cfr_sections
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148 rows where part_number = 195 and title_number = 49 sorted by section_id
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| section_id ▼ | title_number | title_name | chapter | subchapter | part_number | part_name | subpart | subpart_name | section_number | section_heading | agency | authority | source_citation | amendment_citations | full_text |
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| 49:49:3.1.1.2.11.1.20.1 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | A | Subpart A—General | § 195.0 Scope. | PHMSA | [Amdt. 195-45, 56 FR 26925, June 12, 1991] | This part prescribes safety standards and reporting requirements for pipeline facilities used in the transportation of hazardous liquids or carbon dioxide. | |||
| 49:49:3.1.1.2.11.1.20.10 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | A | Subpart A—General | § 195.10 Responsibility of operator for compliance with this part. | PHMSA | An operator may make arrangements with another person for the performance of any action required by this part. However, the operator is not thereby relieved from the responsibility for compliance with any requirement of this part. | ||||
| 49:49:3.1.1.2.11.1.20.11 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | A | Subpart A—General | § 195.11 What is a regulated rural gathering line and what requirements apply? | PHMSA | [73 FR 31644, June 3, 2008, as amended by Amdt. 195-105, 87 FR 20987, Apr. 8, 2022; Amdt. 195-106, 88 FR 50062, Aug. 1, 2023] | Each operator of a regulated rural gathering line, as defined in paragraph (a) of this section, must comply with the safety requirements described in paragraph (b) of this section. (a) Definition. As used in this section, a regulated rural gathering line means an onshore gathering line in a rural area that meets all of the following criteria— (1) Has a nominal diameter from 6 5/8 inches (168 mm) to 8 5/8 inches (219.1 mm); (2) Is located in or within one-quarter mile (.40 km) of an unusually sensitive area as defined in § 195.6; and (3) Operates at a maximum pressure established under § 195.406 corresponding to— (i) A stress level greater than 20-percent of the specified minimum yield strength of the line pipe; or (ii) If the stress level is unknown or the pipeline is not constructed with steel pipe, a pressure of more than 125 psi (861 kPa) gage. (b) Safety requirements. Each operator must prepare, follow, and maintain written procedures to carry out the requirements of this section. Except for the requirements in paragraphs (b)(2), (b)(3), (b)(9) and (b)(10) of this section, the safety requirements apply to all materials of construction. (1) Identify all segments of pipeline meeting the criteria in paragraph (a) of this section before April 3, 2009. (2) For steel pipelines constructed, replaced, relocated, or otherwise changed after July 3, 2009: (i) Design, install, construct, initially inspect, and initially test the pipeline in compliance with this part, unless the pipeline is converted under § 195.5. (ii) [Reserved] (3) For non-steel pipelines constructed after July 3, 2009, notify the Administrator according to § 195.8. (4) Beginning no later than January 3, 2009, comply with the reporting requirements in subpart B of this part. (5) Establish the maximum operating pressure of the pipeline according to § 195.406 before transportation begins, or if the pipeline exists on July 3, 2008, before July 3, 2009. (6) Install line markers according to § 195.410 before transportation begins, or … | |||
| 49:49:3.1.1.2.11.1.20.12 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | A | Subpart A—General | § 195.12 What requirements apply to low-stress pipelines in rural areas? | PHMSA | [76 FR 25587, May 5, 2011, as amended at 76 FR 43605, July 21, 2011] | (a) General. This Section sets forth the requirements for each category of low-stress pipeline in a rural area set forth in paragraph (b) of this Section. This Section does not apply to a rural low-stress pipeline regulated under this Part as a low-stress pipeline that crosses a waterway currently used for commercial navigation; these pipelines are regulated pursuant to § 195.1(a)(2). (b) Categories. An operator of a rural low-stress pipeline must meet the applicable requirements and compliance deadlines for the category of pipeline set forth in paragraph (c) of this Section. For purposes of this Section, a rural low-stress pipeline is a Category 1, 2, or 3 pipeline based on the following criteria: (1) A Category 1 rural low-stress pipeline: (i) Has a nominal diameter of 8 5/8 inches (219.1 mm) or more; (ii) Is located in or within one-half mile (.80 km) of an unusually sensitive area (USA) as defined in § 195.6; and (iii) Operates at a maximum pressure established under § 195.406 corresponding to: (A) A stress level equal to or less than 20-percent of the specified minimum yield strength of the line pipe; or (B) If the stress level is unknown or the pipeline is not constructed with steel pipe, a pressure equal to or less than 125 psi (861 kPa) gauge. (2) A Category 2 rural pipeline: (i) Has a nominal diameter of less than 8 5/8 inches (219.1mm); (ii) Is located in or within one-half mile (.80 km) of an unusually sensitive area (USA) as defined in § 195.6; and (iii) Operates at a maximum pressure established under § 195.406 corresponding to: (A) A stress level equal to or less than 20-percent of the specified minimum yield strength of the line pipe; or (B) If the stress level is unknown or the pipeline is not constructed with steel pipe, a pressure equal to or less than 125 psi (861 kPa) gage. (3) A Category 3 rural low-stress pipeline: (i) Has a nominal diameter of any size and is not located in or within one-half mile (.80 km) of an unusually sensitive area (USA) as defined in § 195.6; an… | |||
| 49:49:3.1.1.2.11.1.20.13 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | A | Subpart A—General | § 195.13 What requirements apply to pipelines transporting hazardous liquids by gravity? | PHMSA | [Amdt. 195-102, 84 FR 52294, Oct. 1, 2019] | (a) Scope. Pipelines transporting hazardous liquids by gravity must comply with the reporting requirements of subpart B of this part. (b) Implementation period —(1) Annual reporting. Comply with the annual reporting requirements in subpart B of this part by March 31, 2021. (2) Accident and safety-related reporting. Comply with the accident and safety-related condition reporting requirements in subpart B of this part by January 1, 2021. (c) Exceptions. (1) This section does not apply to the transportation of a hazardous liquid in a gravity line that meets the definition of a low-stress pipeline, travels no farther than 1 mile from a facility boundary, and does not cross any waterways used for commercial navigation. (2) The reporting requirements in §§ 195.52, 195.61, and 195.65 do not apply to the transportation of a hazardous liquid in a gravity line. (3) The drug and alcohol testing requirements in part 199 of this subchapter do not apply to the transportation of a hazardous liquid in a gravity line. | |||
| 49:49:3.1.1.2.11.1.20.14 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | A | Subpart A—General | § 195.15 What requirements apply to reporting-regulated-only gathering lines? | PHMSA | [Amdt. 195-102, 84 FR 52294, Oct. 1, 2019] | (a) Scope. Gathering lines that do not otherwise meet the definition of a regulated rural gathering line in § 195.11 and any gathering line not already covered under § 195.1(a)(1), (2), (3) or (4) must comply with the reporting requirements of subpart B of this part. (b) Implementation period —(1) Annual reporting. Operators must comply with the annual reporting requirements in subpart B of this part by March 31, 2021. (2) Accident and safety-related condition reporting. Operators must comply with the accident and safety-related condition reporting requirements in subpart B of this part by January 1, 2021. (c) Exceptions. (1) This section does not apply to those gathering lines that are otherwise excepted under § 195.1(b)(3), (7), (8), (9), or (10). (2) The reporting requirements in §§ 195.52, 195.61, and 195.65 do not apply to the transportation of a hazardous liquid in a gathering line that is specified in paragraph (a) of this section. (3) The drug and alcohol testing requirements in part 199 of this subchapter do not apply to the transportation of a hazardous liquid in a gathering line that is specified in paragraph (a) of this section. | |||
| 49:49:3.1.1.2.11.1.20.15 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | A | Subpart A—General | § 195.18 How to notify PHMSA. | PHMSA | [Amdt. 195-105, 87 FR 20987, Apr. 8, 2022] | (a) An operator must provide any notification required by this part by: (1) Sending the notification by electronic mail to InformationResourcesManager@dot.gov; or (2) Sending the notification by mail to ATTN: Information Resources Manager, DOT/PHMSA/OPS, East Building, 2nd Floor, E22-321, 1200 New Jersey Ave. SE, Washington, DC 20590. (b) An operator must also notify the appropriate State or local pipeline safety authority when an applicable pipeline segment is located in a State where OPS has an interstate agent agreement, or an intrastate pipeline segment is regulated by that State. (c) Unless otherwise specified, if an operator submits, pursuant to § 195.258, § 195.260, § 195.418, § 195.419, § 195.420 or § 195.452 a notification requesting use of a different integrity assessment method, analytical method, sampling approach, compliance timeline, or technique (e.g., “other technology” or “alternative equivalent technology”) than otherwise prescribed in those sections, that notification must be submitted to PHMSA for review at least 90 days in advance of using that other method, approach, compliance timeline, or technique. An operator may proceed to use the other method, approach, compliance timeline, or technique 91 days after submittal of the notification unless it receives a letter from the Associate Administrator of Pipeline Safety informing the operator that PHMSA objects to the proposal, or that PHMSA requires additional time and/or information to conduct its review. | |||
| 49:49:3.1.1.2.11.1.20.2 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | A | Subpart A—General | § 195.1 Which pipelines are covered by this Part? | PHMSA | (a) Covered. Except for the pipelines listed in paragraph (b) of this Section, this Part applies to pipeline facilities and the transportation of hazardous liquids or carbon dioxide associated with those facilities in or affecting interstate or foreign commerce, including pipeline facilities on the Outer Continental Shelf (OCS). Covered pipelines include, but are not limited to: (1) Any pipeline that transports a highly volatile liquid; (2) Any pipeline segment that crosses a waterway currently used for commercial navigation; (3) Except for a gathering line not covered by paragraph (a)(4) of this Section, any pipeline located in a rural or non-rural area of any diameter regardless of operating pressure; (4) Any of the following onshore gathering lines used for transportation of petroleum: (i) A pipeline located in a non-rural area; (ii) A regulated rural gathering line as provided in § 195.11; or (iii) A pipeline located in an inlet of the Gulf of America as provided in § 195.413. (5) For purposes of the reporting requirements in subpart B of this part, any gathering line not already covered under paragraphs (a)(1), (2), (3) or (4) of this section. (b) Excepted. This Part does not apply to any of the following: (1) Transportation of a hazardous liquid transported in a gaseous state; (2) Except for the reporting requirements of subpart B of this part, see § 195.13, transportation of a hazardous liquid through a pipeline by gravity. (3) Transportation of a hazardous liquid through any of the following low-stress pipelines: (i) A pipeline subject to safety regulations of the U.S. Coast Guard; or (ii) A pipeline that serves refining, manufacturing, or truck, rail, or vessel terminal facilities, if the pipeline is less than one mile long (measured outside facility grounds) and does not cross an offshore area or a waterway currently used for commercial navigation; (4) Except for the reporting requirements of subpart B of this part, see § 195.15, transportation of petroleum through an onshore rural ga… | ||||
