Louisiana Administrative Code › Title 43 - NATURAL RESOURCES › Part XIII - Office of Conservation-Pipeline Safety › Subpart 3 - Transportation of Natural Gas or Other Gas by Pipeline: Minimum Safety Standards [49 CFR Part 192] › Chapter 51 - Appendices › Section XIII-5109 - Appendix E-Guidance on Determining High Consequence Areas and on Carrying out Requirements in the Integrity Management Rule

Current through Register Vol. 50, No. 6, June 20, 2024
I.
Guidance on Determining a High
				  Consequence Area
To determine which segments of an operator's transmission
					 pipeline system are covered for purposes of the integrity management program
					 requirements, an operator must identify the high consequence areas. An operator
					 must use Method (1) or (2) from the definition in
					 §3303 to
					 identify a high consequence area. An operator may apply one method to its
					 entire pipeline system, or an operator may apply one method to individual
					 portions of the pipeline system. (Refer to Figure E.I.A for a diagram of a high
					 consequence area).
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II.
Guidance
				  on Assessment Methods and Additional Preventive and Mitigative Measures for
				  Transmission Pipelines
1. Table E.II.1
				  gives guidance to help an operator implement requirements on additional
				  preventive and mitigative measures for addressing time dependent and
				  independent threats for a transmission pipeline operating below 30 percent SMYS
				  not in an HCA (i.e., outside of potential impact circle) but located within a
				  Class 3 or Class 4 Location.
2.
				  Table E.II.2 gives guidance to help an operator implement requirements on
				  assessment methods for addressing time dependent and independent threats for a
				  transmission pipeline in an HCA.
3.
				  Table E.II.3 gives guidance on preventative and mitigative measures addressing
				  time dependent and independent threats for transmission pipelines that operate
				  below 30 percent SMYS, in HCAs.
Table E.II.1
: Preventative and
								Mitigative Measures for Transmission Pipelines Operating below 30 Percent SMYS
								Not in an HCA but in a Class 3 or Class 4 Location
(Column 1)
Threat
Existing Subpart 3 Requirements
(Column 4)
Additional (to Subpart 3 requirements)
Preventive and Mitigative Measures
(Column 2)
Primary
(Column 3)
Secondary
External Corrosion
2107-(Gen. Post 1971)
2109-(Gen. Pre-1971)
2111-(Examination)
2113-(Ext. coating)
2115-(CP)
2117-(Monitoring)
2119-(Elect isolation)
2121-Test stations)
2123-(Test leads)
2125-(Interference)
2131-(Atmospheric)
2133-(Atmospheric)
2137-(Remedial)
2905-(Patrol)
2906-(Leak survey)
2911 (Repair B gen.)
2917-(Repair B perm.)
2703-(Gen Operation)
2713-(Surveillance)
For Cathodically Protected Transmission Pipeline:
* Perform semi-annual leak surveys.
For Unprotected Transmission Pipelines or for
								Cathodically Protected Pipe where Electrical Surveys are Impractical:
* Perform quarterly leak surveys
Internal Corrosion
2127-(Gen IC),
2129-(IC monitoring)
2137-(Remedial),
2905-(Patrol)
2906-(Leak survey),
2911-(Repair B gen.)
2917-(Repair B perm.)
703(A)-(Materials)
2703-(Gen Operation)
2713-(Surveillance)
* Perform semi-annual leak surveys.
3rd Party Damage
903-(Gen. Design),
911-(Design factor)
1717-(Hazard prot),
1727-(Cover)
2714-(Dam. Prevent),
2716-(Public education)
2905-(Patrol),
2907-(Line markers)
2911-(Repair B gen.),
2917-(Repair B perm.)
2715 B (Emerg. Plan)
* Participation in state one-call system,
* Use of qualified operator employees and
								contractors to perform marking and locating of buried structures and in direct
								supervision of excavation work, AND
* Either monitoring of excavations near operator's
								transmission pipelines, or bi-monthly patrol of transmission pipelines in class
								3 and 4 locations. Any indications of unreported construction activity would
								require a follow up investigation to determine if mechanical damage occurred.
Table E.II.2 Assessment Requirements for
								Transmission Pipelines in HCAs (Re-assessment intervals are maximum allowed.)
