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 27 - Operations [49 CFR Part 192 Subpart L] › Section XIII-2703 - General Provisions [49 CFR 192.603]

Current through Register Vol. 50, No. 6, June 20, 2024
A. No person may operate a segment of
				  pipeline unless it is operated in accordance with this Subpart. [
				49 CFR
				  192.603(a)]
B. Each operator shall keep records necessary
				  to administer the procedures established under §2705 [
				49 CFR
				  192.603(b)]
C. The administrator or the state agency that
				  has submitted a current certification under the pipeline safety laws, (49
				  U.S.C. 60101 et seq.) with respect to the
				  pipeline facility governed by an operator's plans and procedures may, after
				  notice and opportunity for hearing as provided in
				  49 CFR
				  190.206 or the relevant state procedures,
				  require the operator to amend its plans and procedures as necessary to provide
				  a reasonable level of safety. [
				49 CFR
				  192.603(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 27 - Operations [49 CFR Part 192 Subpart L] › Section XIII-2709 - Change in Class Location: Required Study [49 CFR 192.609]

Current through Register Vol. 50, No. 6, June 20, 2024
A. Whenever an
				  increase in population density indicates a change in class location for a
				  segment of an existing steel pipeline operating at a hoop stress that is more
				  than 40 percent of SMYS, or indicates that the hoop stress corresponding to the
				  established maximum allowable operating pressure for a segment of existing
				  pipeline is not commensurate with the present class location, the operator
				  shall immediately make a study to determine: [
				49 CFR
				  192.609]
1.
				  the present class location for the segment involved; [
				49 CFR
				  192.609(a)]
2. the design, construction, and testing
				  procedures followed in the original construction, and a comparison of these
				  procedures with those required for the present class location by the applicable
				  provisions of this Subpart; [
				49 CFR
				  192.609(b)]
3. the physical condition of the segment to
				  the extent it can be ascertained from available records; [
				49 CFR
				  192.609(c)]
4. the operating and maintenance history of
				  the segment; [
				49 CFR
				  192.609(d)]
5. the maximum actual operating pressure and
				  the corresponding operating hoop stress, taking pressure gradient into account,
				  for the segment of pipeline involved; and [
				49 CFR
				  192.609(e)]
6. the actual area affected by the population
				  density increase, and physical barriers or other factors which may limit
				  further expansion of the more densely populated area. [
				49 CFR
				  192.609(f)]
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 27 - Operations [49 CFR Part 192 Subpart L] › Section XIII-2710 - Change in class location: Change in valve spacing. [49 CFR 192.610]

Current through Register Vol. 50, No. 6, June 20, 2024
A. If a class
				  location change on a transmission pipeline occurs after October 5, 2022 and
				  results in pipe replacement, of 2 or more miles, in the aggregate, within any 5
				  contiguous miles within a 24-month period, to meet the maximum allowable
				  operating pressure (MAOP) requirements in §§2711, 2719, or 2720, then
				  the requirements in §§1139, 2734, 2736, as applicable, apply to the
				  new class location, and the operator must install valves, including
				  rupture-mitigation valves (RMV) or alternative equivalent technologies, as
				  necessary, to comply with those sections. Such valves must be installed within
				  24 months of the class location change in accordance with the timing
				  requirement in
				  §2711.D for compliance
				  after a class location change. [49 CFR
				  192.610(a)]
B. If a class location change occurs after
				  October 5, 2022 and results in pipe replacement of less than 2 miles within 5
				  contiguous miles during a 24-month period, to meet the MAOP requirements in
				  §§2711, 2719, or 2720, then within 24 months of the class location
				  change, in accordance with
				  §2711 D, the
				  operator must either: [49
				  CFR 192.610(b)]
1. Comply with the valve spacing requirements
				  of §192.179(a) for the
				  replaced pipeline segment; or [49 CFR
				  192.610(b)(1)]
2. Install or use existing RMVs or
				  alternative equivalent technologies so that the entirety of the replaced
				  pipeline segments are between at least two RMVs or alternative equivalent
				  technologies. The distance between RMVs and alternative equivalent technologies
				  for the replaced segment must not exceed 20 miles. The RMVs and alternative
				  equivalent technologies must comply with the applicable requirements of
				  §2736 [49 CFR
				  192.610(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 27 - Operations [49 CFR Part 192 Subpart L] › Section XIII-2711 - Change in Class Location: Confirmation or Revision of Maximum Allowable Operating Pressure [49 CFR 192.611]