| 49:49:3.1.1.2.11.1.20.3 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | A | Subpart A—General | § 195.2 Definitions. | PHMSA | [Amdt. 195-22, 46 FR 38360, July 27, 1981; 47 FR 32721, July 29, 1982] | As used in this part— Abandoned means permanently removed from service. Administrator means the Administrator, Pipeline and Hazardous Materials Safety Administration or his or her delegate. Alarm means an audible or visible means of indicating to the controller that equipment or processes are outside operator-defined, safety-related parameters. Barrel means a unit of measurement equal to 42 U.S. standard gallons. Breakout tank means a tank used to (a) relieve surges in a hazardous liquid pipeline system or (b) receive and store hazardous liquid transported by a pipeline for reinjection and continued transportation by pipeline. Carbon dioxide means a fluid consisting of more than 90 percent carbon dioxide molecules compressed to a supercritical state. Component means any part of a pipeline which may be subjected to pump pressure including, but not limited to, pipe, valves, elbows, tees, flanges, and closures. Computation Pipeline Monitoring (CPM) means a software-based monitoring tool that alerts the pipeline dispatcher of a possible pipeline operating anomaly that may be indicative of a commodity release. Confirmed Discovery means when it can be reasonably determined, based on information available to the operator at the time a reportable event has occurred, even if only based on a preliminary evaluation. Control room means an operations center staffed by personnel charged with the responsibility for remotely monitoring and controlling a pipeline facility. Controller means a qualified individual who remotely monitors and controls the safety-related operations of a pipeline facility via a SCADA system from a control room, and who has operational authority and accountability for the remote operational functions of the pipeline facility. Corrosive product means “corrosive material” as defined by § 173.136 Class 8-Definitions of this chapter. Entirely replaced onshore hazardous liquid or carbon dioxide pipeline segments, for the purposes of §§ 195.258, 195.260, and 195.418, means where 2 or … | |||
| 49:49:3.1.1.2.11.1.20.4 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | A | Subpart A—General | § 195.3 What documents are incorporated by reference partly or wholly in this part? | PHMSA | [Amdt. 195-117, 90 FR 40764, Aug. 21, 2025] | (a) Certain material is incorporated by reference into this part with the approval of the Director of the Federal Register under 5 U.S.C. 552(a) and 1 CFR part 51. All approved incorporation by reference material (IBR) is available for inspection at the Pipeline and Hazardous Materials Safety Administration (PHMSA) and the National Archives and Records Administration (NARA). Contact PHSMA at: Office of Pipeline Safety, Pipeline and Hazardous Materials Safety Administration, 1200 New Jersey Avenue SE, Washington, DC 20590; phone: 202-366-4046; website: www.phmsa.dot.gov/pipeline/regs. For information on the availability of this material at NARA, visit www.archives.gov/federal-register/cfr/ibr-locations or email fr.inspection@nara.gov. The material may be obtained from the sources in the following paragraphs of this section. (b) American Petroleum Institute (API), 200 Massachusetts Avenue NW, Suite 1100, Washington, DC 20001-5571; phone: (202) 682-8000; website: www.api.org/. (1) API 510, Pressure Vessel Inspection Code: In-service Inspection, Rating, Repair, and Alteration, 10th Edition, May 2014, Including Addendum 1 (May 2017); IBR approved for §§ 195.205(b); 195.432(c). (2) API Recommended Practice 5L1, Recommended Practice for Railroad Transportation of Line Pipe, 7th edition, September 2009, (API RP 5L1); IBR approved for § 195.207(a). (3) API Recommended Practice 5LT, Recommended Practice for Truck Transportation of Line Pipe, First edition, March 12, 2012, (API RP 5LT); IBR approved for § 195.207(c). (4) API Recommended Practice 5LW, Recommended Practice Transportation of Line Pipe on Barges and Marine Vessels, 3rd edition, September 2009, (API RP 5LW); IBR approved for § 195.207(b). (5) API Recommended Practice 651, Cathodic Protection of Aboveground Petroleum Storage Tanks, 4th edition, September 2014, (API RP 651); IBR approved for §§ 195.565; 195.573(d). (6) API Recommended Practice 652, Linings of Aboveground Petroleum Storage Tank Bottoms, 5th Edition, May 2020, (API RP 652); IBR approve… | |||
| 49:49:3.1.1.2.11.1.20.5 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | A | Subpart A—General | § 195.4 Compatibility necessary for transportation of hazardous liquids or carbon dioxide. | PHMSA | [Amdt. 195-45, 56 FR 26925, June 12, 1991] | No person may transport any hazardous liquid or carbon dioxide unless the hazardous liquid or carbon dioxide is chemically compatible with both the pipeline, including all components, and any other commodity that it may come into contact with while in the pipeline. | |||
| 49:49:3.1.1.2.11.1.20.6 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | A | Subpart A—General | § 195.5 Conversion to service subject to this part. | PHMSA | [Amdt. 195-22, 46 FR 38360, July 27, 1981, as amended by Amdt. 195-52, 59 FR 33396, June 28, 1994; Amdt. 195-173, 66 FR 67004, Dec. 27, 2001; Amdt. 195-99, 80 FR 184, Jan. 5, 2015; Amdt. 195-101, 82 FR 7999, Jan. 23, 2017; Amdts. 192-135, 195-107, 89 FR 33284, Apr. 29, 2024] | (a) A steel pipeline previously used in service not subject to this part qualifies for use under this part if the operator prepares and follows a written procedure to accomplish the following: (1) The design, construction, operation, and maintenance history of the pipeline must be reviewed and, where sufficient historical records are not available, appropriate tests must be performed to determine if the pipeline is in satisfactory condition for safe operation. If one or more of the variables necessary to verify the design pressure under § 195.106 or to perform the testing under paragraph (a)(4) of this section is unknown, the design pressure may be verified and the maximum operating pressure determined by— (i) Testing the pipeline in accordance with ASME B31.8 (incorporated by reference, see § 195.3), Appendix N, to produce a stress equal to the yield strength; and (ii) Applying, to not more than 80 percent of the first pressure that produces a yielding, the design factor F in § 195.106(a) and the appropriate factors in § 195.106(e). (2) The pipeline right-of-way, all aboveground segments of the pipeline, and appropriately selected underground segments must be visually inspected for physical defects and operating conditions which reasonably could be expected to impair the strength or tightness of the pipeline. (3) All known unsafe defects and conditions must be corrected in accordance with this part. (4) The pipeline must be tested in accordance with subpart E of this part to substantiate the maximum operating pressure permitted by § 195.406. (b) A pipeline that qualifies for use under this section need not comply with the corrosion control requirements of subpart H of this part until 12 months after it is placed into service, notwithstanding any previous deadlines for compliance. (c) Each operator must keep for the life of the pipeline a record of the investigations, tests, repairs, replacements, and alterations made under the requirements of paragraph (a) of this section. (d) An operator converting a… | |||
| 49:49:3.1.1.2.11.1.20.7 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | A | Subpart A—General | § 195.6 Unusually Sensitive Areas (USAs). | PHMSA | [Amdt. 195-71, 65 FR 80544, Dec. 21, 2000, as amended at 86 FR 73186, Dec. 27, 2021] | As used in this part, a USA means a drinking water or ecological resource area that is unusually sensitive to environmental damage from a hazardous liquid pipeline release. (a) An USA drinking water resource is: (1) The water intake for a Community Water System (CWS) or a Non-transient Non-community Water System (NTNCWS) that obtains its water supply primarily from a surface water source and does not have an adequate alternative drinking water source; (2) The Source Water Protection Area (SWPA) for a CWS or a NTNCWS that obtains its water supply from a Class I or Class IIA aquifer and does not have an adequate alternative drinking water source. Where a state has not yet identified the SWPA, the Wellhead Protection Area (WHPA) will be used until the state has identified the SWPA; or (3) The sole source aquifer recharge area where the sole source aquifer is a karst aquifer in nature. (b) An USA ecological resource is: (1) An area containing a critically imperiled species or ecological community; (2) A multi-species assemblage area; (3) A migratory waterbird concentration area; (4) An area containing an imperiled species, threatened or endangered species, depleted marine mammal species, or an imperiled ecological community where the species or community is aquatic, aquatic dependent, or terrestrial with a limited range; (5) An area containing an imperiled species, threatened or endangered species, depleted marine mammal species, or imperiled ecological community where the species or community occurrence is considered to be one of the most viable, highest quality, or in the best condition, as identified by an element occurrence ranking (EORANK) of A (excellent quality) or B (good quality) or (6) A coastal beach; or (7) Certain coastal waters. (c) Definitions used in this part— Adequate Alternative Drinking Water Source means a source of water that currently exists, can be used almost immediately with a minimal amount of effort and cost, involves no decline in water quality, and will meet the consumptiv… | |||
| 49:49:3.1.1.2.11.1.20.8 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | A | Subpart A—General | § 195.8 Transportation of hazardous liquid or carbon dioxide in pipelines constructed with other than steel pipe. | PHMSA | [Amdt. 195-45, 56 FR 26925, June 12, 1991, as amended by Amdt. 195-50, 59 FR 17281, Apr. 12, 1994] | No person may transport any hazardous liquid or carbon dioxide through a pipe that is constructed after October 1, 1970, for hazardous liquids or after July 12, 1991 for carbon dioxide of material other than steel unless the person has notified the Administrator in writing at least 90 days before the transportation is to begin. The notice must state whether carbon dioxide or a hazardous liquid is to be transported and the chemical name, common name, properties and characteristics of the hazardous liquid to be transported and the material used in construction of the pipeline. If the Administrator determines that the transportation of the hazardous liquid or carbon dioxide in the manner proposed would be unduly hazardous, he will, within 90 days after receipt of the notice, order the person that gave the notice, in writing, not to transport the hazardous liquid or carbon dioxide in the proposed manner until further notice. | |||
| 49:49:3.1.1.2.11.1.20.9 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | A | Subpart A—General | § 195.9 Outer continental shelf pipelines. | PHMSA | [Amdt. 195-59, 62 FR 61695, Nov. 19, 1997, as amended at 70 FR 11140, Mar. 8, 2005] | Operators of transportation pipelines on the Outer Continental Shelf must identify on all their respective pipelines the specific points at which operating responsibility transfers to a producing operator. For those instances in which the transfer points are not identifiable by a durable marking, each operator will have until September 15, 1998 to identify the transfer points. If it is not practicable to durably mark a transfer point and the transfer point is located above water, the operator must depict the transfer point on a schematic maintained near the transfer point. If a transfer point is located subsea, the operator must identify the transfer point on a schematic which must be maintained at the nearest upstream facility and provided to PHMSA upon request. For those cases in which adjoining operators have not agreed on a transfer point by September 15, 1998 the Regional Director and the MMS Regional Supervisor will make a joint determination of the transfer point. | |||
| 49:49:3.1.1.2.11.2.20.1 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | B | Subpart B—Annual, Accident, and Safety-Related Condition Reporting | § 195.48 Scope. | PHMSA | [76 FR 25588, May 5, 2011] | This Subpart prescribes requirements for periodic reporting and for reporting of accidents and safety-related conditions. This Subpart applies to all pipelines subject to this Part. An operator of a Category 3 rural low-stress pipeline meeting the criteria in § 195.12 is not required to complete those parts of the hazardous liquid annual report form PHMSA F 7000-1.1 associated with IM or high consequence areas. | |||
| 49:49:3.1.1.2.11.2.20.10 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | B | Subpart B—Annual, Accident, and Safety-Related Condition Reporting | § 195.60 Operator assistance in investigation. | PHMSA | If the Department of Transportation investigates an accident, the operator involved shall make available to the representative of the Department all records and information that in any way pertain to the accident, and shall afford all reasonable assistance in the investigation of the accident. | ||||
