reglab/statecodes huggingface dataset:
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 29 - Maintenance [49 CFR Part 192 Subpart M] › Section XIII-2921 - Distribution Systems: Patrolling [49 CFR 192.721]

Current through Register Vol. 50, No. 6, June 20, 2024
A. The frequency of patrolling mains must be
				  determined by the severity of the conditions which could cause failure or
				  leakage, and the consequent hazards to public safety. [
				49 CFR
				  192.721(a)]
B. Mains in places or on structures where
				  anticipated physical movement or external loading could cause failure or
				  leakage must be patrolled: [
				49 CFR
				  192.721(b)]
1. in business districts, at intervals not
				  exceeding 4 1/2 months, but at least four times each calendar year; and [
				49 CFR
				  192.721(b)(1)]
2. outside business districts, at intervals
				  not exceeding seven and one-half months, but at least twice each calendar year.
				  [
				49 CFR
				  192.721(b)(2)]
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 29 - Maintenance [49 CFR Part 192 Subpart M] › Section XIII-2923 - Distribution Systems: Leakage Surveys [49 CFR 192.723]

Current through Register Vol. 50, No. 6, June 20, 2024
A. Each operator of a distribution system
				  shall conduct periodic leakage surveys in accordance with this Section. [
				49 CFR
				  192.723(a)]
B. The type and scope of the leakage control
				  program must be determined by the nature of the operations and the local
				  conditions, but it must meet the following minimum requirements. [
				49 CFR
				  192.723(b)]
1. A leakage survey with leak detector
				  equipment must be conducted in business districts, including tests of the
				  atmosphere in gas, electric, telephone, sewer, and water system manholes, at
				  cracks in pavement and sidewalks, and at other locations providing an
				  opportunity for finding gas leaks, at intervals not exceeding 15 months, but at
				  least once each calendar year. [
				49 CFR
				  192.723(b)(1)]
2. A leakage survey with leak detector
				  equipment must be conducted outside business districts as frequently as
				  necessary, but at least once every 5 calendar years at intervals not exceeding
				  63 months. However, for cathodically unprotected distribution lines subject to
				  §
												2117. E on which electrical surveys for corrosion are impractical, a
				  leakage survey must be conducted at least once every 3 calendar years at
				  intervals not exceeding 39 months [
				49 CFR
				  192.723(b)(2)].
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 29 - Maintenance [49 CFR Part 192 Subpart M] › Section XIII-2925 - Test Requirements for Reinstating Service Lines [49 CFR 192.725]

Current through Register Vol. 50, No. 6, June 20, 2024
A. Except as
				  provided in Subsection B of this Section, each disconnected service line must
				  be tested in the same manner as a new service line, before being reinstated. [
				49 CFR
				  192.725(a)]
B. Each service line temporarily disconnected
				  from the main must be tested from the point of disconnection to the service
				  line valve in the same manner as a new service line, before reconnecting.
				  However, if provisions are made to maintain continuous service, such as by
				  installation of a bypass, any part of the original service line used to
				  maintain continuous service need not be tested. [
				49 CFR
				  192.725(b)]
AUTHORITY NOTE:
					 Promulgated in accordance with
					 R.S. 30:501
					 et seq.
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 29 - Maintenance [49 CFR Part 192 Subpart M] › Section XIII-2927 - Abandonment or Deactivation of Facilities [49 CFR 192.727]

Current through Register Vol. 50, No. 6, June 20, 2024
A. Each operator
				  shall conduct abandonment or deactivation of pipelines in accordance with the
				  requirements of this Section. [
				49 CFR
				  192.727(a)]
B. Each pipeline abandoned in place must be
				  disconnected from all sources and supplies of gas; purged of gas; in the case
				  of offshore pipelines, filled with water or inert materials; and sealed at the
				  ends. However, the pipeline need not be purged when the volume of gas is so
				  small that there is no potential hazard. [
				49 CFR
				  192.727(b)]
C. Except for service lines, each inactive
				  pipeline that is not being maintained under this Subpart must be disconnected
				  from all sources and supplies of gas; purged of gas; in the case of offshore
				  pipelines, filled with water or inert materials; and sealed at the ends.
				  However, the pipeline need not be purged when the volume of gas is so small
				  that there is no potential hazard. [
				49 CFR
				  192.727(c)]
D. Whenever service to a customer is
				  discontinued, one of the following must be complied with. [
				49 CFR
				  192.727(d)]
1. The valve that is closed to prevent the
				  flow of gas to the customer must be provided with a locking device or other
				  means designed to prevent the opening of the valve by persons other than those
				  authorized by the operator. [
				49 CFR
				  192.727(d)(1)]
2. A mechanical device or fitting that will
				  prevent the flow of gas must be installed in the service line or in the meter
				  assembly. [
				49 CFR
				  192.727(d)(2)]
3. The customer's piping must be physically
				  disconnected from the gas supply and the open pipe ends sealed. [
				49 CFR
				  192.727(d)(3)]
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 29 - Maintenance [49 CFR Part 192 Subpart M] › Section XIII-2931 - Compressor Stations: Inspection and Testing of Relief Devices [49 CFR 192.731]