Current through Register Vol. 50, No. 6, June 20, 2024
A. If the hoop stress corresponding to the
				  established maximum allowable operating pressure of a segment of pipeline is
				  not commensurate with the present class location, and the segment is in
				  satisfactory physical condition, the maximum allowable operating pressure of
				  that segment of pipeline must be confirmed or revised according to one of the
				  following requirements. [
				49
				  CFR 192.611(a)]
1. If the segment involved has been
				  previously tested in place for a period of not less than 8 hours: [
				49
				  CFR 192.611(a)(1)]
a. The maximum allowable operating pressure
				  is 0.8 times the test pressure in Class 2 locations, 0.667 times the test
				  pressure in Class 3 locations, or 0.555 times the test pressure in Class 4
				  locations. The corresponding hoop stress may not exceed 72 percent of the SMYS
				  of the pipe in Class 2 locations, 60 percent of SMYS in Class 3 locations, or
				  50 percent of SMYS in Class 4 locations. [
				49
				  CFR
				  192.611(a)(1)(i)]
b. The alternative maximum allowable
				  operating pressure is 0.8 times the test pressure in Class 2 locations and
				  0.667 times the test pressure in Class 3 locations. For pipelines operating at
				  alternative maximum allowable pressure per §2720, the corresponding hoop
				  stress may not exceed 80 percent of the SMYS of the pipe in Class 2 locations
				  and 67 percent of SMYS in Class 3 locations. [
				49
				  CFR 192.611(a)(1)(ii)
				  ]
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 27 - Operations [49 CFR Part 192 Subpart L] › Section XIII-2712 - Underwater Inspection and Reburial of Pipelines in the Gulf of Mexico and Its Inlets [49 CFR 192.612]

Current through Register Vol. 50, No. 6, June 20, 2024
A. Each
				  operator shall prepare and follow a procedure to identify its pipelines in the
				  Gulf of Mexico and its inlets in waters less than 15 feet (4.6 meters) deep as
				  measured from mean low water that are at risk of being an exposed underwater
				  pipeline or a hazard to navigation. The procedures must be in effect August 10,
				  2005. [
				49
				  CFR 192.612(a)]
B. Each operator shall conduct appropriate
				  periodic underwater inspections of its pipelines in the Gulf of Mexico and its
				  inlets in waters less than 15 feet (4.6 meters) deep as measured from mean low
				  water based on the identified risk. [
				49
				  CFR 192.612(b)]
C. If an operator discovers that its pipeline
				  is an exposed underwater pipeline or poses a hazard to navigation, the operator
				  shall: [
				49
				  CFR 192.612(c)]
1. promptly, but not later than 24 hours
				  after discovery, notify the National Response Center, telephone:
				  1-800-424-8802, as well as Louisiana Pipeline Safety (225) 342-5505 (day or
				  night), of the location and, if available, the geographic coordinates of that
				  pipeline; [
				49
				  CFR 192.612(c)(1)]
2. promptly, but not later than seven days
				  after discovery, mark the location of the pipeline in accordance with  33 CFR
				  Part 64  at the ends of the pipeline segment and at intervals of not over 500
				  yards (457 meters) long, except that a pipeline segment less than 200 yards
				  (183 meters) long need only be marked at the center; and [
				49
				  CFR 192.612(c)(2)]
3. within six months after discovery, or not
				  later than November 1 of the following year if the six month period is later
				  than November 1 of the year of discovery, bury the pipeline so that the top of
				  the pipe is 36 inches (914 millimeters) below the underwater natural bottom (as
				  determined by recognized and generally accepted practices) for normal
				  excavation or 18 inches (457 millimeters) for rock excavation: [
				49
				  CFR 192.612(c)(3)]
a. an operator may employ engineered
				  alternatives to burial that meet or exceed the level of protection provided by
				  burial; [
				49
				  CFR
				  192.612(c)(3)(i)]
b. if an operator cannot obtain required
				  state or federal permits in time to comply with this Section, it must notify
				  OPS; specify whether the required permit is state or federal; and, justify the
				  delay. [
				49
				  CFR 192.612(c)(3)(ii)
				  ]
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 27 - Operations [49 CFR Part 192 Subpart L] › Section XIII-2713 - Continuing Surveillance [49 CFR 192.613]

Current through Register Vol. 50, No. 6, June 20, 2024
A. Each operator shall have a procedure for
				  continuing surveillance of its facilities to determine and take appropriate
				  action concerning changes in class location, failures, leakage history,
				  corrosion, substantial changes in cathodic protection requirements, and other
				  unusual operating and maintenance conditions. [
				49 CFR
				  192.613(a)]
B. If a segment of pipeline is determined to
				  be in unsatisfactory condition but no immediate hazard exists, the operator
				  shall initiate a program to recondition or phase out the segment involved, or,
				  if the segment cannot be reconditioned or phased out, reduce the maximum
				  allowable operating pressure in accordance with §2719. A and B. [
				49 CFR
				  192.613(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 27 - Operations [49 CFR Part 192 Subpart L] › Section XIII-2714 - Damage Prevention Progra [49 CFR 192.614]