| 49:49:3.1.1.2.11.2.20.11 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | B | Subpart B—Annual, Accident, and Safety-Related Condition Reporting | § 195.61 National Pipeline Mapping System. | PHMSA | [Amdt. 195-100, 80 FR 12780, Mar. 11, 2015] | (a) Each operator of a hazardous liquid pipeline facility must provide the following geospatial data to PHMSA for that facility: (1) Geospatial data, attributes, metadata and transmittal letter appropriate for use in the National Pipeline Mapping System. Acceptable formats and additional information are specified in the NPMS Operator Standards manual available at www.npms.phmsa.dot.gov or by contacting the PHMSA Geographic Information Systems Manager at (202) 366-4595. (2) The name of and address for the operator. (3) The name and contact information of a pipeline company employee, to be displayed on a public Web site, who will serve as a contact for questions from the general public about the operator's NPMS data. (b) This information must be submitted each year, on or before June 15, representing assets as of December 31 of the previous year. If no changes have occurred since the previous year's submission, the operator must refer to the information provided in the NPMS Operator Standards manual available at www.npms.phmsa.dot.gov or contact the PHMSA Geographic Information Systems Manager at (202) 366-4595. | |||
| 49:49:3.1.1.2.11.2.20.12 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | B | Subpart B—Annual, Accident, and Safety-Related Condition Reporting | § 195.63 OMB control number assigned to information collection. | PHMSA | [Amdt. 195-95, 75 FR 72907, Nov. 26, 2010] | The control numbers assigned by the Office of Management and Budget to the hazardous liquid pipeline information collection pursuant to the Paperwork Reduction Act are 2137-0047, 2137-0601, 2137-0604, 2137-0605, 2137-0618, and 2137-0622. | |||
| 49:49:3.1.1.2.11.2.20.13 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | B | Subpart B—Annual, Accident, and Safety-Related Condition Reporting | § 195.64 National Registry of Operators. | PHMSA | [Amdt. 195-95, 75 FR 72907, Nov. 26, 2010, as amended by Amdt. 195-100, 80 FR 12780, Mar. 11, 2015; Amdt. 195-101, 82 FR 7999, Jan. 23, 2017; Amdt. 195-103, 85 FR 8127, Feb. 12, 2020] | (a) OPID Request. Effective January 1, 2012, each operator of a hazardous liquid or carbon dioxide pipeline or pipeline facility must obtain from PHMSA an Operator Identification Number (OPID). An OPID is assigned to an operator for the pipeline or pipeline system for which the operator has primary responsibility. To obtain an OPID or a change to an OPID, an operator must complete an OPID Assignment Request DOT Form PHMSA F 1000.1 through the National Registry of Operators in accordance with § 195.58. (b) OPID validation. An operator who has already been assigned one or more OPID by January 1, 2011 must validate the information associated with each such OPID through the National Registry of Operators at https://portal.phmsa.dot.gov, and correct that information as necessary, no later than June 30, 2012. (c) Changes. Each operator must notify PHMSA electronically through the National Registry of Operators at https://portal.phmsa.dot.gov, of certain events. (1) An operator must notify PHMSA of any of the following events not later than 60 days before the event occurs: (i) Construction or any planned rehabilitation, replacement, modification, upgrade, uprate, or update of a facility, other than a section of line pipe, that costs $10 million or more. If 60 day notice is not feasible because of an emergency, an operator must notify PHMSA as soon as practicable; (ii) Construction of 10 or more miles of a new or replacement hazardous liquid or carbon dioxide pipeline; (iii) Reversal of product flow direction when the reversal is expected to last more than 30 days. This notification is not required for pipeline systems already designed for bi-directional flow; or (iv) A pipeline converted for service under § 195.5, or a change in commodity as reported on the annual report as required by § 195.49. (2) An operator must notify PHMSA of any following event not later than 60 days after the event occurs: (i) A change in the primary entity responsible ( i.e. , with an assigned OPID) for managing or administering a … | |||
| 49:49:3.1.1.2.11.2.20.14 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | B | Subpart B—Annual, Accident, and Safety-Related Condition Reporting | § 195.65 Safety data sheets. | PHMSA | [Amdt. 195-102, 84 FR 52294, Oct. 1, 2019] | (a) Each owner or operator of a hazardous liquid pipeline facility, following an accident involving a pipeline facility that results in a hazardous liquid spill, must provide safety data sheets on any spilled hazardous liquid to the designated Federal On-Scene Coordinator and appropriate State and local emergency responders within 6 hours of a telephonic or electronic notice of the accident to the National Response Center. (b) Definitions. In this section: (1) Federal On-Scene Coordinator. The term “Federal On-Scene Coordinator” has the meaning given such term in section 311(a) of the Federal Water Pollution Control Act (33 U.S.C. 1321(a)). (2) National Response Center. The term “National Response Center” means the center described under 40 CFR 300.125(a). (3) Safety data sheet. The term “safety data sheet” means a safety data sheet required under 29 CFR 1910.1200. | |||
| 49:49:3.1.1.2.11.2.20.2 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | B | Subpart B—Annual, Accident, and Safety-Related Condition Reporting | § 195.49 Annual report. | PHMSA | [75 FR 72907, Nov. 26, 2010] | Each operator must annually complete and submit DOT Form PHMSA F 7000-1.1 for each type of hazardous liquid pipeline facility operated at the end of the previous year. An operator must submit the annual report by June 15 each year, except that for the 2010 reporting year the report must be submitted by August 15, 2011. A separate report is required for crude oil, HVL (including anhydrous ammonia), petroleum products, carbon dioxide pipelines, and fuel grade ethanol pipelines. For each state a pipeline traverses, an operator must separately complete those sections on the form requiring information to be reported for each state. | |||
| 49:49:3.1.1.2.11.2.20.3 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | B | Subpart B—Annual, Accident, and Safety-Related Condition Reporting | § 195.50 Reporting accidents. | PHMSA | [Amdt. 195-22, 46 FR 38360, July 27, 1981, as amended by Amdt. 195-39, 53 FR 24950, July 1, 1988; Amdt. 195-45, 56 FR 26925, June 12, 1991; Amdt. 195-52, 59 FR 33396, June 28, 1994; Amdt. 195-63, 63 FR 37506, July 13, 1998; Amdt. 195-75, 67 FR 836, Jan. 8, 2002] | An accident report is required for each failure in a pipeline system subject to this part in which there is a release of the hazardous liquid or carbon dioxide transported resulting in any of the following: (a) Explosion or fire not intentionally set by the operator. (b) Release of 5 gallons (19 liters) or more of hazardous liquid or carbon dioxide, except that no report is required for a release of less than 5 barrels (0.8 cubic meters) resulting from a pipeline maintenance activity if the release is: (1) Not otherwise reportable under this section; (2) Not one described in § 195.52(a)(4); (3) Confined to company property or pipeline right-of-way; and (4) Cleaned up promptly; (c) Death of any person; (d) Personal injury necessitating hospitalization; (e) Estimated property damage, including cost of clean-up and recovery, value of lost product, and damage to the property of the operator or others, or both, exceeding $50,000. | |||
| 49:49:3.1.1.2.11.2.20.4 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | B | Subpart B—Annual, Accident, and Safety-Related Condition Reporting | § 195.52 Immediate notice of certain accidents. | PHMSA | [75 FR 72907, Nov. 26, 2010, as amended by Amdt. 195-101, 82 FR 7999, Jan. 23, 2017] | (a) Notice requirements. At the earliest practicable moment following discovery, of a release of the hazardous liquid or carbon dioxide transported resulting in an event described in § 195.50, but no later than one hour after confirmed discovery, the operator of the system must give notice, in accordance with paragraph (b) of this section of any failure that: (1) Caused a death or a personal injury requiring hospitalization; (2) Resulted in either a fire or explosion not intentionally set by the operator; (3) Caused estimated property damage, including cost of cleanup and recovery, value of lost product, and damage to the property of the operator or others, or both, exceeding $50,000; (4) Resulted in pollution of any stream, river, lake, reservoir, or other similar body of water that violated applicable water quality standards, caused a discoloration of the surface of the water or adjoining shoreline, or deposited a sludge or emulsion beneath the surface of the water or upon adjoining shorelines; or (5) In the judgment of the operator was significant even though it did not meet the criteria of any other paragraph of this section. (b) Information required. Each notice required by paragraph (a) of this section must be made to the National Response Center either by telephone to 800-424-8802 (in Washington, DC, 202-267-2675) or electronically at http://www.nrc.uscg.mil and must include the following information: (1) Name, address and identification number of the operator. (2) Name and telephone number of the reporter. (3) The location of the failure. (4) The time of the failure. (5) The fatalities and personal injuries, if any. (6) Initial estimate of amount of product released in accordance with paragraph (c) of this section. (7) All other significant facts known by the operator that are relevant to the cause of the failure or extent of the damages. (c) Calculation. A pipeline operator must have a written procedure to calculate and provide a reasonable initial estimate of the amount of released pro… | |||
| 49:49:3.1.1.2.11.2.20.5 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | B | Subpart B—Annual, Accident, and Safety-Related Condition Reporting | § 195.54 Accident reports. | PHMSA | [Amdt. 195-39, 53 FR 24950, July 1, 1988, as amended by Amdt. 195-95, 75 FR 72907, Nov. 26, 2010; Amdt. 195-117, 90 FR 40766, Aug. 21, 2025] | (a) Each operator that experiences an accident that is required to be reported under § 195.50 must, as soon as practicable, but not later than 30 days after discovery of the accident, file an accident report on DOT Form 7000-1 or 7000-2, whichever is applicable. (b) Whenever an operator receives any changes in the information reported or additions to the original report on DOT Form 7000-1 or 7000-2, whichever is applicable, it shall file a supplemental report within 30 days. | |||
| 49:49:3.1.1.2.11.2.20.6 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | B | Subpart B—Annual, Accident, and Safety-Related Condition Reporting | § 195.55 Reporting safety-related conditions. | PHMSA | [Amdt. 195-39, 53 FR 24950, July 1, 1988; 53 FR 29800, Aug. 8, 1988, as amended by Amdt. 195-63, 63 FR 37506, July 13, 1998] | (a) Except as provided in paragraph (b) of this section, each operator shall report in accordance with § 195.56 the existence of any of the following safety-related conditions involving pipelines in service: (1) General corrosion that has reduced the wall thickness to less than that required for the maximum operating pressure, and localized corrosion pitting to a degree where leakage might result. (2) Unintended movement or abnormal loading of a pipeline by environmental causes, such as an earthquake, landslide, or flood, that impairs its serviceability. (3) Any material defect or physical damage that impairs the serviceability of a pipeline. (4) Any malfunction or operating error that causes the pressure of a pipeline to rise above 110 percent of its maximum operating pressure. (5) A leak in a pipeline that constitutes an emergency. (6) Any safety-related condition that could lead to an imminent hazard and causes (either directly or indirectly by remedial action of the operator), for purposes other than abandonment, a 20 percent or more reduction in operating pressure or shutdown of operation of a pipeline. (b) A report is not required for any safety-related condition that— (1) Exists on a pipeline that is more than 220 yards (200 meters) from any building intended for human occupancy or outdoor place of assembly, except that reports are required for conditions within the right-of-way of an active railroad, paved road, street, or highway, or that occur offshore or at onshore locations where a loss of hazardous liquid could reasonably be expected to pollute any stream, river, lake, reservoir, or other body of water; (2) Is an accident that is required to be reported under § 195.50 or results in such an accident before the deadline for filing the safety-related condition report; or (3) Is corrected by repair or replacement in accordance with applicable safety standards before the deadline for filing the safety-related condition report, except that reports are required for all conditions under paragraph (… | |||