Current through Register Vol. 50, No. 6, June 20, 2024
A. Except for
				  rupture discs, each pressure relieving device in a compressor station must be
				  inspected and tested in accordance with
				  §2939 and
				  2943, and must be operated periodically to determine that it opens at the
				  correct set pressure. [
				49
				  CFR 192.731(a)]
B. Any defective or inadequate equipment
				  found must be promptly repaired or replaced. [
				49
				  CFR 192.731(b)]
C. Each remote control shutdown device must
				  be inspected and tested at intervals not exceeding 15 months, but at least once
				  each calendar year, to determine that it functions properly. [
				49
				  CFR 192.731(c)]
AUTHORITY NOTE:
					 Promulgated in accordance with
					 R.S. 30:501
					 et seq.
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 29 - Maintenance [49 CFR Part 192 Subpart M] › Section XIII-2935 - Compressor Stations: Storage of Combustible Materials [49 CFR 192.735]

Current through Register Vol. 50, No. 6, June 20, 2024
A. Flammable or
				  combustible materials in quantities beyond those required for everyday use, or
				  other than those normally used in compressor buildings, must be stored a safe
				  distance from the compressor building. [
				49 CFR
				  192.735(a)]
B. Aboveground oil or gasoline storage tanks
				  must be protected in accordance with NFPA-30 (incorporated by reference, see
				  §507). [
				49 CFR
				  192.735(b)
				  ]
AUTHORITY NOTE:
					 Promulgated in accordance with
					 R.S. 30:501
					 et seq.
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 29 - Maintenance [49 CFR Part 192 Subpart M] › Section XIII-2936 - Compressor Stations: Gas Detection [49 CFR 192.736]

Current through Register Vol. 50, No. 6, June 20, 2024
A. Not later than September 16, 1996, each
				  compressor building in a compressor station must have a fixed gas detection and
				  alarm system, unless the building is: [
				49 CFR
				  192.736(a)]
1. constructed so that at least 50 percent of
				  its upright side area is permanently open; or [
				49 CFR
				  192.736(a)(1)]
2. located in an unattended field compressor
				  station of 1,000 horsepower (746 kW) or less. [
				49 CFR
				  192.736(a)(2)]
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 29 - Maintenance [49 CFR Part 192 Subpart M] › Section XIII-2939 - Pressure Limiting and Regulating Stations: Inspection and Testing [49 CFR 192.739]

Current through Register Vol. 50, No. 6, June 20, 2024
A. Each
				  pressure limiting station, relief device (except rupture discs), and pressure
				  regulating station and its equipment must be subjected at intervals not
				  exceeding 15 months, but at least once each calendar year, to inspections and
				  tests to determine that it is [
				49
				  CFR 192.739(a)]:
1. in good mechanical condition [
				49
				  CFR
				  192.739(a)(1)];
2. adequate from the standpoint of capacity
				  and reliability of operation for the service in which it is employed [
				49
				  CFR
				  192.739(a)(2)];
3. except as provided in Subsection B of this
				  Section, set to control or relieve at the correct pressure consistent with the
				  pressure limits of §1161. A and [
				49
				  CFR
				  192.739(a)(3)];
4. properly installed and protected from
				  dirt, liquids, or other conditions that might prevent proper operation [
				49
				  CFR
				  192.739(a)(4)].
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 29 - Maintenance [49 CFR Part 192 Subpart M] › Section XIII-2940 - Pressure Regulating, Limiting, and Overpressure Protection-Individual Service Lines Directly Connected to Regulated Gathering or Transmission Pipelines [49 CFR 192.740]