Current through Register Vol. 50, No. 6, June 20, 2024
A. Except as provided in Subsection D and E
				  of this Section, each operator of a buried pipeline shall carry out, in
				  accordance with this Section a written program to prevent damage to that
				  pipeline by excavation activities. For the purpose of this Section, the term
excavation activities
include excavation, blasting, boring,
				  tunneling, backfilling, the removal of above ground structures by either
				  explosive or mechanical means, and other earth moving operations. [
				49 CFR
				  192.614(a)]
B. An operator may comply with any of the
				  requirements of Subsection C of this Section through participation in a public
				  service program, such as a one-call system, but such participation does not
				  relieve the operator of responsibility for compliance with this Section.
				  However, an operator must perform the duties of Paragraph C.3 of this Section
				  through participation in a one-call system, if that one-call system is a
				  qualified one-call system. In areas that are covered by more than one qualified
				  one-call system, an operator need only join one of the qualified one-call
				  systems if there is a central telephone number for excavators to call for
				  excavation activities, or if the one-call systems in those areas communicate
				  with one another. An operator's pipeline system must be covered by a qualified
				  one-call system where there is one in place. For the purpose of this Section, a
				  one-call system is considered a
qualified one-call system
if
				  it meets the requirements of Paragraph B.1 or B.2 of this Section: [
				49 CFR
				  192.614(b)]
1. the state has adopted a one-call damage
				  prevention program under §198.37 of CFR 49; or [
				49 CFR
				  192.614(b)(1)]
2. the one-call system: [
				49 CFR
				  192.614(b)(2)]
a. is operated in accordance with
				  §198.39 of CFR 49; [
				49 CFR
				  192.614(b)(2)(i)]
b. provides a pipeline operator an
				  opportunity similar to a voluntary participant to have a part in management
				  responsibilities; and [
				49 CFR
				  192.614(b)(2)(ii)
				  ]
c. assesses a participating
				  pipeline operator a fee that is proportionate to the costs of the one-call
				  system's coverage of the operator's pipeline. [
				49 CFR
				  192.614(b)(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 27 - Operations [49 CFR Part 192 Subpart L] › Section XIII-2716 - Public Awareness [49 CFR 192.616]

Current through Register Vol. 50, No. 6, June 20, 2024
A. Except for an operator of a master meter
				  or petroleum gas system covered under Subsection J of this Section, each
				  pipeline operator must develop and implement a written continuing public
				  education program that follows the guidance provided in the American Petroleum
				  Institute's (API) RecommendedPractice (RP) 1162 (Incorporated by Reference, see
				  §507). [
				49 CFR
				  192.616(a)]
B. The operator's program must follow the
				  general program recommendations of API RP 1162 and assess the unique attributes
				  and characteristics of the operator's pipeline and facilities, Except as stated
				  in Paragraph B.1 [
				49 CFR
				  192.616(b)].
1. Regulatory inspections are not an
				  acceptable alternative to conducting an annual audit for measuring program
				  implementation as mentioned in API RP 1162 section 8. 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 27 - Operations [49 CFR Part 192 Subpart L] › Section XIII-2717 - Investigation of Failures [49 CFR 192.617]