| 49:49:3.1.1.2.11.2.20.7 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | B | Subpart B—Annual, Accident, and Safety-Related Condition Reporting | § 195.56 Filing safety-related condition reports. | PHMSA | [Amdt. 195-39, 53 FR 24950, July 1, 1988; 53 FR 29800, Aug. 8, 1988, as amended by Amdt. 195-42, 54 FR 32344, Aug. 7, 1989; Amdt. 195-44, 54 FR 40878, Oct. 4, 1989; Amdt. 195-50, 59 FR 17281, Apr. 12, 1994; Amdt. 195-61, 63 FR 7723, Feb. 17, 1998; Amdt. 195-100, 80 FR 12780, Mar. 11, 2015] | (a) Each report of a safety-related condition under § 195.55(a) must be filed (received by OPS) within five working days (not including Saturday, Sunday, or Federal Holidays) after the day a representative of the operator first determines that the condition exists, but not later than 10 working days after the day a representative of the operator discovers the condition. Separate conditions may be described in a single report if they are closely related. Reports may be transmitted by electronic mail to InformationResourcesManager@dot.gov, or by facsimile at (202) 366-7128. (b) The report must be headed “Safety-Related Condition Report” and provide the following information: (1) Name and principal address of operator. (2) Date of report. (3) Name, job title, and business telephone number of person submitting the report. (4) Name, job title, and business telephone number of person who determined that the condition exists. (5) Date condition was discovered and date condition was first determined to exist. (6) Location of condition, with reference to the State (and town, city, or county) or offshore site, and as appropriate nearest street address, offshore platform, survey station number, milepost, landmark, or name of pipeline. (7) Description of the condition, including circumstances leading to its discovery, any significant effects of the condition on safety, and the name of the commodity transported or stored. (8) The corrective action taken (including reduction of pressure or shutdown) before the report is submitted and the planned follow-up or future corrective action, including the anticipated schedule for starting and concluding such action. | |||
| 49:49:3.1.1.2.11.2.20.8 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | B | Subpart B—Annual, Accident, and Safety-Related Condition Reporting | § 195.58 Report submission requirements. | PHMSA | [Amdt. 195-95, 75 FR 72907, Nov. 26, 2010, as amended by Amdt. 195-100, 80 FR 12780, Mar. 11, 2015; Amdts. 192-135, 195-107, 89 FR 33284, Apr. 29, 2024] | (a) General. Except as provided in paragraphs (b) and (e) of this section, an operator must submit each report required by this part electronically to PHMSA at https://portal.phmsa.dot.gov unless an alternative reporting method is authorized in accordance with paragraph (d) of this section. (b) Exceptions: An operator is not required to submit a safety-related condition report (§ 195.56) electronically. (c) Safety-related conditions. An operator must submit concurrently to the applicable State agency a safety-related condition report required by § 195.55 for an intrastate pipeline or when the State agency acts as an agent of the Secretary with respect to interstate pipelines. (d) Alternate Reporting Method. If electronic reporting imposes an undue burden and hardship, the operator may submit a written request for an alternative reporting method to the Information Resources Manager, Office of Pipeline Safety, Pipeline and Hazardous Materials Safety Administration, PHP-20, 1200 New Jersey Avenue, SE., Washington DC 20590. The request must describe the undue burden and hardship. PHMSA will review the request and may authorize, in writing, an alternative reporting method. An authorization will state the period for which it is valid, which may be indefinite. An operator must contact PHMSA at 202-366-8075, or electronically to “ informationresourcesmanager@dot.gov” to make arrangements for submitting a report that is due after a request for alternative reporting is submitted but before an authorization or denial is received. (e) National Pipeline Mapping System (NPMS). An operator must provide NPMS data to the address identified in the NPMS Operator Standards Manual available at www.npms.phmsa.dot.gov or by contacting the PHMSA Geographic Information Systems Manager at (202) 366-4595. | |||
| 49:49:3.1.1.2.11.2.20.9 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | B | Subpart B—Annual, Accident, and Safety-Related Condition Reporting | § 195.59 Abandonment or deactivation of facilities. | PHMSA | [Amdt. 195-69, 65 FR 54444, Sept. 8, 2000, as amended at 70 FR 11140, Mar. 8, 2005; Amdt. 195-86, 72 FR 4657, Feb. 1, 2007; 73 FR 16570, Mar. 28, 2008; 74 FR 2894, Jan. 16, 2009; Amdts. 192-135, 195-107, 89 FR 33284, Apr. 29, 2024] | For each abandoned offshore pipeline facility or each abandoned onshore pipeline facility that crosses over, under or through a commercially navigable waterway, the last operator of that facility must file a report upon abandonment of that facility. (a) The preferred method to submit data on pipeline facilities abandoned after October 10, 2000, is to the National Pipeline Mapping System (NPMS) in accordance with the NPMS “Standards for Pipeline and Liquefied Natural Gas Operator Submissions.” To obtain a copy of the NPMS standards, please refer to the NPMS homepage at https://www.npms.phmsa.dot.gov. A digital data format is preferred, but hard copy submissions are acceptable if they comply with the NPMS Standards. In addition to the NPMS-required attributes, operators must submit the date of abandonment, diameter, method of abandonment, and certification that, to the best of the operator's knowledge, all of the reasonably available information requested was provided and, to the best of the operator's knowledge, the abandonment was completed in accordance with applicable laws. Refer to the NPMS Standards for details in preparing your data for submission. The NPMS Standards also include details of how to submit data. Alternatively, operators may submit reports by mail, fax or email to the Office of Pipeline Safety, Pipeline and Hazardous Materials Safety Administration, U.S. Department of Transportation, Information Resources Manager, PHP-10, 1200 New Jersey Avenue SE, Washington, DC 20590-0001; fax: (202) 366-4566; email: InformationResourcesManager@dot.gov. The information in the report must contain all reasonably available information related to the facility, including information in the possession of a third party. The report must contain the location, size, date, method of abandonment, and a certification that the facility has been abandoned in accordance with all applicable laws. (b) [Reserved] | |||
| 49:49:3.1.1.2.11.3.20.1 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | C | Subpart C—Design Requirements | § 195.100 Scope. | PHMSA | This subpart prescribes minimum design requirements for new pipeline systems constructed with steel pipe and for relocating, replacing, or otherwise changing existing systems constructed with steel pipe. However, it does not apply to the movement of line pipe covered by § 195.424. | ||||
| 49:49:3.1.1.2.11.3.20.10 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | C | Subpart C—Design Requirements | § 195.114 Used pipe. | PHMSA | [Amdt. 195-22, 46 FR 38360, July 27, 1981; 47 FR 32721, July 29, 1982] | Any used pipe installed in a pipeline system must comply with § 195.112 (a) and (b) and the following: (a) The pipe must be of a known specification and the seam joint factor must be determined in accordance with § 195.106(e). If the specified minimum yield strength or the wall thickness is not known, it is determined in accordance with § 195.106 (b) or (c) as appropriate. (b) There may not be any: (1) Buckles; (2) Cracks, grooves, gouges, dents, or other surface defects that exceed the maximum depth of such a defect permitted by the specification to which the pipe was manufactured; or (3) Corroded areas where the remaining wall thickness is less than the minimum thickness required by the tolerances in the specification to which the pipe was manufactured. However, pipe that does not meet the requirements of paragraph (b)(3) of this section may be used if the operating pressure is reduced to be commensurate with the remaining wall thickness. | |||
| 49:49:3.1.1.2.11.3.20.11 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | C | Subpart C—Design Requirements | § 195.116 Valves. | PHMSA | [Amdt. 195-22, 46 FR 38360, July 27, 1981, as amended by Amdt. 195-45, 56 FR 26926, June 12, 1991; Amdt. 195-86, 71 FR 33410, June 9, 2006; Amdt. 195-94, 75 FR 48606, Aug. 11, 2010; Amdt. 195-99, 80 FR 186, Jan. 5, 2015; Amdts. 192-135, 195-107, 89 FR 33284, Apr. 29, 2024] | Each valve installed in a pipeline system must comply with the following: (a) The valve must be of a sound engineering design. (b) Materials subject to the internal pressure of the pipeline system, including welded and flanged ends, must be compatible with the pipe or fittings to which the valve is attached. (c) Each part of the valve that will be in contact with the carbon dioxide or hazardous liquid stream must be made of materials that are compatible with carbon dioxide or each hazardous liquid that it is anticipated will flow through the pipeline system. (d) Each valve must be both hydrostatically shell tested and hydrostatically seat tested without leakage to at least the requirements set forth in Section 11 of API Spec 6D (incorporated by reference, see § 195.3). (e) Each valve other than a check valve must be equipped with a means for clearly indicating the position of the valve (open, closed, etc.). (f) Each valve must be marked on the body or the nameplate, with at least the following: (1) Manufacturer's name or trademark. (2) Class designation or the maximum working pressure to which the valve may be subjected. (3) Body material designation (the end connection material, if more than one type is used). (4) Nominal valve size. | |||
| 49:49:3.1.1.2.11.3.20.12 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | C | Subpart C—Design Requirements | § 195.118 Fittings. | PHMSA | [Amdt. 195-22, 46 FR 38360, July 27, 1981; 47 FR 32721, July 29, 1982, as amended at 58 FR 14524, Mar. 18, 1993; Amdt. 195-99, 80 FR 186, Jan. 5, 2015] | (a) Butt-welding type fittings must meet the marking, end preparation, and the bursting strength requirements of ASME/ANSI B16.9 or MSS SP-75 (incorporated by reference, see § 195.3). (b) There may not be any buckles, dents, cracks, gouges, or other defects in the fitting that might reduce the strength of the fitting. (c) The fitting must be suitable for the intended service and be at least as strong as the pipe and other fittings in the pipeline system to which it is attached. | |||
| 49:49:3.1.1.2.11.3.20.13 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | C | Subpart C—Design Requirements | § 195.120 Passage of internal inspection devices. | PHMSA | [Amdt. 195-102, 84 FR 52294, Oct. 1, 2019] | (a) General. Except as provided in paragraphs (b) and (c) of this section, each new pipeline and each main line section of a pipeline where the line pipe, valve, fitting or other line component is replaced must be designed and constructed to accommodate the passage of instrumented internal inspection devices in accordance with NACE SP0102 (incorporated by reference, see § 195.3). (b) Exceptions. This section does not apply to: (1) Manifolds; (2) Station piping such as at pump stations, meter stations, or pressure reducing stations; (3) Piping associated with tank farms and other storage facilities; (4) Cross-overs; (5) Pipe for which an instrumented internal inspection device is not commercially available; and (6) Offshore pipelines, other than lines 10 inches (254 millimeters) or greater in nominal diameter, that transport liquids to onshore facilities. (c) Impracticability. An operator may file a petition under § 190.9 for a finding that the requirements in paragraph (a) of this section should not be applied to a pipeline for reasons of impracticability. (d) Emergencies. An operator need not comply with paragraph (a) of this section in constructing a new or replacement segment of a pipeline in an emergency. Within 30 days after discovering the emergency, the operator must file a petition under § 190.9 for a finding that requiring the design and construction of the new or replacement pipeline segment to accommodate passage of instrumented internal inspection devices would be impracticable as a result of the emergency. If PHMSA denies the petition, within 1 year after the date of the notice of the denial, the operator must modify the new or replacement pipeline segment to allow passage of instrumented internal inspection devices. | |||