Current through Register Vol. 50, No. 6, June 20, 2024
A. This Section
				  applies, except as provided in Subsection C of this Section, to any service
				  line directly connected to a transmission pipeline or regulated gathering
				  pipeline as determined in
				  §508 that is
				  not operated as part of a distribution system. [49
				  CFR 192.740(a)]
B. Each pressure regulating or limiting
				  device, relief device (except rupture discs), automatic shutoff device, and
				  associated equipment must be inspected and tested at least once every three
				  calendar years, not exceeding 39 months, to determine that it is: [
				49
				  CFR 192.740(b)]
1. a controller's authority and
				  responsibility to make decisions and take actions during normal operations; [
				49
				  CFR 192.740(b)(1)]
2. adequate from the standpoint of capacity
				  and reliability of operation for the service in which it is employed; [
				49
				  CFR 192.740(b)(2)]
3. set to control or relieve at the correct
				  pressure consistent with the pressure limits of § 192 197; and to limit
				  the pressure on the inlet of the service regulator to 60 psi (414 kPa) gauge or
				  less in case the upstream regulator fails to function properly; and [
				49
				  CFR 192.740(b)(3)]
4. properly installed and protected from
				  dirt, liquids, or other conditions that might prevent proper operation. [
				49
				  CFR 192.740(b)(4)
				  ]
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 29 - Maintenance [49 CFR Part 192 Subpart M] › Section XIII-2941 - Pressure Limiting and Regulating Stations: Telemetering or Recording Gages [49 CFR 192.741]

Current through Register Vol. 50, No. 6, June 20, 2024
A. Each
				  distribution system supplied by more than one district pressure regulating
				  station must be equipped with telemetering or recording pressure gages to
				  indicate the gas pressure in the district. [
				49
				  CFR 192.741(a)]
B. On distribution systems supplied by a
				  single district pressure regulating station, the operator shall determine the
				  necessity of installing telemetering or recording gages in the district, taking
				  into consideration the number of customers supplied, the operating pressures,
				  the capacity of the installation, and other operating conditions. [
				49
				  CFR 192.741(b)]
C. If there are indications of abnormally
				  high- or low-pressure, the regulator and the auxiliary equipment must be
				  inspected and the necessary measures employed to correct any unsatisfactory
				  operating conditions. [
				49
				  CFR 192.741(c)]
AUTHORITY NOTE:
					 Promulgated in accordance with
					 R.S. 30:501
					 et seq.
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 29 - Maintenance [49 CFR Part 192 Subpart M] › Section XIII-2943 - Pressure Limiting and Regulating Stations: Capacity of Relief Devices [49 CFR 192.743]

Current through Register Vol. 50, No. 6, June 20, 2024
A. Pressure
				  relief devices at pressure limiting stations and pressure regulating stations
				  must have sufficient capacity to protect the facilities to which they are
				  connected. Except as provided in §2939 B, the capacity must be consistent
				  with the pressure limits of §1161. A This capacity must be determined at
				  intervals not exceeding 15 months, but at least once each calendar year, by
				  testing the devices in place or by review and calculations [
				49
				  CFR 192.743(a)].
B. If review and calculations are used to
				  determine if a device has sufficient capacity, the calculated capacity must be
				  compared with the rated or experimentally determined relieving capacity of the
				  device for the conditions under which it operates. After the initial
				  calculations, subsequent calculations need not be made if the annual review
				  documents that parameters have not changed to cause the rated or experimentally
				  determined relieving capacity to be insufficient. [
				49
				  CFR 192.743(b)]
C. If a relief device is of insufficient
				  capacity, a new or additional device must be installed to provide the capacity
				  required by Subsection A of this Section. [
				49
				  CFR 192.743(c)]
AUTHORITY NOTE:
					 Promulgated in accordance with
					 R.S. 30:501
					 et seq.
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 29 - Maintenance [49 CFR Part 192 Subpart M] › Section XIII-2947 - Valve Maintenance: Distribution Systems [49 CFR 192.747]

Current through Register Vol. 50, No. 6, June 20, 2024
A. Each valve, the
				  use of which may be necessary for the safe operation of a distribution system,
				  must be checked and serviced at intervals not exceeding 15 months, but at least
				  once each calendar year. [
				49 CFR
				  192.747(a)]
B. Each operator must take prompt remedial
				  action to correct any valve found inoperable, unless the operator designates an
				  alternative valve. [
				49 CFR
				  192.747(b)]
AUTHORITY NOTE:
					 Promulgated in accordance with
					 R.S. 30:501
					 et seq.
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 29 - Maintenance [49 CFR Part 192 Subpart M] › Section XIII-2949 - Vault Maintenance [49 CFR 192.749]

Current through Register Vol. 50, No. 6, June 20, 2024
A. Each vault housing pressure regulating and
				  pressure limiting equipment, and having a volumetric internal content of 200
				  cubic feet (5.66 cubic meters) or more, must be inspected at intervals not
				  exceeding 15 months, but at least once each calendar year, to determine that it
				  is in good physical condition and adequately ventilated. [
				49 CFR
				  192.749(a)]
B. If gas is found in the vault, the
				  equipment in the vault must be inspected for leaks, and any leaks found must be
				  repaired. [
				49 CFR
				  192.749(b)]
C. The ventilating equipment must also be
				  inspected to determine that it is functioning properly. [
				49 CFR
				  192.749(c)]
D. Each vault cover must be inspected to
				  assure that it does not present a hazard to public safety. [
				49 CFR
				  192.749(d)]
AUTHORITY NOTE:
					 Promulgated in accordance with
					 R.S. 30:501
					 et seq.
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 29 - Maintenance [49 CFR Part 192 Subpart M] › Section XIII-2950 - Launcher and Receiver Safety [49 CFR 192.750]