Current through Register Vol. 50, No. 6, June 20, 2024
A. Post-failure and incident procedures. Each
				  operator must establish and follow procedures for investigating and analyzing
				  failures and incidents as defined in §303, including sending the failed
				  pipe, component, or equipment for laboratory testing or examination, where
				  appropriate, for the purpose of determining the causes and contributing
				  factor(s) of the failure or incident and minimizing the possibility of a
				  recurrence. [49 CFR
				  192.617(a)]
B. Post-failure and incident lessons learned.
				  Each operator must develop, implement, and incorporate lessons learned from a
				  post-failure or incident review into its written procedures, including
				  personnel training and qualification programs, and design, construction,
				  testing, maintenance, operations, and emergency procedure manuals and
				  specifications. [49 CFR
				  192.617(b)]
C. Analysis of rupture and valve shutoffs. If
				  an incident on an onshore gas transmission pipeline or a Type A gathering
				  pipeline involves the closure of a rupture-mitigation valve (RMV), as defined
				  in §503, or the closure of alternative equivalent technology, the operator
				  of the pipeline must also conduct a post-incident analysis of all of the
				  factors that may have impacted the release volume and the consequences of the
				  incident and identify and implement operations and maintenance measures to
				  prevent or minimize the consequences of a future incident. The requirements of
				  this Subsection B are not applicable to distribution pipelines or Types B and C
				  gas gathering pipelines. The analysis must include all relevant factors
				  impacting the release volume and consequences, including, but not limited to,
				  the following: [49 CFR
				  192.617(c)]
1. detection, identification, operational
				  response, system shut-off, and emergency response communications, based on the
				  type and volume of the incident; [49 CFR
				  192.617(c)(1)]
2. appropriateness and effectiveness of
				  procedures and pipeline systems, including supervisory control and data
				  acquisition (SCADA), communications, valve shut-off, and operator personnel;
				  [49 CFR
				  192.617(c)(2)]
3. actual response time from identifying a
				  rupture following a notification of potential rupture, as defined at §503,
				  to initiation of mitigative actions and isolation of the pipeline segment, and
				  the appropriateness and effectiveness of the mitigative actions taken;
				  [49 CFR
				  192.617(c)(3)]
4. location and timeliness of actuation of
				  RMVs or alternative equivalent technologies; and [49 CFR
				  192.617(c)(4)]
5. all other factors the operator deems
				  appropriate. [49 CFR
				  192.617(c)(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 27 - Operations [49 CFR Part 192 Subpart L] › Section XIII-2719 - What is the Maximum Allowable Operating Pressure for Steel or Plastic Pipelines? [49 CFR 192.619]

Current through Register Vol. 50, No. 6, June 20, 2024
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. 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. 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. 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)
				  ]
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 27 - Operations [49 CFR Part 192 Subpart L] › Section XIII-2720 - Alternative Maximum Allowable Operating Pressure for Certain Steel Pipelines [49 CFR 192.620]

Current through Register Vol. 50, No. 6, June 20, 2024
A.
How
				  does an operator calculate the alternative maximum allowable operating
				  pressure?
An operator calculates the alternative maximum allowable
				  operating pressure by using different factors in the same formulas used for
				  calculating maximum allowable operating pressure under §2719. A as
				  follows: [
				49
				  CFR 192.620(a)]
1. In determining the alternative design
				  pressure under §905, use a design factor determined in accordance with
				  §911 B, C, or D or, if none of these Subsections apply, in accordance
				  with the following table: [
				49
				  CFR 192.620(a)(1)]
Class Location
Alternative design factor (F)
1
0.80
2
0.67
3
0.56
a. For
				  facilities installed prior to December 22, 2008, for which §911 B, C, or
				  D applies, use the following design factors as alternatives for the factors
				  specified in those Subsections: §911 B0.67 or less; 911.C and D0.56 or
				  less. [
				49
				  CFR
				  192.620(a)(1)(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 27 - Operations [49 CFR Part 192 Subpart L] › Section XIII-2721 - Maximum Allowable Operating Pressure: High-Pressure Distribution Systems [49 CFR 192.621]

Current through Register Vol. 50, No. 6, June 20, 2024
A. No person
				  may operate a segment of a high pressure distribution system at a pressure that
				  exceeds the lowest of the following pressures, as applicable: [
				49
				  CFR 192.621(a)]
1. the design pressure of the weakest element
				  in the segment, determined in accordance with Chapter 9 and 11 of this Subpart;
				  [
				49
				  CFR 192.621(a)(1)]
2. 60 psi (414 kPa) gage, for a segment of a
				  distribution system otherwise designated to operate at over 60 psi (414 kPa)
				  gage, unless the service lines in the segment are equipped with service
				  regulators or other pressure limiting devices in series that meet the
				  requirements of §1157 C; [
				49
				  CFR 192.621(a)(2)]
3. 25 psi (172 kPa) gage in segments of cast
				  iron pipe in which there are unreinforced bell and spigot joints; [
				49
				  CFR 192.621(a)(3)]
4. the pressure limits to which a joint could
				  be subjected without the possibility of its parting; [
				49
				  CFR 192.621(a)(4)]
5. the pressure determined by the operator to
				  be the maximum safe pressure after considering the history of the segment,
				  particularly known corrosion and the actual operating pressures. [
				49
				  CFR 192.621(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 27 - Operations [49 CFR Part 192 Subpart L] › Section XIII-2723 - Maximum and Minimum Allowable Operating Pressure: Low-Pressure Distribution Systems [49 CFR 192.623]