| 49:49:3.1.1.2.11.3.20.14 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | C | Subpart C—Design Requirements | § 195.122 Fabricated branch connections. | PHMSA | Each pipeline system must be designed so that the addition of any fabricated branch connections will not reduce the strength of the pipeline system. | ||||
| 49:49:3.1.1.2.11.3.20.15 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | C | Subpart C—Design Requirements | § 195.124 Closures. | PHMSA | [Amdt. 195-99, 80 FR 186, Jan. 5, 2015] | Each closure to be installed in a pipeline system must comply with the 2007 ASME Boiler and Pressure Vessel Code (BPVC) (Section VIII, Division 1) (incorporated by reference, see § 195.3) and must have pressure and temperature ratings at least equal to those of the pipe to which the closure is attached. | |||
| 49:49:3.1.1.2.11.3.20.16 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | C | Subpart C—Design Requirements | § 195.126 Flange connection. | PHMSA | Each component of a flange connection must be compatible with each other component and the connection as a unit must be suitable for the service in which it is to be used. | ||||
| 49:49:3.1.1.2.11.3.20.17 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | C | Subpart C—Design Requirements | § 195.128 Station piping. | PHMSA | Any pipe to be installed in a station that is subject to system pressure must meet the applicable requirements of this subpart. | ||||
| 49:49:3.1.1.2.11.3.20.18 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | C | Subpart C—Design Requirements | § 195.130 Fabricated assemblies. | PHMSA | Each fabricated assembly to be installed in a pipeline system must meet the applicable requirements of this subpart. | ||||
| 49:49:3.1.1.2.11.3.20.19 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | C | Subpart C—Design Requirements | § 195.132 Design and construction of aboveground breakout tanks. | PHMSA | [Amdt. 195-66, 64 FR 15935, Apr. 2, 1999, as amended by Amdt. 195-99, 80 FR 186, Jan. 5, 2015; 80 FR 46848, Aug. 6, 2015] | (a) Each aboveground breakout tank must be designed and constructed to withstand the internal pressure produced by the hazardous liquid to be stored therein and any anticipated external loads. (b) For aboveground breakout tanks first placed in service after October 2, 2000, compliance with paragraph (a) of this section requires one of the following: (1) Shop-fabricated, vertical, cylindrical, closed top, welded steel tanks with nominal capacities of 90 to 750 barrels (14.3 to 119.2 m 3 ) and with internal vapor space pressures that are approximately atmospheric must be designed and constructed in accordance with API Spec 12F (incorporated by reference, see § 195.3) . (2) Welded, low-pressure ( i.e. , internal vapor space pressure not greater than 15 psig (103.4 kPa)), carbon steel tanks that have wall shapes that can be generated by a single vertical axis of revolution must be designed and constructed in accordance with API Std 620 (incorporated by reference, see § 195.3). (3) Vertical, cylindrical, welded steel tanks with internal pressures at the tank top approximating atmospheric pressures ( i.e. , internal vapor space pressures not greater than 2.5 psig (17.2 kPa), or not greater than the pressure developed by the weight of the tank roof) must be designed and constructed in accordance with API Std 650 (incorporated by reference, see § 195.3). (4) High pressure steel tanks ( i.e. , internal gas or vapor space pressures greater than 15 psig (103.4 kPa)) with a nominal capacity of 2000 gallons (7571 liters) or more of liquefied petroleum gas (LPG) must be designed and constructed in accordance with API Std 2510 (incorporated by reference, see § 195.3). | |||
| 49:49:3.1.1.2.11.3.20.2 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | C | Subpart C—Design Requirements | § 195.101 Qualifying metallic components other than pipe. | PHMSA | [Amdt. 195-28, 48 FR 30639, July 5, 1983] | Notwithstanding any requirement of the subpart which incorporates by reference an edition of a document listed in § 195.3, a metallic component other than pipe manufactured in accordance with any other edition of that document is qualified for use if— (a) It can be shown through visual inspection of the cleaned component that no defect exists which might impair the strength or tightness of the component: and (b) The edition of the document under which the component was manufactured has equal or more stringent requirements for the following as an edition of that document currently or previously listed in § 195.3: (1) Pressure testing; (2) Materials; and (3) Pressure and temperature ratings. | |||
| 49:49:3.1.1.2.11.3.20.20 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | C | Subpart C—Design Requirements | § 195.134 Leak detection. | PHMSA | [Amdt. 195-102, 84 FR 52295, Oct. 1, 2019] | (a) Scope. This section applies to each hazardous liquid pipeline transporting liquid in single phase (without gas in the liquid). (b) General. (1) For each pipeline constructed prior to October 1, 2019. Each pipeline must have a system for detecting leaks that complies with the requirements in § 195.444 by October 1, 2024. (2) For each pipeline constructed on or after October 1, 2019. Each pipeline must have a system for detecting leaks that complies with the requirements in § 195.444 by October 1, 2020. (c) CPM leak detection systems. A new computational pipeline monitoring (CPM) leak detection system or replaced component of an existing CPM system must be designed in accordance with the requirements in section 4.2 of API RP 1130 (incorporated by reference, see § 195.3) and any other applicable design criteria in that standard. (d) Exception. The requirements of paragraph (b) of this section do not apply to offshore gathering or regulated rural gathering lines. | |||
| 49:49:3.1.1.2.11.3.20.3 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | C | Subpart C—Design Requirements | § 195.102 Design temperature. | PHMSA | [Amdt. 195-45, 56 FR 26925, June 12, 1991] | (a) Material for components of the system must be chosen for the temperature environment in which the components will be used so that the pipeline will maintain its structural integrity. (b) Components of carbon dioxide pipelines that are subject to low temperatures during normal operation because of rapid pressure reduction or during the initial fill of the line must be made of materials that are suitable for those low temperatures. | |||
| 49:49:3.1.1.2.11.3.20.4 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | C | Subpart C—Design Requirements | § 195.104 Variations in pressure. | PHMSA | If, within a pipeline system, two or more components are to be connected at a place where one will operate at a higher pressure than another, the system must be designed so that any component operating at the lower pressure will not be overstressed. | ||||
| 49:49:3.1.1.2.11.3.20.5 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | C | Subpart C—Design Requirements | § 195.106 Internal design pressure. | PHMSA | [Amdt. 195-22, 46 FR 38360, July 27, 1981; 47 FR 32721, July 29, 1982, as amended by Amdt. 195-30, 49 FR 7569, Mar. 1, 1984; Amdt. 195-37, 51 FR 15335, Apr. 23, 1986; Amdt. 195-40, 54 FR 5628, Feb. 6, 1989; 58 FR 14524, Mar. 18, 1993; Amdt. 195-50, 59 FR 17281, Apr. 12, 1994; Amdt. 195-52, 59 FR 33396, 33397, June 28, 1994; Amdt. 195-63, 63 FR 37506, July 13, 1998; Amdt. 195-99, 80 FR 185, Jan. 5, 2015; Amdts. 192-135, 195-107, 89 FR 33284, Apr. 29, 2024] | (a) Internal design pressure for the pipe in a pipeline is determined in accordance with the following formula: P = (2 St/D ) × E × F P = Internal design pressure in p.s.i. (kPa) gage. S = Yield strength in pounds per square inch (kPa) determined in accordance with paragraph (b) of this section. t = Nominal wall thickness of the pipe in inches (millimeters). If this is unknown, it is determined in accordance with paragraph (c) of this section. D = Nominal outside diameter of the pipe in inches (millimeters). E = Seam joint factor determined in accordance with paragraph (e) of this section. F = A design factor of 0.72, except that a design factor of 0.60 is used for pipe, including risers, on a platform located offshore or on a platform in inland navigable waters, and 0.54 is used for pipe that has been subjected to cold expansion to meet the specified minimum yield strength and is subsequently heated, other than by welding or stress relieving as a part of welding, to a temperature higher than 900 °F (482 °C) for any period of time or over 600 °F (316 °C) for more than 1 hour. P = Internal design pressure in p.s.i. (kPa) gage. S = Yield strength in pounds per square inch (kPa) determined in accordance with paragraph (b) of this section. t = Nominal wall thickness of the pipe in inches (millimeters). If this is unknown, it is determined in accordance with paragraph (c) of this section. D = Nominal outside diameter of the pipe in inches (millimeters). E = Seam joint factor determined in accordance with paragraph (e) of this section. F = A design factor of 0.72, except that a design factor of 0.60 is used for pipe, including risers, on a platform located offshore or on a platform in inland navigable waters, and 0.54 is used for pipe that has been subjected to cold expansion to meet the specified minimum yield strength and is subsequently heated, other than by welding or stress relieving as a part of welding, to a temperature higher than 900 °F (482 °C) for any period of time or o… | |||
| 49:49:3.1.1.2.11.3.20.6 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | C | Subpart C—Design Requirements | § 195.108 External pressure. | PHMSA | Any external pressure that will be exerted on the pipe must be provided for in designing a pipeline system. | ||||
| 49:49:3.1.1.2.11.3.20.7 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | C | Subpart C—Design Requirements | § 195.110 External loads. | PHMSA | [Amdt. 195-22, 46 FR 38360, July 27, 1981, as amended at 58 FR 14524, Mar. 18, 1993; Amdts. 192-135, 195-107, 89 FR 33284, Apr. 29, 2024; Amdt. 195-117, 90 FR 40766, Aug. 21, 2025] | (a) Anticipated external loads ( e.g., earthquakes, vibration, thermal expansion, and contraction) must be provided for in a pipeline system's design. Sections 401, 402, 403.3, and 403.9 of ASME B31.4 (incorporated by reference, see § 195.3) must be followed to provide for expansion and flexibility. (b) The pipe and other components must be supported in such a way that the support does not cause excess localized stresses. In designing attachments to pipe, the added stress to the wall of the pipe must be computed and compensated for. | |||
| 49:49:3.1.1.2.11.3.20.8 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | C | Subpart C—Design Requirements | § 195.111 Fracture propagation. | PHMSA | [Amdt. 195-45, 56 FR 26926, June 12, 1991] | A carbon dioxide pipeline system must be designed to mitigate the effects of fracture propagation. | |||
| 49:49:3.1.1.2.11.3.20.9 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | C | Subpart C—Design Requirements | § 195.112 New pipe. | PHMSA | [Amdt. 195-22, 46 FR 38360, July 27, 1981, as amended by Amdt. 195-52, 59 FR 33396, June 28, 1994; Amdt. 195-63, 63 FR 37506, July 13, 1998] | Any new pipe installed in a pipeline system must comply with the following: (a) The pipe must be made of steel of the carbon, low alloy-high strength, or alloy type that is able to withstand the internal pressures and external loads and pressures anticipated for the pipeline system. (b) The pipe must be made in accordance with a written pipe specification that sets forth the chemical requirements for the pipe steel and mechanical tests for the pipe to provide pipe suitable for the use intended. (c) Each length of pipe with a nominal outside diameter of 4 1/2 in (114.3 mm) or more must be marked on the pipe or pipe coating with the specification to which it was made, the specified minimum yield strength or grade, and the pipe size. The marking must be applied in a manner that does not damage the pipe or pipe coating and must remain visible until the pipe is installed. | |||
| 49:49:3.1.1.2.11.4.20.1 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | D | Subpart D—Construction | § 195.200 Scope. | PHMSA | This subpart prescribes minimum requirements for constructing new pipeline systems with steel pipe, and for relocating, replacing, or otherwise changing existing pipeline systems that are constructed with steel pipe. However, this subpart does not apply to the movement of pipe covered by § 195.424. | ||||