Current through Register Vol. 50, No. 6, June 20, 2024
A. Any launcher or receiver used after July
				  1, 2021, must be equipped with a device capable of safely relieving pressure in
				  the barrel before removal or opening of the launcher or receiver barrel closure
				  or flange and insertion or removal of in-line inspection tools, scrapers, or
				  spheres. An operator must use a device to either: Indicate that pressure has
				  been relieved in the barrel; or alternatively prevent opening of the barrel
				  closure or flange when pressurized, or insertion or removal of in-line devices
				  (e.g. inspection tools, scrapers, or spheres), if pressure has not been
				  relieved. [49 CFR
				  192.750]
AUTHORITY NOTE:
					 Promulgated in accordance with
					 R.S. 30:501
					 et seq.
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 29 - Maintenance [49 CFR Part 192 Subpart M] › Section XIII-2951 - Prevention of Accidental Ignition [49 CFR 192.751]

Current through Register Vol. 50, No. 6, June 20, 2024
A. Each operator shall take steps to minimize
				  the danger of accidental ignition of gas in any structure or area where the
				  presence of gas constitutes a hazard of fire or explosion, including the
				  following: [
				49 CFR
				  192.751]
1.
				  when a hazardous amount of gas is being vented into open air, each potential
				  source of ignition must be removed from the area and a fire extinguisher must
				  be provided; [
				49 CFR
				  192.751(a)]
2. gas or electric welding or cutting may not
				  be performed on pipe or on pipe components that contain a combustible mixture
				  of gas and air in the area of work; [
				49 CFR
				  192.751(b)]
3. post warning signs, where appropriate. [
				49 CFR
				  192.751(c)]
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 29 - Maintenance [49 CFR Part 192 Subpart M] › Section XIII-2953 - Caulked Bell and Spigot Joints [49 CFR 192.753]

Current through Register Vol. 50, No. 6, June 20, 2024
A. Each cast-iron caulked bell and spigot
				  joint that is subject to pressures of more than 25 psi (172 kPa) gage must be
				  sealed with: [
				49 CFR
				  192.753(a)]
1. a mechanical leak clamp; or [
				49 CFR
				  192.753(a)(1)]
2. a material or device which: [
				49 CFR
				  192.753(a)(2)]
a. does not reduce the flexibility of the
				  joint; [
				49 CFR
				  192.753(a)(2)(i)]
b. permanently bonds, either chemically or
				  mechanically, or both, with the bell and spigot metal surfaces or adjacent pipe
				  metal surfaces; and [
				49 CFR
				  192.753(a)(2)(ii)
				  ]
c. seals and bonds in a manner
				  that meets the strength, environmental, and chemical compatibility requirements
				  of §703. A.1 and A.2 and §1103 [
				49 CFR
				  192.753(a)(2)(iii)
				  ]
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 29 - Maintenance [49 CFR Part 192 Subpart M] › Section XIII-2955 - Protecting Cast-Iron Pipelines [49 CFR 192.755]

Current through Register Vol. 50, No. 6, June 20, 2024
A. When an operator has knowledge that the
				  support for a segment of a buried cast-iron pipeline is disturbed: [
				49 CFR
				  192.755]
1.
				  that segment of the pipeline must be protected, as necessary, against damage
				  during the disturbance by: [
				49 CFR
				  192.755(a)]
a. vibrations from heavy construction
				  equipment, trains, trucks, buses, or blasting; [
				49 CFR
				  192.755(a)(1)]
b. impact forces by vehicles; [
				49 CFR
				  192.755(a)(2)]
c. earth movement; [
				49 CFR
				  192.755(a)(3)]
d. apparent future excavations near the
				  pipeline; or [
				49 CFR
				  192.755(a)(4)]
e. other foreseeable outside forces which may
				  subject that segment of the pipeline to bending stress; [
				49 CFR
				  192.755(a)(5)]
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 29 - Maintenance [49 CFR Part 192 Subpart M] › Section XIII-2956 - Joining Plastic Pipe by Heat Fusion; Equipment Maintenance and Calibration. [49 CFR 192.756]