Current through Register Vol. 50, No. 6, June 20, 2024
A. No person
				  may operate a low-pressure distribution system at a pressure high enough to
				  make unsafe the operation of any connected and properly adjusted low-pressure
				  gas burning equipment. [
				49
				  CFR 192.623(a)]
B. No person may operate a low-pressure
				  distribution system at a pressure lower than the minimum pressure at which the
				  safe and continuing operation of any connected and properly adjusted
				  low-pressure gas burning equipment can be assured. [
				49
				  CFR 192.623(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 27 - Operations [49 CFR Part 192 Subpart L] › Section XIII-2724 - Maximum Allowable Operating Pressure Reconfirmation: Onshore Steel Transmission Pipelines [49 CFR 192.624]

Current through Register Vol. 50, No. 6, June 20, 2024
A. Applicability. Operators of onshore steel
				  transmission pipeline segments must reconfirm the maximum allowable operating
				  pressure (MAOP) of all pipeline segments in accordance with the requirements of
				  this Section if either of the following conditions are met: [49
				  CFR 192.624(a)]
1. Records necessary to establish the MAOP in
				  accordance with
				  §2719.A 2, including
				  records required by
				  §2317 A, are
				  not traceable, verifiable, and complete and the pipeline is located in one of
				  the following locations: [49
				  CFR 192.624(a)(1)]
a. a high consequence area as defined in
				  § 3303; or [49
				  CFR
				  192.624(a)(1)(i)]
b. a Class 3 or Class 4 location.
				  [49
				  CFR
				  192.624(a)(1)(ii)]
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 27 - Operations [49 CFR Part 192 Subpart L] › Section XIII-2725 - Odorization of Gas [49 CFR 192.625]

Current through Register Vol. 50, No. 6, June 20, 2024
A. No person engaged in the business of
				  handling, storing, selling, or distributing natural and other toxic or
				  combustible odorless gases, except liquefied petroleum gases, shall operate a
				  gathering, distribution or transmission pipeline, unless the gas is malodorized
				  in accordance with this regulation.
B. Natural gas or any toxic or combustible
				  odorless gas, in a distribution line must contain a natural odorant or be
				  odorized so that at a concentration in air of one-fifth of the lower explosive
				  limit, the gas is readily detectable by a person with a normal sense of smell
				  at any point in the line where odorization is required. [
				49 CFR
				  192.625(a)]
C. Natural gas, or any toxic or combustible
				  odorless gas, in a gathering or transmission line in a Class 3 or Class 4
				  location must contain a natural odorant or be odorized so that at a
				  concentration in air of one-fifth of the lower explosive limit, the gas is
				  readily detectable by a person with a normal sense of smell at any point in the
				  line where odorization is required, unless: [
				49 CFR
				  192.625(b)]
1. at least 50 percent of the length of the
				  line downstream from that location is in a Class 1 or Class 2 location; [
				49 CFR
				  192.625(b)(1)]
2. the line transports gas to any of the
				  following facilities: [
				49 CFR
				  192.625(b)(2)]
a. an underground storage field; [
				49 CFR
				  192.625(b)(2)(i)]
b. a gas processing plant; [
				49 CFR
				  192.625(b)(2)(ii)]
c. a gas dehydration plant; or [
				49 CFR
				  192.625(b)(2)(iii)]
d. an industrial plant using gas in a process
				  where the presence of an odorant: [
				49 CFR
				  192.625(b)(2)(iv)]
i. makes the end product unfit for the
				  purpose for which it is intended; [
				49 CFR
				  192.625(b)(2)(iv)(A)
				  ]
ii. reduces the activity of a
				  catalyst; or [
				49 CFR
				  192.625(b)(2)(iv)(B)
				  ]
iii. reduces the percentage
				  completion of a chemical reaction; [
				49 CFR
				  192.625(b)(2)(iv)(C)
				  ]
3. in the
				  case of a lateral line which transports gas to a distribution center or
				  industrial complex, at least 50 percent of the length of that line is in a
				  Class 1 or Class 2 location; or [
				49 CFR
				  192.625(b)(3)]
4. the combustible gas is hydrogen intended
				  for use as a feedstock in a manufacturing process. [
				49 CFR
				  192.625(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 27 - Operations [49 CFR Part 192 Subpart L] › Section XIII-2727 - Tapping Pipelines under Pressure [49 CFR 192.627]

Current through Register Vol. 50, No. 6, June 20, 2024
A. Each tap made on a pipeline under pressure
				  must be performed by a crew qualified to make hot taps. [
				49 CFR
				  192.627]
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 27 - Operations [49 CFR Part 192 Subpart L] › Section XIII-2729 - Purging of Pipelines [49 CFR 192.629]