| 49:49:3.1.1.2.11.4.20.10 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | D | Subpart D—Construction | § 195.214 Welding procedures. | PHMSA | [Amdt. 195-38, 51 FR 20297, June 4, 1986, as amended at Amdt. 195-81, 69 FR 32897, June 14, 2004; Amdt. 195-99, 80 FR 186, Jan. 5, 2015; Amdt. 195-100, 80 FR 12780, Mar. 11, 2015; Amdt. 195-101, 82 FR 7999, Jan. 23, 2017; Amdts. 192-135, 195-107, 89 FR 33284, Apr. 29, 2024] | (a) Welding must be performed by a qualified welder or welding operator in accordance with welding procedures qualified under section 5 (except for Note 2 in section 5.4.2.2), section 12, Appendix A or Appendix B of API Std 1104 (incorporated by reference, see § 195.3), or Section IX of the ASME Boiler and Pressure Vessel Code (ASME BPVC) (incorporated by reference, see § 195.3). The quality of the test welds used to qualify the welding procedures must be determined by destructive testing. (b) Each welding procedure must be recorded in detail, including the results of the qualifying tests. This record must be retained and followed whenever the procedure is used. | |||
| 49:49:3.1.1.2.11.4.20.11 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | D | Subpart D—Construction | § 195.216 Welding: Miter joints. | PHMSA | A miter joint is not permitted (not including deflections up to 3 degrees that are caused by misalignment). | ||||
| 49:49:3.1.1.2.11.4.20.12 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | D | Subpart D—Construction | § 195.222 Welders and welding operators: Qualification of welders and welding operators. | PHMSA | [Amdt. 195-81, 69 FR 54593, Sept. 9, 2004, as amended by Amdt. 195-86, 71 FR 33409, June 9, 2006; Amdt. 195-99, 80 FR 186, Jan. 5, 2015; Amdt. 195-100, 80 FR 12780, Mar. 11, 2015; Amdt. 195-101, 82 FR 7999, Jan. 23, 2017] | (a) Each welder or welding operator must be qualified in accordance with section 6, section 12, Appendix A or Appendix B of API Std 1104 (incorporated by reference, see § 195.3), or section IX of the ASME Boiler and Pressure Vessel Code (ASME BPVC), (incorporated by reference, see § 195.3) except that a welder or welding operator qualified under an earlier edition than listed in § 195.3, may weld but may not requalify under that earlier edition. (b) No welder or welding operator may weld with a welding process unless, within the preceding 6 calendar months, the welder or welding operator has— (1) Engaged in welding with that process; and (2) Had one weld tested and found acceptable under section 9 or Appendix A of API Std 1104 (incorporated by reference, see § 195.3). | |||
| 49:49:3.1.1.2.11.4.20.13 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | D | Subpart D—Construction | § 195.224 Welding: Weather. | PHMSA | Welding must be protected from weather conditions that would impair the quality of the completed weld. | ||||
| 49:49:3.1.1.2.11.4.20.14 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | D | Subpart D—Construction | § 195.226 Welding: Arc burns. | PHMSA | (a) Each arc burn must be repaired. (b) An arc burn may be repaired by completely removing the notch by grinding, if the grinding does not reduce the remaining wall thickness to less than the minimum thickness required by the tolerances in the specification to which the pipe is manufactured. If a notch is not repairable by grinding, a cylinder of the pipe containing the entire notch must be removed. (c) A ground may not be welded to the pipe or fitting that is being welded. | ||||
| 49:49:3.1.1.2.11.4.20.15 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | D | Subpart D—Construction | § 195.228 Welds and welding inspection: Standards of acceptability. | PHMSA | [Amdt. 195-22, 46 FR 38360, July 27, 1981, as amended by Amdt. 195-52, 59 FR 33397, June 28, 1994; Amdt. 195-81, 69 FR 32898, June 14, 2004; Amdt. 195-99, 80 FR 186, Jan. 5, 2015; Amdt. 195-100, 80 FR 12780, Mar. 11, 2015] | (a) Each weld and welding must be inspected to insure compliance with the requirements of this subpart. Visual inspection must be supplemented by nondestructive testing. (b) The acceptability of a weld is determined according to the standards in section 9 or Appendix A of API Std 1104 (incorporated by reference, see § 195.3). Appendix A of API Std 1104 may not be used to accept cracks. | |||
| 49:49:3.1.1.2.11.4.20.16 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | D | Subpart D—Construction | § 195.230 Welds: Repair or removal of defects. | PHMSA | [Amdt. 195-29, 48 FR 48674, Oct. 20, 1983] | (a) Each weld that is unacceptable under § 195.228 must be removed or repaired. Except for welds on an offshore pipeline being installed from a pipelay vessel, a weld must be removed if it has a crack that is more than 8 percent of the weld length. (b) Each weld that is repaired must have the defect removed down to sound metal and the segment to be repaired must be preheated if conditions exist which would adversely affect the quality of the weld repair. After repair, the segment of the weld that was repaired must be inspected to ensure its acceptability. (c) Repair of a crack, or of any defect in a previously repaired area must be in accordance with written weld repair procedures that have been qualified under § 195.214. Repair procedures must provide that the minimum mechanical properties specified for the welding procedure used to make the original weld are met upon completion of the final weld repair. | |||
| 49:49:3.1.1.2.11.4.20.17 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | D | Subpart D—Construction | § 195.234 Welds: Nondestructive testing. | PHMSA | [Amdt. 195-22, 46 FR 38360, July 27, 1981, as amended by Amdt. 195-35, 50 FR 37192, Sept. 21, 1985; Amdt. 195-52, 59 FR 33397, June 28, 1994; Amdt. 195-100, 80 FR 12780, Mar. 11, 2015] | (a) A weld may be nondestructively tested by any process that will clearly indicate any defects that may affect the integrity of the weld. (b) Any nondestructive testing of welds must be performed— (1) In accordance with a written set of procedures for nondestructive testing; and (2) With personnel that have been trained in the established procedures and in the use of the equipment employed in the testing. (c) Procedures for the proper interpretation of each weld inspection must be established to ensure the acceptability of the weld under § 195.228. (d) During construction, at least 10 percent of the girth welds made by each welder and welding operator during each welding day must be nondestructively tested over the entire circumference of the weld. (e) All girth welds installed each day in the following locations must be nondestructively tested over their entire circumference, except that when nondestructive testing is impracticable for a girth weld, it need not be tested if the number of girth welds for which testing is impracticable does not exceed 10 percent of the girth welds installed that day: (1) At any onshore location where a loss of hazardous liquid could reasonably be expected to pollute any stream, river, lake, reservoir, or other body of water, and any offshore area; (2) Within railroad or public road rights-of-way; (3) At overhead road crossings and within tunnels; (4) Within the limits of any incorporated subdivision of a State government; and (5) Within populated areas, including, but not limited to, residential subdivisions, shopping centers, schools, designated commercial areas, industrial facilities, public institutions, and places of public assembly. (f) When installing used pipe, 100 percent of the old girth welds must be nondestructively tested. (g) At pipeline tie-ins, including tie-ins of replacement sections, 100 percent of the girth welds must be nondestructively tested. | |||
| 49:49:3.1.1.2.11.4.20.18 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | D | Subpart D—Construction | §§ 195.236-195.244 [Reserved] | PHMSA | |||||
| 49:49:3.1.1.2.11.4.20.19 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | D | Subpart D—Construction | § 195.246 Installation of pipe in a ditch. | PHMSA | [Amdt. 195-22, 46 FR 38360, July 27, 1981, as amended by Amdt. 195-52, 59 FR 33397, June 28, 1994; 59 FR 36256, July 15, 1994; Amdt. 195-85, 69 FR 48407, Aug. 10, 2004; Amdt. 195-108, 90 FR 21436, May 20, 2025] | (a) All pipe installed in a ditch must be installed in a manner that minimizes the introduction of secondary stresses and the possibility of damage to the pipe. (b) Except for pipe in the Gulf of America and its inlets in waters less than 15 feet deep, all offshore pipe in water at least 12 feet deep (3.7 meters) but not more than 200 feet deep (61 meters) deep as measured from the mean low water must be installed so that the top of the pipe is below the underwater natural bottom (as determined by recognized and generally accepted practices) unless the pipe is supported by stanchions held in place by anchors or heavy concrete coating or protected by an equivalent means. | |||
| 49:49:3.1.1.2.11.4.20.2 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | D | Subpart D—Construction | § 195.202 Compliance with specifications or standards. | PHMSA | Each pipeline system must be constructed in accordance with comprehensive written specifications or standards that are consistent with the requirements of this part. | ||||
| 49:49:3.1.1.2.11.4.20.20 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | D | Subpart D—Construction | § 195.248 Cover over buried pipeline. | PHMSA | [Amdt. 195-22, 46 FR 38360, July 27, 1981; 47 FR 32721, July 29, 1982, as amended by Amdt. 195-52, 59 FR 33397, June 28, 1994; 59 FR 36256, July 15, 1994; Amdt. 195-63, 63 FR 37506, July 13, 1998; Amdt. 195-95, 69 FR 48407, Aug. 10, 2004; Amdt. 195-101, 82 FR 7999, Jan. 23, 2017; Amdt. 195-108, 90 FR 21436, May 20, 2025] | (a) Unless specifically exempted in this subpart, all pipe must be buried so that it is below the level of cultivation. Except as provided in paragraph (b) of this section, the pipe must be installed so that the cover between the top of the pipe and the ground level, road bed, river bottom, or underwater natural bottom (as determined by recognized and generally accepted practices), as applicable, complies with the following table: 1 Rock excavation is any excavation that requires blasting or removal by equivalent means. (b) Except for the Gulf of America and its inlets in waters less than 15 feet (4.6 meters) deep, less cover than the minimum required by paragraph (a) of this section and § 195.210 may be used if— (1) It is impracticable to comply with the minimum cover requirements; and (2) Additional protection is provided that is equivalent to the minimum required cover. | |||
| 49:49:3.1.1.2.11.4.20.21 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | D | Subpart D—Construction | § 195.250 Clearance between pipe and underground structures. | PHMSA | [Amdt. 195-22, 46 FR 38360, July 27, 1981, as amended by Amdt. 195-63, 63 FR 37506, July 13, 1998] | Any pipe installed underground must have at least 12 inches (305 millimeters) of clearance between the outside of the pipe and the extremity of any other underground structure, except that for drainage tile the minimum clearance may be less than 12 inches (305 millimeters) but not less than 2 inches (51 millimeters). However, where 12 inches (305 millimeters) of clearance is impracticable, the clearance may be reduced if adequate provisions are made for corrosion control. | |||
| 49:49:3.1.1.2.11.4.20.22 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | D | Subpart D—Construction | § 195.252 Backfilling. | PHMSA | [Amdt. 195-78, 68 FR 53528, Sept. 11, 2003] | When a ditch for a pipeline is backfilled, it must be backfilled in a manner that: (a) Provides firm support under the pipe; and (b) Prevents damage to the pipe and pipe coating from equipment or from the backfill material. | |||
| 49:49:3.1.1.2.11.4.20.23 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | D | Subpart D—Construction | § 195.254 Above ground components. | PHMSA | (a) Any component may be installed above ground in the following situations, if the other applicable requirements of this part are complied with: (1) Overhead crossings of highways, railroads, or a body of water. (2) Spans over ditches and gullies. (3) Scraper traps or block valves. (4) Areas under the direct control of the operator. (5) In any area inaccessible to the public. (b) Each component covered by this section must be protected from the forces exerted by the anticipated loads. | ||||
| 49:49:3.1.1.2.11.4.20.24 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | D | Subpart D—Construction | § 195.256 Crossing of railroads and highways. | PHMSA | The pipe at each railroad or highway crossing must be installed so as to adequately withstand the dynamic forces exerted by anticipated traffic loads. | ||||