Current through Register Vol. 50, No. 6, June 20, 2024
A. Each
				  operator must maintain equipment used in joining plastic pipe in accordance
				  with the manufacturers recommended practices or with written procedures that
				  have been proven by test and experience to produce acceptable joints.
				  [49
				  CFR 192.756]
AUTHORITY NOTE:
					 Promulgated in accordance with
					 R.S. 30:501
					 et seq.
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 31 - Operator Qualification [49 CFR Part 192 Subpart N] › Section XIII-3101 - Scope [49 CFR 192.801]

Current through Register Vol. 50, No. 6, June 20, 2024
A. This
				  Chapter prescribes the minimum requirements for operator qualification of
				  individuals performing covered tasks on a pipeline facility. [
				49 CFR
				  192.801(a)]
B. For the purpose of this Chapter, a covered
				  task is an activity, identified by the operator, that: [
				49 CFR
				  192.801(b)]
1. is performed on a pipeline facility; [
				49 CFR
				  192.801(b)(1)]
2. is an operations or maintenance task; [
				49 CFR
				  192.801(b)(2)]
3. is performed as a requirement of this
				  Part; and [
				49 CFR
				  192.801(b)(3)]
4. affects the operation or integrity of the
				  pipeline. [
				49 CFR
				  192.801(b)(4)]
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 31 - Operator Qualification [49 CFR Part 192 Subpart N] › Section XIII-3103 - Definitions [49 CFR 192.803]

Current through Register Vol. 50, No. 6, June 20, 2024
Abnormal Operating Condition
-a condition
					 identified by the operator that may indicate a malfunction of a component or
					 deviation from normal operations that may:
1. indicate a condition exceeding design limits; or
2. result in a hazard(s) to persons, property, or the
					 environment.
Evaluation
-a process, established and
					 documented by the operator, to determine an individual's ability to perform a
					 covered task by any of the following:
1. written examination;
2. oral examination;
3. work performance history review;
4. observation during:
a. performance on the job;
b. on the job training; or
c. simulations; or
5. other forms of assessment.
Qualified
-that an individual has been
					 evaluated and can:
1. perform assigned covered tasks; and
2. recognize and react to abnormal operating
					 conditions.
AUTHORITY NOTE:
					 Promulgated in accordance with
					 R.S. 30:501
					 et seq.
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 31 - Operator Qualification [49 CFR Part 192 Subpart N] › Section XIII-3105 - Qualification Program [49 CFR 192.805]

Current through Register Vol. 50, No. 6, June 20, 2024
A. Each operator shall have and follow a
				  written qualification program. The program shall include provisions to: [
				49 CFR
				  192.805]
1.
				  identify covered tasks; [
				49 CFR
				  192.805(a)]
2. ensure through evaluation that individuals
				  performing covered tasks are qualified; [
				49 CFR
				  192.805(b)]
3. allow individuals that are not qualified
				  pursuant to this Subpart to perform a covered task if directed and observed by
				  an individual that is qualified; [
				49 CFR
				  192.805(c)]
4. evaluate an individual if the operator has
				  reason to believe that the individual's performance of a covered task
				  contributed to an incident as defined in Chapter 3 of this Part; [
				49 CFR
				  192.805(d)]
5. evaluate an individual if the operator has
				  reason to believe that the individual is no longer qualified to perform a
				  covered task; [
				49 CFR
				  192.805(e)]
6. communicate changes that affect covered
				  tasks to individuals performing those covered tasks; [
				49 CFR
				  192.805(f)]
7. identify those covered tasks and the
				  intervals at which evaluation of the individual's qualifications is needed [
				49 CFR
				  192.805(g)] ;
8. after December 16, 2004, provide training,
				  as appropriate, to ensure that individuals performing covered tasks have the
				  necessary knowledge and skills to perform the tasks in a manner that ensures
				  the safe operation of pipeline facilities [
				49 CFR
				  192.805(h)]; and
9. After December 16, 2004, notify the
				  Administrator or a state agency participating under 49 U.S.C. Chapter 601 if an
				  operator significantly modifies the program after the administrator or state
				  agency has verified that it complies with this Section. Notifications to PHMSA
				  must be submitted in accordance with §518 [49 CFR
				  192.805(i)]
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 31 - Operator Qualification [49 CFR Part 192 Subpart N] › Section XIII-3107 - Recordkeeping [49 CFR 192.807]

Current through Register Vol. 50, No. 6, June 20, 2024
A. Each
				  operator shall maintain records that demonstrate compliance with this Subpart.
				   [49 CFR 192.807]
1. Qualification records shall include: [
				49
				  CFR 192.807(a)]
a. identification of qualified individual(s);
				   [49 CFR
				  192.807(a)(1)]
b. identification of the covered tasks the
				  individual is qualified to perform; [
				49
				  CFR 192.807(a)(2)]
c. date(s) of current qualification; and [
				49
				  CFR 192.807(a)(3)]
d. qualification method(s). [
				49
				  CFR 192.807(a) (4]
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 31 - Operator Qualification [49 CFR Part 192 Subpart N] › Section XIII-3109 - General [49 CFR 192.809]