Current through Register Vol. 50, No. 6, June 20, 2024
A. When a pipeline is being purged of air by
				  use of gas, the gas must be released into one end of the line in a moderately
				  rapid and continuous flow. If gas cannot be supplied in sufficient quantity to
				  prevent the formation of a hazardous mixture of gas and air, a slug of inert
				  gas must be released into the line before the gas. [
				49 CFR
				  192.629(a)]
B. When a pipeline is being purged of gas by
				  use of air, the air must be released into one end of the line in a moderately
				  rapid and continuous flow. If air cannot be supplied in sufficient quantity to
				  prevent the formation of a hazardous mixture of gas and air, a slug of inert
				  gas must be released into the line before the air. [
				49 CFR
				  192.629(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 27 - Operations [49 CFR Part 192 Subpart L] › Section XIII-2731 - Control Room Management [49 CFR 192.631]

Current through Register Vol. 50, No. 6, June 20, 2024
A. General [
				49 CFR
				  192.631(a)]
1. This Section applies to each operator of a
				  pipeline facility with a controller working in a control room who monitors and
				  controls all or part of a pipeline facility through a SCADA system. Each
				  operator must have and follow written control room management procedures that
				  implement the requirements of this Section, except that for each control room
				  where an operator's activities are limited to either or both of: [
				49 CFR
				  192.631(a)(1)]
a. distribution with less than 250,000
				  services; or [
				49 CFR
				  192.631(a)(1)(i)]
b. transmission without a compressor station,
				  the operator must have and follow written procedures that implement only
				  Subsections D (regarding fatigue), I (regarding compliance validation), and J
				  (regarding compliance and deviations) of this Section. [
				49 CFR
				  192.631(a)(1)(ii)
				  ]
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 27 - Operations [49 CFR Part 192 Subpart L] › Section XIII-2735 - Notification of Potential Rupture [49 CFR 192.635]

Current through Register Vol. 50, No. 6, June 20, 2024
A. As used in this part, a "notification of
				  potential rupture" refers to the notification of, or observation by, an
				  operator (e.g., by or to its controller(s) in a control room, field personnel,
				  nearby pipeline or utility personnel, the public, local responders, or public
				  authorities) of one or more of the below indicia of a potential unintentional
				  or uncontrolled release of a large volume of gas from a pipeline:
				  [49 CFR
				  192.635(a)]
1. an unanticipated or unexplained pressure
				  loss outside of the pipeline's normal operating pressures, as defined in the
				  operator's written procedures. The operator must establish in its written
				  procedures that an unanticipated or unplanned pressure loss is outside of the
				  pipeline's normal operating pressures when there is a pressure loss greater
				  than 10 percent occurring within a time interval of 15 minutes or less, unless
				  the operator has documented in its written procedures the operational need for
				  a greater pressure-change threshold due to pipeline flow dynamics (including
				  changes in operating pressure, flow rate, or volume), that are caused by
				  fluctuations in gas demand, gas receipts, or gas deliveries; or [49 CFR
				  192.635(a)(1)]
2. an unanticipated or unexplained flow rate
				  change, pressure change, equipment function, or other pipeline instrumentation
				  indication at the upstream or downstream station that may be representative of
				  an event meeting paragraph (a)(1) of this section; or [49 CFR
				  192.635(a)(2)]
3. any unanticipated or unexplained rapid
				  release of a large volume of gas, a fire, or an explosion in the immediate
				  vicinity of the pipeline. [49 CFR
				  192.635(a)(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-2901 - Scope [49 CFR 192.701]

Current through Register Vol. 50, No. 6, June 20, 2024
A. This
				  Chapter prescribes minimum requirements for maintenance of pipeline facilities.
				   [49 CFR
				  192.701]
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-2903 - General [49 CFR 192.703]

Current through Register Vol. 50, No. 6, June 20, 2024
A. No
				  person may operate a segment of pipeline, unless it is maintained in accordance
				  with this Chapter. [
				49 CFR
				  192.703(a)]
B. Each segment of pipeline that becomes
				  unsafe must be replaced, repaired, or removed from service. [
				49 CFR
				  192.703(b)]
C. Hazardous leaks must be repaired promptly.
				   [49 CFR
				  192.703(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-2905 - Transmission Lines: Patrolling [49 CFR 192.705]

