendar year; [49 CFR 192.941(c)(1)]#

(2)2. conduct periodic testing of fluids removed from the segment. At least once each calendar year test the fluids removed from each storage field that may affect a covered segment; and [49 CFR 192.941(c)(2)]#

(3)3. at least every seven years, integrate data from the analysis and testing required by Paragraphs C.1. and 2 with applicable internal corrosion leak records, incident reports, safety-related condition reports, repair records, patrol records, exposed pipe reports, and test records, and define and implement appropriate remediation actions. [49 CFR 192.941(c)(3)]#

AUTHORITY NOTE: Promulgated in accordance with R.S. 30:501 et seq.#

HISTORICAL NOTE: Promulgated by the Department of Natural Resources, Office of Conservation, Pipeline Division, LR 30:1284 (June 2004), amended LR 31:689 (March 2005), LR 50:1263 (September 2024).#