Current through Register Vol. 50, No. 6, June 20, 2024
A.
				  Operators must have a written qualification program by April 27, 2001. The
				  program must be available for review by the administrator or by a state agency
				  participating under 49 U.S.C. Chapter 601 if the program is under the authority
				  of that state agency [
				49 CFR
				  192.809(a)].
B. Operators must complete the qualification
				  of individuals performing covered tasks by October 28, 2002. [
				49 CFR
				  192.809(b)]
C. Work performance history review may be
				  used as a sole evaluation method for individuals who were performing a covered
				  task prior to October 26, 1999. [
				49 CFR
				  192.809(c)]
D. After October 28, 2002, work performance
				  history may not be used as a sole evaluation method. [
				49 CFR
				  192.809(d)]
E. After December 16, 2004, observation of
				  on-the-job performance may not be used as the sole method of evaluation [
				49 CFR
				  192.809(e)].
AUTHORITY NOTE:
					 Promulgated in accordance with
					 R.S. 30:501
					 et seq.
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 33 - Gas Transmission Pipeline Integrity Management [49 CFR Part 192 Subpart O] › Section XIII-3301 - What Do the Regulations in this Chapter Cover? [49 CFR 192.901]

Current through Register Vol. 50, No. 6, June 20, 2024
A. This Chapter
				  prescribes minimum requirements for an integrity management program on any gas
				  transmission pipeline covered under this Part. For gas transmission pipelines
				  constructed of plastic, only the requirements in
				  §3317 apply.
				  [
				49 CFR
				  192.901]
AUTHORITY NOTE:
					 Promulgated in accordance with
					 R.S. 30:501
					 et seq.
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 33 - Gas Transmission Pipeline Integrity Management [49 CFR Part 192 Subpart O] › Section XIII-3305 - How Does an Operator Identify a High Consequence Area? [49 CFR 192.905]

Current through Register Vol. 50, No. 6, June 20, 2024
A. General. To
				  determine which segments of an operator's transmission pipeline system are
				  covered by this Chapter, an operator must identify the high consequence areas.
				  An operator must use Method a or b 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. An operator must describe in its
				  integrity management program which method it is applying to each portion of the
				  operator's pipeline system. The description must include the potential impact
				  radius when utilized to establish a high consequence area. (See §5109,
				  Appendix E.I for guidance on identifying high consequence areas.) [
				49 CFR
				  192.905(a)]
B. Identified Sites. An operator must
				  identify an identified site, for purposes of this Chapter, from information the
				  operator has obtained from routine operation and maintenance activities and
				  from public officials with safety or emergency response or planning
				  responsibilities who indicate to the operator that they know of locations that
				  meet the identified site criteria. These public officials could include
				  officials on a local emergency planning commission or relevant Native American
				  tribal officials. If a public official with safety or emergency response or
				  planning responsibilities informs an operator that it does not have the
				  information to identify an identified site, the operator must use one of the
				  following sources, as appropriate, to identify these sites: [
				49 CFR
				  192.905(b)]
1. visible marking (e.g., a sign); or [
				49 CFR
				  192.905(b)(1)]
2. the site is licensed or registered by a
				  federal, state, or local government agency; or [
				49 CFR
				  192.905(b)(2)]
3. the site is on a list (including a list on
				  an internet web site) or map maintained by or available from a federal, state,
				  or local government agency and available to the general public. [
				49 CFR
				  192.905(b)(3)]
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 33 - Gas Transmission Pipeline Integrity Management [49 CFR Part 192 Subpart O] › Section XIII-3307 - What Must an Operator Do to Implement this Chapter? [49 CFR 192.907]

Current through Register Vol. 50, No. 6, June 20, 2024
A. General. No
				  later than December 17, 2004, an operator of a covered pipeline segment must
				  develop and follow a written integrity management program that contains all the
				  elements described in
				  §3311 and
				  that addresses the risks on each covered transmission pipeline segment. The
				  initial integrity management program must consist, at a minimum, of a framework
				  that describes the process for implementing each program element, how relevant
				  decisions will be made and by whom, a time line for completing the work to
				  implement the program element, and how information gained from experience will
				  be continuously incorporated into the program. The framework will evolve into a
				  more detailed and comprehensive program. An operator must make continual
				  improvements to the program. [
				49 CFR
				  192.907(a)]
B. Implementation Standards. In carrying out
				  this Chapter, an operator must follow the requirements of this Chapter and of
				  ASME/ANSI B31.8S (incorporated by reference, see §507) and its appendices,
				  where specified. An operator may follow an equivalent standard or practice only
				  when the operator demonstrates the alternative standard or practice provides an
				  equivalent level of safety to the public and property. In the event of a
				  conflict between this Chapter and ASME/ANSI B31.8S, the requirements in this
				  Chapter control [
				49 CFR
				  192.907(b)].
AUTHORITY NOTE:
					 Promulgated in accordance with
					 R.S. 30:501
					 et seq.
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 33 - Gas Transmission Pipeline Integrity Management [49 CFR Part 192 Subpart O] › Section XIII-3309 - How Can an Operator Change Its Integrity Management Program? [49 CFR 192.909]