Current through Register Vol. 50, No. 6, June 20, 2024
A. Each operator shall have a patrol program
				  to observe surface conditions on and adjacent to the transmission line
				  right-of-way for indications of leaks, construction activity, and other factors
				  affecting safety and operation. [
				49 CFR
				  192.705(a)]
B. The frequency of patrols is determined by
				  the size of the line, the operating pressures, the class location, terrain,
				  weather, and other relevant factors, but intervals between patrols may not be
				  longer than prescribed in the following table. [
				49 CFR
				  192.705(b)]
Maximum Interval between
								Patrols
Class Location of Line
At Highway and Railroad Crossings
At All Other Locations
1, 2
7-1/2 months; but at least twice each calendar
								year.
15 months; but at least once each calendar year.
3
4-1/2 months; but at least four times each
								calendar year.
7-1/2 months; but at least twice each calendar
								year.
4
4-1/2 months; but at least four times each
								calendar year.
4-1/2 months; but at least four times each
								calendar year.
C.
				  Methods of patrolling include walking, driving, flying or other appropriate
				  means of traversing the right-of-way. [
				49 CFR
				  192.705(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-2906 - Transmission Lines: Leakage Surveys [49 CFR 192.706]

Current through Register Vol. 50, No. 6, June 20, 2024
A. Leakage surveys of a transmission line
				  must be conducted at intervals not exceeding 15 months, but at least once each
				  calendar year. However, in the case of a transmission line which transports gas
				  in conformity with
				  §2725 without
				  an odor or odorant, leakage surveys using leak detector equipment must be
				  conducted: [
				49 CFR
				  192.706]
1.
				  in Class 3 locations, at intervals not exceeding seven and one-half months, but
				  at least twice each calendar year; and [
				49 CFR
				  192.706(a)]
2. in Class 4 locations, at intervals not
				  exceeding four and one-half months, but at least four times each calendar year.
				  [
				49 CFR
				  192.706(b)]
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-2907 - Line Markers for Mains and Transmission Lines [49 CFR 192.707]

Current through Register Vol. 50, No. 6, June 20, 2024
A. Buried
				  Pipelines. Except as provided in Subsection B of this Section, a line marker
				  must be placed and maintained as close as practical over each buried main and
				  transmission line: [
				49 CFR
				  192.707(a)]
1. at each crossing of a public road and
				  railroad; and [
				49 CFR
				  192.707(a)(1)]
2. wherever necessary to identify the
				  location of the transmission line or main to reduce the possibility of damage
				  or interference. [
				49 CFR
				  192.707(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-2909 - Transmission Lines: Record Keeping [49 CFR 192.709]

Current through Register Vol. 50, No. 6, June 20, 2024
A. Each operator shall maintain the following
				  records for transmission lines for the periods specified. [
				49 CFR
				  192.709]
1.
				  The date, location, and description of each repair made to pipe (including
				  pipe-to-pipe connections) must be retained for as long as the pipe remains in
				  service. [
				49 CFR
				  192.709(a)]
2. The date, location, and description of
				  each repair made to parts of the pipeline system other than pipe must be
				  retained for at least five years. However, repairs generated by patrols,
				  surveys, inspections, or tests required by Chapters 27 and 29 of this Subpart
				  must be retained in accordance with Paragraph A.3 of this Section. [
				49 CFR
				  192.709(b)]
3. A record of each patrol, survey,
				  inspection, and test required by Chapters 27 and 29 of this Subpart must be
				  retained for at least five years or until the next patrol, survey, inspection,
				  or test is completed, whichever is longer. [
				49 CFR
				  192.709(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-2910 - Transmission Lines: Assessments Outside of High Consequence Areas [49 CFR 192.710]

Current through Register Vol. 50, No. 6, June 20, 2024
A.
				  Applicability
1. This Section applies to
				  onshore steel transmission pipeline segments with a maximum allowable operating
				  pressure of greater than or equal to 30 percent of the specified minimum yield
				  strength and are located in: [49
				  CFR 192.710(a)]
a. a Class 3 or Class 4 location; or
				  [49
				  CFR 192.710(a)(1)]
b. a moderate consequence area as defined in
				  §503, if the pipeline segment can accommodate inspection by means of an
				  instrumented inline inspection tool (i.e., "smart
				  pig"). [49
				  CFR 192.710(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-2911 - Transmission Lines: General Requirements for Repair Procedures [49 CFR 192.711]

Current through Register Vol. 50, No. 6, June 20, 2024
A. Temporary
				  Repairs. Each operator shall take immediate temporary measures to protect the
				  public whenever: [
				49
				  CFR 192.711(a)]
1. a leak, imperfection, or damage that
				  impairs its serviceability is found in a segment of steel transmission line
				  operating at or above 40 percent of the SMYS; and [
				49
				  CFR 192.711(a)(1)]
2. it is not feasible to make a permanent
				  repair at the time of discovery. [
				49
				  CFR 192.711(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-2913 - Transmission Lines: Permanent Field Repair of Imperfections and Damages [49 CFR 192.713]