Re-Assessment Requirements (see Note 3)
At or above 50 Percent SMYS
At or above 30 Percent SMYS
up to 50 Percent SMYS
Below 30 Percent SMYS
Baseline Assessment Method (see Note 3)
Max Re-Assessment Interval
Assessment Method
Max Re-Assessment Interval
Assessment Method
Max Re-Assessment Interval
Assessment Method
Pressure Testing
7
CDA
7
CDA
Ongoing
Preventative & Mitigative (P&M) Measures
								(see Table E.II.3), (see Note 2)
10
Pressure Test or ILI or DA
Repeat inspection cycle every 10 years
15 (see Note 1)
Pressure Test or ILI or DA (see Note 1)
Repeat inspection cycle every 15 years
20
Pressure Test or ILI or DA
Repeat inspection cycle every 20 years
In-Line Inspection
7
CDA
7
CDA
Ongoing
Preventative & Mitigative (P&M) Measures
								(see Table E.II.3), (see Note 2)
10
ILI or DA or Pressure Test
Repeat inspection cycle every 10 years
15 (see Note 1)
ILI or DA or Pressure Test (see Note 1)
Repeat inspection cycle every 15 years
20
ILI or DA or Pressure Test
Repeat inspection cycle every 20 years
Direct Assessment
7
CDA
7
CDA
Ongoing
Preventative & Mitigative (P&M) Measures
								(see Table E.II.3), (see Note 2)
10
DA or ILI or Pressure Test
Repeat inspection cycle every 10 years
15 (see Note 1)
DA or ILI or Pressure Test (see Note 1)
Repeat inspection cycle every 15 years
20
DA or ILI or Pressure Test
Repeat inspection cycle every 20 years
Note 1: Operator may choose to utilize CDA at year
								14, then utilize ILI, Pressure Test, or DA at year 15 as allowed under ASME
								B31.8S
Note 2: Operator may choose to utilize CDA at year
								7 and 14 in lieu of P&M
Note 3: Operator may utilize "other technology
								that an operator demonstrates can provide an equivalent understanding of the
								condition of line pipe"
Table E.II.3
Preventative and Mitigative Measures
								addressing Time Dependent and Independent Threats for Transmission Pipelines
								that Operate below 30 Percent SMYS, in HCAs
Threat
Existing Subpart 3 Requirements
Additional (to Subpart 3 requirements)
								Preventive and Mitigative Measures
Primary
Secondary
External Corrosion
2107-(Gen. Post 1971)
2109-(Gen. Pre-1971)
2111-(Examination)
2113-(Ext. coating)
2115-(CP)
2117-(Monitoring)
2119-(Elect isolation)
2121-Test stations)
2123-(Test leads)
2125-(Interference)
2131-(Atmospheric)
2133-(Atmospheric)
2137-(Remedial)
2905-(Patrol)
2906-(Leak survey)
2911-(Repair B gen.)
2917-(Repair B perm.)
2703-(Gen Oper)
2713-(Surveil)
For Cathodically Protected Trmn. Pipelines
* Perform an electrical survey (i.e., indirect
								examination tool/method) at least every seven years. Results are to be utilized
								as part of an overall evaluation of the CP system and corrosion threat for the
								covered segment. Evaluation shall include consideration of leak repair and
								inspection records, corrosion monitoring records, exposed pipe inspection
								records, and the pipeline environment.
For Unprotected Trmn. Pipelines or for
								Cathodically Protected Pipe where Electrical Surveys are Impracticable
* Conduct quarterly leak surveys AND
* Every 1 1/2 years, determine areas of active
								corrosion by evaluation of leak repair and inspection records, corrosion
								monitoring records, exposed pipe inspection records, and the pipeline
								environment.
Internal Corrosion
2127-(Gen IC)
2129-(IC monitoring)
2137-(Remedial)
2905-(Patrol)
2906-(Leak survey)
2911-(Repair B gen.)
2917-(Repair B perm.)
703(A)-(Materials)
2703-(Gen Oper)
2713-(Surveil)
* Obtain and review gas analysis data each calendar
								year for corrosive agents from transmission pipelines in HCAs,
* Periodic testing of fluid removed from pipelines.
								Specifically, once each calendar year from each storage field that may affect
								transmission pipelines in HCAs, AND
* At least every seven years, integrate data
								obtained with applicable internal corrosion leak records, incident reports,
								safety related condition reports, repair records, patrol records, exposed pipe
								reports, and test records.
3rd Party Damage
903-(Gen. Design)
911-(Design factor)
1717-(Hazard prot)
1727-(Cover)
2714-(Dam. Prevent)
2716-(Public educat)
2905-(Patrol)
2909-(Line markers)
2911-(Repair B gen.)
2917-(Repair B perm.)
2715 B (Emerg Plan)
* Participation in state one-call system,
* Use of qualified operator employees and
								contractors to perform marking and locating of buried structures and in direct
								supervision of excavation work, AND
* Either monitoring of excavations near operator's
								transmission pipelines, or bi-monthly patrol of transmission pipelines in HCAs
								or Class 3 and 4 locations. Any indications of unreported construction activity
								would require a follow up investigation to determine if mechanical damage
								occurred.