Current through Register Vol. 50, No. 6, June 20, 2024
A. General. An
				  operator must document any change to its program and the reasons for the change
				  before implementing the change. [
				49 CFR
				  192.909(a)]
B. Notification. An operator must notify OPS,
				  in accordance with §518, of any change to the program that may
				  substantially affect the programs implementation or may significantly modify
				  the program or schedule for carrying out the program elements. An operator must
				  provide notification within 30 days after adopting this type of change into its
				  program. [49 CFR
				  192.909(b)]
AUTHORITY NOTE:
					 Promulgated in accordance with
					 R.S. 30:501
					 et seq.
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 33 - Gas Transmission Pipeline Integrity Management [49 CFR Part 192 Subpart O] › Section XIII-3313 - When May an Operator Deviate Its Program from Certain Requirements of this Chapter? [49 CFR 192.913]

Current through Register Vol. 50, No. 6, June 20, 2024
A. General.
				  ASME/ANSI B31.8S (ibr, see §507) provides the essential features of a
				  performance-based or a prescriptive integrity management program. An operator
				  that uses a performance-based approach that satisfies the requirements for
				  exceptional performance in Subsection B of this Section may deviate from
				  certain requirements in this Chapter, as provided in Subsection C of this
				  Section. [
				49
				  CFR 192.913(a)]
B. Exceptional Performance
.
An operator must be able to demonstrate the exceptional performance of its
				  integrity management program through the following actions. [
				49
				  CFR 192.913(b)]
1. To deviate from any of the requirements
				  set forth in Subsection C of this Section, an operator must have a
				  performance-based integrity management program that meets or exceed the
				  performance-based requirements of ASME/ANSI B31.8S and includes, at a minimum,
				  the following elements: [
				49
				  CFR 192.913(b)(1)]
a. a comprehensive process for risk analysis;
				  [
				49
				  CFR
				  192.913(b)(1)(i)]
b. all risk factor data used to support the
				  program; [
				49
				  CFR 192.913(b)(1)(ii)
				  ]
c. a comprehensive data
				  integration process; [
				49
				  CFR 192.913(b)(1)(iii)
				  ]
d. a procedure for applying
				  lessons learned from assessment of covered pipeline segments to pipeline
				  segments not covered by this Chapter; [
				49
				  CFR 192.913(b)(1)(iv)
				  ]
e. a procedure for evaluating
				  every incident, including its cause, within the operator's sector of the
				  pipeline industry for implications both to the operator's pipeline system and
				  to the operator's integrity management program; [
				49
				  CFR
				  192.913(b)(1)(v)]
f. a performance matrix that demonstrates the
				  program has been effective in ensuring the integrity of the covered segments by
				  controlling the identified threats to the covered segments; [
				49
				  CFR 192.913(b)(1)(vi)
				  ]
g. semi-annual performance
				  measures beyond those required in
				  §3345 that
				  are part of the operator's performance plan [see §3311 9]. An operator
				  must submit these measures, by electronic or other means, on a semi-annual
				  frequency to OPS in accordance with
				  §3351 [
				49
				  CFR 192.913(b)(1)(vii)];
				  and
h. an analysis that supports
				  the desired integrity reassessment interval and the remediation methods to be
				  used for all covered segments. [
				49
				  CFR 192.913(b)(1)(viii)
				  ]
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 33 - Gas Transmission Pipeline Integrity Management [49 CFR Part 192 Subpart O] › Section XIII-3315 - What Knowledge and Training Must Personnel Have to Carry Out an Integrity Management Program? [49 CFR 192.915]

