LAC 43:XIII §2719
What is the Maximum Allowable Operating Pressure for Steel or Plastic Pipelines? [49 CFR 192.619]
(A)A. No person may operate a segment of steel or plastic pipeline at a pressure that exceeds a maximum allowable operating pressure determined under Subsection C, D, or E of this Section, or the lowest of the following: [49 CFR 192.619(a)]#
(1)1. the design pressure of the weakest element in the segment, determined in accordance with Chapter 9 and 11 of this Subpart. However, for steel pipe in pipelines being converted under §514 or uprated under Chapter 25 of this Subpart, if any variable necessary to determine the design pressure under the design formula (§905) is unknown, one of the following pressures is to be used as design pressure: [49 CFR 192.619(a)(1)]#
(a)a. 80 percent of the first test pressure that produces yield under Section N5 of Appendix N of ASME B31.8 (incorporated by reference, see §507), reduced by the appropriate factor in Subparagraph A.2.b of this Section [49 CFR 192.619(a)(1)(i)] ; or#
(b)b. if the pipe is 12 3/4 in. (324 mm) or less in outside diameter and is not tested to yield under this Subsection, 200 psi (1379 kPa) gage; [49 CFR 192.619(a)(1)(ii)]#
(2)2. the pressure obtained by dividing the pressure to which the pipeline segment was tested after construction as follows: [49 CFR 192.619(a)(2)]#
(a)a. for plastic pipe in all locations, the test pressure is divided by a factor of 1.5; [49 CFR 192.619(a)(2)(i)]#
(b)b. for steel pipe operated at 100 psi (689 kPa) gage or more, the test pressure is divided by a factor determined in accordance with the following table to Subparagraph A.2.b. [49 CFR 192.619(a)(2)(ii)]#
Table 1 to Subparagraph A.2.b#
Factors1, Segment#
Class Location#
Installed before (Nov. 12, 1970)#
Installed after (Nov. 11, 1970) and before July 1, 2020#
Installed on or after July 1, 2020#
1#
1. 1#
1. 1#
1. 25#
1. 25#
2#
1. 25#
1. 25#
1. 25#
1. 25#
3#
1. 4#
1. 5#
1. 5#
1. 5#
4#
1. 4#
1. 5#
1. 5#
1. 5#
1For offshore segments installed, uprated or converted after July 31, 1977, that are not located on an offshore platform, the factor is 1.25. For segments installed, uprated or converted after July 31, 1977, that are located on an offshore platform or on a platform in inland navigable waters, including a pipe riser, the factor is 1.5.#
2For a component with a design pressure established in accordance with §1113.A or B installed after July 14, 2004, the factor is 1.3.#
(3)3. the highest actual operating pressure to which the segment was subjected during the five years preceding the applicable date in the second column. This pressure restriction applies unless the segment was tested according to the requirements in Paragraph A.2 of this Section after the applicable date in the third column or the segment was uprated according to the requirements in Chapter 25 of this Subpart. [49 CFR 192.619(a)(3)]#
Pipeline Segment#
Pressure Date#
Test Date#
—Onshore gathering line that first became subject to this Subpart (other than §2712) after April 13, 2006.#
March 15, 2006, or date line becomes subject to this Subpart, whichever is later.#
5 years preceding applicable date in second column.#
Onshore regulated gathering pipeline (Type C under §509.D that first became subject to this part (other than §2712) on or after May 16, 2022#
May 16, 2023, or date pipeline becomes subject to this Subpart, whichever is later#
5 years preceding applicable date in second column.#
—Onshore transmission line that was a gathering line not subject to this Subpart before March 15, 2006.#
March 15, 2006, or date line becomes subject to this Subpart, whichever is later.#
5 years preceding applicable date in second column#
Offshore gathering lines.#
July 1, 1976#
July 1, 1971#
All other pipelines.#
July 1, 1970#
July 1, 1965#