Current through Register Vol. 50, No. 6, June 20, 2024
A. Each
				  imperfection or damage that impairs the serviceability of pipe in a steel
				  transmission line operating at or above 40 percent of SMYS must be: [
				49
				  CFR 192.713(a)]
1. removed by cutting out and replacing a
				  cylindrical piece of pipe; or [
				49
				  CFR 192.713(a)(1)]
2. repaired by a method that reliable
				  engineering tests and analyses show can permanently restore the serviceability
				  of the pipe. [
				49
				  CFR 192.713(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-2915 - Transmission Lines: Permanent Field Repair of Welds [49 CFR 192.715]

Current through Register Vol. 50, No. 6, June 20, 2024
A. Each weld that
				  is unacceptable under §1321(c) must be repaired as follows. [
				49 CFR
				  192.715]
1.
				  If it is feasible to take the segment of transmission line out of service, the
				  weld must be repaired in accordance with the applicable requirements of
				  §1325 [
				49 CFR
				  192.715(a)]
2. A weld may be repaired in accordance with
				  §1325 while
				  the segment of transmission line is in service if: [
				49 CFR
				  192.715(b)]
a. the weld is not leaking; [
				49 CFR
				  192.715(b)(1)]
b. the pressure in the segment is reduced so
				  that it does not produce a stress that is more than 20 percent of the SMYS of
				  the pipe; and [
				49 CFR
				  192.715(b)(2)]
c. grinding of the defective area can be
				  limited so that at least 1/8 inch (3.2 millimeters) thickness in the pipe weld
				  remains. [
				49 CFR
				  192.715(b)(3)]
3. A defective weld which cannot
				  be repaired in accordance with Paragraph 1 or 2 of this Section must be
				  repaired by installing a full encirclement welded split sleeve of appropriate
				  design. [
				49 CFR
				  192.715(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-2917 - Transmission Lines: Permanent Field Repair of Leaks [49 CFR 192.717]

Current through Register Vol. 50, No. 6, June 20, 2024
A. Each permanent
				  field repair of a leak on a transmission line must be made by: [
				49 CFR
				  192.717]
1.
				  removing the leak by cutting out and replacing a cylindrical piece of pipe; or
				  [
				49 CFR
				  192.717(a)]
2. repairing the leak by one of the following
				  methods: [
				49 CFR
				  192.717(b)]
a. install a full encirclement welded split
				  sleeve of appropriate design, unless the transmission line is joined by
				  mechanical couplings and operates at less than 40 percent of SMYS; [
				49 CFR
				  192.717(b)(1)]
b. if the leak is due to a corrosion pit,
				  install a properly designed bolt-on-leak clamp; [
				49 CFR
				  192.717(b)(2)]
c. if the leak is due to a corrosion pit and
				  on pipe of not more than 40,000 psi (276 Mpa) SMYS, fillet weld over the pitted
				  area a steel plate patch with rounded corners, of the same or greater thickness
				  than the pipe, and not more than one-half of the diameter of the pipe in size;
				  [
				49 CFR
				  192.717(b)(3)]
d. if the leak is on a submerged offshore
				  pipeline or submerged pipeline in inland navigable waters, mechanically apply a
				  full encirclement split sleeve of appropriate design; [
				49 CFR
				  192.717(b)(4)]
e. apply a method that reliable engineering
				  tests and analyses show can permanently restore the serviceability of the pipe.
				  [
				49 CFR
				  192.717(b)(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-2919 - Transmission Lines: Testing of Repairs [49 CFR 192.719]

Current through Register Vol. 50, No. 6, June 20, 2024
A. Testing of Replacement Pipe. If a segment
				  of transmission line is repaired by cutting out the damaged portion of the pipe
				  as a cylinder, the replacement pipe must be tested to the pressure required for
				  a new line installed in the same location. This test may be made on the pipe
				  before it is installed. [
				49 CFR
				  192.719(a)]
B. Testing of Repairs Made by Welding. Each
				  repair made by welding in accordance with §§2913, 2915, and 2917 must
				  be examined in accordance with §1321 [
				49 CFR
				  192.719(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-2920 - Distribution Systems: Leak Repair [49 CFR 192.720]

Current through Register Vol. 50, No. 6, June 20, 2024
A. Mechanical leak repair clamps installed
				  after January 22, 2019 may not be used as a permanent repair method for plastic
				  pipe. [49 CFR
				  192.720]
AUTHORITY NOTE:
					 Promulgated in accordance with
					 R.S. 30:501
					 et seq.