Current through Register Vol. 50, No. 6, June 20, 2024
A. Supervisory Personnel. The integrity
				  management program must provide that each supervisor whose responsibilities
				  relate to the integrity management program possesses and maintains a thorough
				  knowledge of the integrity management program and of the elements for which the
				  supervisor is responsible. The program must provide that any person who
				  qualifies as a supervisor for the integrity management program has appropriate
				  training or experience in the area for which the person is responsible. [
				49
				  CFR 192.915(a)]
B. Persons Who Carry Out Assessments and
				  Evaluate Assessment Results. The integrity management program must provide
				  criteria for the qualification of any person: [
				49
				  CFR 192.915(b)]
1. who conducts an integrity assessment
				  allowed under this Chapter; or [
				49
				  CFR 192.915(b)(1)]
2. who reviews and analyzes the results from
				  an integrity assessment and evaluation; or [
				49
				  CFR 192.915(b)(2)]
3. who makes decisions on actions to be taken
				  based on these assessments. [
				49
				  CFR 192.915(b)(3)]
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 33 - Gas Transmission Pipeline Integrity Management [49 CFR Part 192 Subpart O] › Section XIII-3317 - How Does an Operator Identify Potential Threats to Pipeline Integrity and Use the Threat Identification in Its Integrity Program? [49 CFR 192.917]

Current through Register Vol. 50, No. 6, June 20, 2024
A. Threat
				  Identification. An operator must identify and evaluate all potential threats to
				  each covered pipeline segment. Potential threats that an operator must consider
				  include, but are not limited to, the threats listed in ASME/ANSI B31.8S
				  (incorporated by reference, see §507), Section 2, which are grouped under
				  the following four categories [
				49
				  CFR 192.917(a)]:
1. time dependent threats such as internal
				  corrosion, external corrosion, and stress corrosion cracking; [
				49
				  CFR 192.917(a)(1)]
2. static or resident threats, such as
				  fabrication or construction defects; [
				49
				  CFR 192.917(a)(2)]
3. time independent threats such as third
				  party damage, mechanical damage, incorrect operational procedure, weather
				  related and outside force damage to include consideration of seismicity,
				  geology, and soil stability of the area; and [49
				  CFR 192.917(a)(3)]
4. human error. [
				49
				  CFR 192.917(a)(4)]
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 33 - Gas Transmission Pipeline Integrity Management [49 CFR Part 192 Subpart O] › Section XIII-3319 - What Must Be in the Baseline Assessment Plan [49 CFR 192.919]

Current through Register Vol. 50, No. 6, June 20, 2024
A. An operator must
				  include each of the following elements in its written baseline assessment plan:
				  [
				49 CFR
				  192.919]
1.
				  identification of the potential threats to each covered pipeline segment and
				  the information supporting the threat identification (see §3317); [
				49 CFR
				  192.919(a)]
2. the methods selected to assess the
				  integrity of the line pipe, including an explanation of why the assessment
				  method was selected to address the identified threats to each covered segment.
				  The integrity assessment method an operator uses must be based on the threats
				  identified to the covered segment (see §3317). More than one method may be
				  required to address all the threats to the covered pipeline segment; [
				49 CFR
				  192.919(b)]
3. a schedule for completing the integrity
				  assessment of all covered segments, including, risk factors considered in
				  establishing the assessment schedule; [
				49 CFR
				  192.919(c)]
4. if applicable, a direct assessment plan
				  that meets the requirements of §3323, and depending on the threat to be
				  addressed, of §§3325, 3327, or 3329; and [
				49 CFR
				  192.919(d)]
5. a procedure to ensure that the baseline
				  assessment is being conducted in a manner that minimizes environmental and
				  safety risks. [
				49 CFR
				  192.919(e)]
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 33 - Gas Transmission Pipeline Integrity Management [49 CFR Part 192 Subpart O] › Section XIII-3323 - How Is Direct Assessment Used and for What Threats? [49 CFR 192.923]

Current through Register Vol. 50, No. 6, June 20, 2024
A. General. An
				  operator may use direct assessment either as a primary assessment method or as
				  a supplement to the other assessment methods allowed under this Chapter. An
				  operator may only use direct assessment as the primary assessment method to
				  address the identified threats of external corrosion (EC), internal corrosion
				  (IC), and stress corrosion cracking (SCC). [
				49 CFR
				  192.923(a)]
B. Primary Method. An operator using direct
				  assessment as a primary assessment method must have a plan that complies with
				  the requirements in: [
				49 CFR
				  192.923(b)]
1.§3325 and
				  ASME/ANSI B31.8S (incorporated by reference, see §507), section 6.4, and
				  NACE SP0502 (incorporated by reference, see §507) if addressing external
				  corrosion (EC). [
				49 CFR
				  192.923(b)(1)]
2.§3327 and
				  ASME/ANSI B31.8S (incorporated by reference, see §507), section 6.4,
				  appendix B2, if addressing internal corrosion (IC). [
				49 CFR
				  192.923(b)(2)]
3.§3329 and
				  ASME/ANSI B31.8S (incorporated by reference, see §5070, appendix A3, if
				  addressing stress corrosion cracking (SCC). [
				49 CFR
				  192.923(b)(3)
				  ]