| 49:49:3.1.1.2.11.4.20.25 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | D | Subpart D—Construction | § 195.258 Valves: General. | PHMSA | [Amdt. 195-22, 46 FR 38360, July 27, 1981, as amended by Amdt. 195-105, 87 FR 20987, Apr. 8, 2022; Amdt. 195-106, 88 FR 50062, Aug. 1, 2023] | (a) Each valve must be installed in a location that is accessible to authorized employees and that is protected from damage or tampering. (b) Each submerged valve located offshore or in inland navigable waters must be marked, or located by conventional survey techniques, to facilitate quick location when operation of the valve is required. (c) For all onshore hazardous liquid or carbon dioxide pipeline segments with diameters greater than or equal to 6 inches that are constructed after April 10, 2023, the operator must install rupture-mitigation valves (RMV) or an alternative equivalent technology whenever a valve must be installed to meet the appropriate valve spacing requirements of this section and § 195.260. An operator using alternative equivalent technology must notify PHMSA in accordance with the procedure in paragraph (e) of this section. All RMVs and alternative equivalent technology installed as required by this section must meet the requirements of § 195.419. An operator may request an extension of the installation compliance deadline requirements of this paragraph if it can demonstrate to PHMSA, in accordance with the notification procedures in § 195.18, that those installation deadline requirements would be economically, technically, or operationally infeasible for a particular new pipeline. (d) For all entirely replaced onshore hazardous liquid or carbon dioxide pipeline segments with diameters greater than or equal to 6 inches that have been replaced after April 10, 2023, the operator must install RMVs or an alternative equivalent technology whenever a valve must be installed to meet the appropriate valve spacing requirements of this section. An operator using alternative equivalent technology must notify PHMSA in accordance with the procedure in paragraph (e) of this section. All valves installed as required by this section must meet the requirements of § 195.419. The requirements of this paragraph (d) apply when the applicable pipeline replacement project involves a valve, either through addit… | |||
| 49:49:3.1.1.2.11.4.20.26 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | D | Subpart D—Construction | § 195.260 Valves: Location. | PHMSA | [Amdt. 195-105, 87 FR 20987, Apr. 8, 2022, as amended by Amdt. 195-106, 88 FR 50062, Aug. 1, 2023] | A valve must be installed at each of the following locations: (a) On the suction end and the discharge end of a pump station in a manner that permits isolation of the pump station equipment in the event of an emergency. (b) On each pipeline entering or leaving a breakout storage tank area in a manner that permits isolation of the tank from other facilities. (c) On each pipeline at locations along the pipeline system that will minimize or prevent safety risks, property damage, or environmental harm from accidental hazardous liquid or carbon dioxide discharges, as appropriate for onshore areas, offshore areas, and high-consequence areas (HCA). For newly constructed or entirely replaced onshore hazardous liquid or carbon dioxide pipeline segments, as that term is defined at § 195.2, that are installed after April 10, 2023, valve spacing must not exceed 15 miles for pipeline segments that could affect or are in HCAs, as defined in § 195.450, and 20 miles for pipeline segments that could not affect HCAs. Valves on pipeline segments that are located in HCAs or which could affect HCAs must be installed at locations as determined by the operator's process for identifying preventive and mitigative measures established pursuant to § 195.452(i) and by using the selection process in section I.B of appendix C of part 195, but with a maximum distance that does not exceed 7 1/2 miles from the endpoints of the HCA segment or the segment that could affect an HCA. An operator may request an exemption from the compliance deadline requirements of this section for valve installation at the specified valve spacing if it can demonstrate to PHMSA, in accordance with the notification procedures in § 195.18, that those compliance deadline requirements would be economically, technically, or operationally infeasible. (d) On each lateral takeoff from a pipeline in a manner that permits shutting off the lateral without interrupting flow in the pipeline. (e) On each side of one or more adjacent water crossings that are more than 100 fee… | |||
| 49:49:3.1.1.2.11.4.20.27 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | D | Subpart D—Construction | § 195.262 Pumping equipment. | PHMSA | [Amdt. 195-22, 46 FR 38360, July 27, 1981, as amended by Amdt. 195-52, 59 FR 33397, June 28, 1994] | (a) Adequate ventilation must be provided in pump station buildings to prevent the accumulation of hazardous vapors. Warning devices must be installed to warn of the presence of hazardous vapors in the pumping station building. (b) The following must be provided in each pump station: (1) Safety devices that prevent overpressuring of pumping equipment, including the auxiliary pumping equipment within the pumping station. (2) A device for the emergency shutdown of each pumping station. (3) If power is necessary to actuate the safety devices, an auxiliary power supply. (c) Each safety device must be tested under conditions approximating actual operations and found to function properly before the pumping station may be used. (d) Except for offshore pipelines, pumping equipment must be installed on property that is under the control of the operator and at least 15.2 m (50 ft) from the boundary of the pump station. (e) Adequate fire protection must be installed at each pump station. If the fire protection system installed requires the use of pumps, motive power must be provided for those pumps that is separate from the power that operates the station. | |||
| 49:49:3.1.1.2.11.4.20.28 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | D | Subpart D—Construction | § 195.264 Impoundment, protection against entry, normal/emergency venting or pressure/vacuum relief for aboveground breakout tanks. | PHMSA | [Amdt. 195-66, 64 FR 15935, Apr. 2, 1999, as amended by Amdt. 195-86, 71 FR 33410, June 9, 2006; Amd .t195-94, 75 FR 48606, Aug. 11, 2010; Amdt. 195-99, 80 FR 186, Jan. 5, 2015; 80 FR 46848, Aug. 6, 2015; Amdt. 195-117, 90 FR 40766, Aug. 21, 2025] | (a) A means must be provided for containing hazardous liquids in the event of spillage or failure of an aboveground breakout tank. (b) After October 2, 2000, compliance with paragraph (a) of this section requires the following for the aboveground breakout tanks specified: (1) For tanks built to API Spec 12F, API Std 620, and others (such as API Std 650 (or its predecessor Standard 12C)), the installation of impoundment must be in accordance with the following sections of NFPA 30 (incorporated by reference, see § 195.3); (i) Impoundment around a breakout tank must be installed in accordance with section 22.11.2; and (ii) Impoundment by drainage to a remote impounding area must be installed in accordance with section 22.11.1. (2) For tanks built to API Std 2510 (incorporated by reference, see § 195.3) , the installation of impoundment must be in accordance with section 5 or 11 of API Std 2510. (c) Aboveground breakout tank areas must be adequately protected against unauthorized entry. (d) Normal/emergency relief venting must be provided for each atmospheric pressure breakout tank. Pressure/vacuum-relieving devices must be provided for each low-pressure and high-pressure breakout tank. (e) For normal/emergency relief venting and pressure/vacuum-relieving devices installed on aboveground breakout tanks after October 2, 2000, compliance with paragraph (d) of this section requires the following for the tanks specified: (1) Normal/emergency relief venting installed on atmospheric pressure tanks built to API Spec 12F must be in accordance with section 4 and Appendices B and C of API Spec 12F (incorporated by reference, see § 195.3) . (2) Normal/emergency relief venting installed on atmospheric pressure tanks (such as those built to API Std 650 or its predecessor Standard 12C) must be in accordance with API Std 2000 (incorporated by reference, see § 195.3). (3) Pressure-relieving and emergency vacuum-relieving devices installed on low-pressure tanks built to API Std 620 must be in accordance with Sectio… | |||
| 49:49:3.1.1.2.11.4.20.29 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | D | Subpart D—Construction | § 195.266 Construction records. | PHMSA | [Amdt. 195-22, 46 FR 38360, July 27, 1981, as amended by Amdt. 195-34, 50 FR 34474, Aug. 26, 1985] | A complete record that shows the following must be maintained by the operator involved for the life of each pipeline facility: (a) The total number of girth welds and the number nondestructively tested, including the number rejected and the disposition of each rejected weld. (b) The amount, location; and cover of each size of pipe installed. (c) The location of each crossing of another pipeline. (d) The location of each buried utility crossing. (e) The location of each overhead crossing. (f) The location of each valve and corrosion test station. | |||
| 49:49:3.1.1.2.11.4.20.3 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | D | Subpart D—Construction | § 195.204 Inspection—general. | PHMSA | [Amdt. 195-100, 80 FR 12780, Mar. 11, 2015] | Inspection must be provided to ensure that the installation of pipe or pipeline systems is in accordance with the requirements of this subpart. Any operator personnel used to perform the inspection must be trained and qualified in the phase of construction to be inspected. An operator must not use operator personnel to perform a required inspection if the operator personnel performed the construction task requiring inspection. Nothing in this section prohibits the operator from inspecting construction tasks with operator personnel who are involved in other construction tasks. | |||
| 49:49:3.1.1.2.11.4.20.4 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | D | Subpart D—Construction | § 195.205 Repair, alteration and reconstruction of aboveground breakout tanks that have been in service. | PHMSA | [Amdt. 195-66, 64 FR 15935, Apr. 2, 1999, as amended by Amdt. 195-99, 80 FR 186, Jan. 5, 2015; 80 FR 46848, Aug. 6, 2015] | (a) Aboveground breakout tanks that have been repaired, altered, or reconstructed and returned to service must be capable of withstanding the internal pressure produced by the hazardous liquid to be stored therein and any anticipated external loads. (b) After October 2, 2000, compliance with paragraph (a) of this section requires the following: (1) For tanks designed for approximate atmospheric pressure, constructed of carbon and low alloy steel, welded or riveted, and non-refrigerated; and for tanks built to API Std 650 (incorporated by reference, see § 195.3) or its predecessor Standard 12C; repair, alteration; and reconstruction must be in accordance with API Std 653 (except section 6.4.3) (incorporated by reference, see § 195.3). (2) For tanks built to API Spec 12F (incorporated by reference, see § 195.3) or API Std 620 (incorporated by reference, see § 195.3), repair, alteration, and reconstruction must be in accordance with the design, welding, examination, and material requirements of those respective standards. (3) For high-pressure tanks built to API Std 2510 (incorporated by reference, see § 195.3), repairs, alterations, and reconstruction must be in accordance with API Std 510 (incorporated by reference, see § 195.3). | |||
| 49:49:3.1.1.2.11.4.20.5 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | D | Subpart D—Construction | § 195.206 Material inspection. | PHMSA | No pipe or other component may be installed in a pipeline system unless it has been visually inspected at the site of installation to ensure that it is not damaged in a manner that could impair its strength or reduce its serviceability. | ||||
| 49:49:3.1.1.2.11.4.20.6 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | D | Subpart D—Construction | § 195.207 Transportation of pipe. | PHMSA | [Amdt. 195-94, 75 FR 48606, Aug. 11, 2010, as amended by Amdt. 195-99, 80 FR 186, Jan. 5, 2015] | (a) Railroad. In a pipeline operated at a hoop stress of 20 percent or more of SMYS, an operator may not use pipe having an outer diameter to wall thickness ratio of 70 to 1, or more, that is transported by railroad unless the transportation is performed in accordance with API RP 5L1 (incorporated by reference, see § 195.3). (b) Ship or barge. In a pipeline operated at a hoop stress of 20 percent or more of SMYS, an operator may not use pipe having an outer diameter to wall thickness ratio of 70 to 1, or more, that is transported by ship or barge on both inland and marine waterways, unless the transportation is performed in accordance with API RP 5LW (incorporated by reference, see § 195.3). (c) Truck. In a pipeline to be operated at a hoop stress of 20 percent or more of SMYS, an operator may not use pipe having an outer diameter to wall thickness ratio of 70 to 1, or more, that is transported by truck unless the transportation is performed in accordance with API RP 5LT (incorporated by reference, see § 195.3). | |||