(4)4. the pressure determined by the operator to be the maximum safe pressure after considering and accounting for records of material properties, including material properties verified in accordance with §2707, if applicable, and the history of the segment, particularly known corrosion and the actual operating pressure. [49 CFR 192.619(a)(4)]#
(B)B. No person may operate a segment to which Paragraph A.4 of this Section is applicable, unless over-pressure protective devices are installed on the segment in a manner that will prevent the maximum allowable operating pressure from being exceeded, in accordance with §1155. [49 CFR 192.619(b)]#
(C)C. The requirements on pressure restrictions in this Section do not apply in the following instance: [49 CFR 192.619(c)]#
(1)1. An operator may operate a segment of pipeline found to be in satisfactory condition, considering its operating and maintenance history, at the highest actual operating pressure to which the segment was subjected during the five years preceding the applicable date in the second column of the table in Paragraph A.3 of this Section. An operator must still comply with §2711. [49 CFR 192.619(c)(1)]#
(2)2. For any Type C gas gathering pipeline under §509 existing on or before May 16, 2022, that was not previously subject to this part and the operator cannot determine the actual operating pressure of the pipeline for the 5 years preceding May 16, 2023, the operator may establish MAOP using other criteria based on a combination of operating conditions, other tests, and design with approval from PHMSA. The operator must notify PHMSA in accordance with §518. The notification must include the following information: [49 CFR 192.19(c)(2)]#
(a)a. the proposed MAOP of the pipeline; [49 CFR 192.619(c)(2)(i)]#
(b)b. description of pipeline segment for which alternate methods are used to establish MAOP, including diameter, wall thickness, pipe grade, seam type, location, endpoints, other pertinent material properties, and age; [49 CFR 192.619(c)(2)(ii)]#
(c)c. pipeline operating data, including operating history and maintenance history; [49 CFR 192.619(c)(2)(iii)]#
(d)d. description of methods being used to establish MAOP; [49 CFR 192.619(c)(2)(iv)]#
(e)e. technical justification for use of the methods chosen to establish MAOP; and [49 CFR 192.619(c)(2)(v)]#
(f)f. evidence of review and acceptance of the justification by a qualified technical subject matter expert. [49 CFR 192.619(c)(2)(vi)]#
(D)D. The operator of a pipeline segment of steel pipeline meeting the conditions prescribed in §2720.B may elect to operate the segment at a maximum allowable operating pressure determined under §2720.A. [49 CFR 192.619(d)]#
(E)E. Notwithstanding the requirements in Subsections A through D of this Section, operators of onshore steel transmission pipelines that meet the criteria specified in §2724.A must establish and document the maximum allowable operating pressure in accordance with §2724. [49 CFR 192.619(e)]#
(F)F. Operators of onshore steel transmission pipelines must make and retain records necessary to establish and document the MAOP of each pipeline segment in accordance with Subsections A through E of this Section as follows: [49 CFR 192.619(f)]#
(1)1. operators of pipelines in operation as of [July 1, 2020 must retain any existing records establishing MAOP for the life of the pipeline; [49 CFR 192.619(f)(1)]#
(2)2. operators of pipelines in operation as of July 1, 2020 that do not have records establishing MAOP and are required to reconfirm MAOP in accordance with §2724, must retain the records reconfirming MAOP for the life of the pipeline; and [49 CFR 192. 619(f)(2)]#
(3)3. operators of pipelines placed in operation after July 1, 2020 must make and retain records establishing MAOP for the life of the pipeline. [49 CFR 192. 619(f)(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, LR 9:242 (April 1983), amended LR 10:534 (July 1984), LR 24:1312 (July 1998), LR 27:1547 (September 2001), LR 30:1264 (June 2004), LR 33:481 (March 2007), LR 35:2807 (December 2009), LR 46:1590 (November 2020), LR 47:1145 (August 2021), LR 49:1106 (June 2023).#