| 49:49:3.1.1.2.11.4.20.7 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | D | Subpart D—Construction | § 195.208 Welding of supports and braces. | PHMSA | [Amdt. 195-22, 46 FR 38360, July 27, 1981, as amended by Amdt. 195-63, 63 FR 37506, July 13, 1998] | Supports or braces may not be welded directly to pipe that will be operated at a pressure of more than 100 p.s.i. (689 kPa) gage. | |||
| 49:49:3.1.1.2.11.4.20.8 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | D | Subpart D—Construction | § 195.210 Pipeline location. | PHMSA | [Amdt. 195-22, 46 FR 39360, July 27, 1981, as amended by Amdt. 195-63, 63 FR 37506, July 13, 1998] | (a) Pipeline right-of-way must be selected to avoid, as far as practicable, areas containing private dwellings, industrial buildings, and places of public assembly. (b) No pipeline may be located within 50 feet (15 meters) of any private dwelling, or any industrial building or place of public assembly in which persons work, congregate, or assemble, unless it is provided with at least 12 inches (305 millimeters) of cover in addition to that prescribed in § 195.248. | |||
| 49:49:3.1.1.2.11.4.20.9 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | D | Subpart D—Construction | § 195.212 Bending of pipe. | PHMSA | [Amdt. 195-22, 46 FR 38360, July 27, 1981, as amended by Amdt. 195-52, 59 FR 33396, June 28, 1994; Amdt. 195-63, 63 FR 37506, July 13, 1998] | (a) Pipe must not have a wrinkle bend. (b) Each field bend must comply with the following: (1) A bend must not impair the serviceability of the pipe. (2) Each bend must have a smooth contour and be free from buckling, cracks, or any other mechanical damage. (3) On pipe containing a longitudinal weld, the longitudinal weld must be as near as practicable to the neutral axis of the bend unless— (i) The bend is made with an internal bending mandrel; or (ii) The pipe is 12 3/4 in (324 mm) or less nominal outside diameter or has a diameter to wall thickness ratio less than 70. (c) Each circumferential weld which is located where the stress during bending causes a permanent deformation in the pipe must be nondestructively tested either before or after the bending process. | |||
| 49:49:3.1.1.2.11.5.20.1 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | E | Subpart E—Pressure Testing | § 195.300 Scope. | PHMSA | [Amdt. 195-51, 59 FR 29384, June 7, 1994] | This subpart prescribes minimum requirements for the pressure testing of steel pipelines. However, this subpart does not apply to the movement of pipe under § 195.424. | |||
| 49:49:3.1.1.2.11.5.20.2 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | E | Subpart E—Pressure Testing | § 195.302 General requirements. | PHMSA | [Amdt. 195-51, 59 FR 29384, June 7, 1994, as amended by Amdt. 195-53, 59 FR 35471, July 12, 1994; Amdt. 195-51B, 61 FR 43027, Aug. 20, 1996; Amdt. 195-58, 62 FR 54592, Oct. 21, 1997; Amdt. 195-63, 63 FR 37506, July 13, 1998; Amdt. 195-65, 63 FR 59479, Nov. 4, 1998] | (a) Except as otherwise provided in this section and in § 195.305(b), no operator may operate a pipeline unless it has been pressure tested under this subpart without leakage. In addition, no operator may return to service a segment of pipeline that has been replaced, relocated, or otherwise changed until it has been pressure tested under this subpart without leakage. (b) Except for pipelines converted under § 195.5, the following pipelines may be operated without pressure testing under this subpart: (1) Any hazardous liquid pipeline whose maximum operating pressure is established under § 195.406(a)(5) that is— (i) An interstate pipeline constructed before January 8, 1971; (ii) An interstate offshore gathering line constructed before August 1, 1977; (iii) An intrastate pipeline constructed before October 21, 1985; or (iv) A low-stress pipeline constructed before August 11, 1994 that transports HVL. (2) Any carbon dioxide pipeline constructed before July 12, 1991, that— (i) Has its maximum operating pressure established under § 195.406(a)(5); or (ii) Is located in a rural area as part of a production field distribution system. (3) Any low-stress pipeline constructed before August 11, 1994 that does not transport HVL. (4) Those portions of older hazardous liquid and carbon dioxide pipelines for which an operator has elected the risk-based alternative under § 195.303 and which are not required to be tested based on the risk-based criteria. (c) Except for pipelines that transport HVL onshore, low-stress pipelines, and pipelines covered under § 195.303, the following compliance deadlines apply to pipelines under paragraphs (b)(1) and (b)(2)(i) of this section that have not been pressure tested under this subpart: (1) Before December 7, 1998, for each pipeline each operator shall— (i) Plan and schedule testing according to this paragraph; or (ii) Establish the pipeline's maximum operating pressure under § 195.406(a)(5). (2) For pipelines scheduled for testing, each operator shall— (i) Before December 7… | |||
| 49:49:3.1.1.2.11.5.20.3 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | E | Subpart E—Pressure Testing | § 195.303 Risk-based alternative to pressure testing older hazardous liquid and carbon dioxide pipelines. | PHMSA | [Amdt. 195-65, 63 FR 59480, Nov. 4, 1998] | (a) An operator may elect to follow a program for testing a pipeline on risk-based criteria as an alternative to the pressure testing in § 195.302(b)(1)(i)-(iii) and § 195.302(b)(2)(i) of this subpart. Appendix B provides guidance on how this program will work. An operator electing such a program shall assign a risk classification to each pipeline segment according to the indicators described in paragraph (b) of this section as follows: (1) Risk Classification A if the location indicator is ranked as low or medium risk, the product and volume indicators are ranked as low risk, and the probability of failure indicator is ranked as low risk; (2) Risk Classification C if the location indicator is ranked as high risk; or (3) Risk Classification B. (b) An operator shall evaluate each pipeline segment in the program according to the following indicators of risk: (1) The location indicator is— (i) High risk if an area is non-rural or environmentally sensitive 1 ; or (ii) Medium risk; or (iii) Low risk if an area is not high or medium risk. (2) The product indicator is 1 1 (See Appendix B, Table C). (i) High risk if the product transported is highly toxic or is both highly volatile and flammable; (ii) Medium risk if the product transported is flammable with a flashpoint of less than 100 °F, but not highly volatile; or (iii) Low risk if the product transported is not high or medium risk. (3) The volume indicator is— (i) High risk if the line is at least 18 inches in nominal diameter; (ii) Medium risk if the line is at least 10 inches, but less than 18 inches, in nominal diameter; or (iii) Low risk if the line is not high or medium risk. (4) The probability of failure indicator is— (i) High risk if the segment has experienced more than three failures in the last 10 years due to time-dependent defects (e.g., corrosion, gouges, or problems developed during manufacture, construction or operation, etc.); or (ii) Low risk if the segment has experienced three failures or less in the last 10 years due to … | |||
| 49:49:3.1.1.2.11.5.20.4 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | E | Subpart E—Pressure Testing | § 195.304 Test pressure. | PHMSA | [Amdt. 195-51, 59 FR 29384, June 7, 1994. Redesignated by Amdt. 195-65, 63 FR 59480, Nov. 4, 1998] | The test pressure for each pressure test conducted under this subpart must be maintained throughout the part of the system being tested for at least 4 continuous hours at a pressure equal to 125 percent, or more, of the maximum operating pressure and, in the case of a pipeline that is not visually inspected for leakage during the test, for at least an additional 4 continuous hours at a pressure equal to 110 percent, or more, of the maximum operating pressure. | |||
| 49:49:3.1.1.2.11.5.20.5 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | E | Subpart E—Pressure Testing | § 195.305 Testing of components. | PHMSA | [Amdt. 195-22, 46 FR 38360, July 27, 1981, as amended by Amdt. 195-51, 59 FR 29385, June 7, 1994; Amdt. 195-52, 59 FR 33397, June 28, 1994. Redesignated by Amdt. 195-65, 63 FR 59480, Nov. 4, 1998] | (a) Each pressure test under § 195.302 must test all pipe and attached fittings, including components, unless otherwise permitted by paragraph (b) of this section. (b) A component, other than pipe, that is the only item being replaced or added to the pipeline system need not be hydrostatically tested under paragraph (a) of this section if the manufacturer certifies that either— (1) The component was hydrostatically tested at the factory; or (2) The component was manufactured under a quality control system that ensures each component is at least equal in strength to a prototype that was hydrostatically tested at the factory. | |||
| 49:49:3.1.1.2.11.5.20.6 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | E | Subpart E—Pressure Testing | § 195.306 Test medium. | PHMSA | [Amdt. 195-22, 46 FR 38360, July 27, 1991, as amended by Amdt. 195-45, 56 FR 26926, June 12, 1991; Amdt. 195-51, 59 FR 29385, June 7, 1994; Amdt. 195-53, 59 FR 35471, July 12, 1994; Amdt. 195-51A, 59 FR 41260, Aug. 11, 1994; Amdt. 195-63, 63 FR 37506, July 13, 1998] | (a) Except as provided in paragraphs (b), (c), and (d) of this section, water must be used as the test medium. (b) Except for offshore pipelines, liquid petroleum that does not vaporize rapidly may be used as the test medium if— (1) The entire pipeline section under test is outside of cities and other populated areas; (2) Each building within 300 feet (91 meters) of the test section is unoccupied while the test pressure is equal to or greater than a pressure which produces a hoop stress of 50 percent of specified minimum yield strength; (3) The test section is kept under surveillance by regular patrols during the test; and (4) Continuous communication is maintained along entire test section. (c) Carbon dioxide pipelines may use inert gas or carbon dioxide as the test medium if— (1) The entire pipeline section under test is outside of cities and other populated areas; (2) Each building within 300 feet (91 meters) of the test section is unoccupied while the test pressure is equal to or greater than a pressure that produces a hoop stress of 50 percent of specified minimum yield strength; (3) The maximum hoop stress during the test does not exceed 80 percent of specified minimum yield strength; (4) Continuous communication is maintained along entire test section; and (5) The pipe involved is new pipe having a longitudinal joint factor of 1.00. (d) Air or inert gas may be used as the test medium in low-stress pipelines. | |||
| 49:49:3.1.1.2.11.5.20.7 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | E | Subpart E—Pressure Testing | § 195.307 Pressure testing aboveground breakout tanks. | PHMSA | [Amdt. 195-99, 80 FR 187, Jan. 5, 2015, as amended by Amdt. 195-100, 80 FR 12780, Mar. 11, 2015; Amdts. 192-135, 195-107, 89 FR 33284, Apr. 29, 2024; Amdt. 195-117, 90 FR 40766, Aug. 21, 2025] | (a) For aboveground breakout tanks built to API Spec 12F (incorporated by reference, see § 195.3) and first placed in service after October 2, 2000, pneumatic testing must be performed in accordance with section 5.3 of API Spec 12F. (b) For aboveground breakout tanks built to API Std 620 (incorporated by reference, see § 195.3) and first placed in service after October 2, 2000, hydrostatic and pneumatic testing must be performed in accordance with section 7.18 of API Std 620. (c) For aboveground breakout tanks built to API Std 650 (incorporated by reference, see § 195.3) that were first placed into service after October 2, 2000, testing must be conducted in accordance with Sections 7.3.6 and 7.3.7 of API Std 650. (d) For aboveground atmospheric pressure breakout tanks constructed of carbon and low alloy steel, welded or riveted, and non-refrigerated tanks built to API Std 650 or its predecessor Standard 12C that are returned to service after October 2, 2000, the necessity for the hydrostatic testing of repair, alteration, and reconstruction is covered in section 12.3 of API Std 653 (incorporated by reference, see § 195.3). (e) For aboveground breakout tanks built to API Std 2510 (incorporated by reference elsewhere in this part, see § 195.3) and first placed in service after October 2, 2000, pressure testing must be performed in accordance with ASME BPVC, Section VIII, Division 1 and ASME BPVC, Section VIII, Division 2 (both incorporated by reference, see § 195.3). | |||
| 49:49:3.1.1.2.11.5.20.8 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | E | Subpart E—Pressure Testing | § 195.308 Testing of tie-ins. | PHMSA | [Amdt. 195-22, 46 FR 38360, July 27, 1981, as amended by Amdt. 195-51, 59 FR 29385, June 7, 1994] | Pipe associated with tie-ins must be pressure tested, either with the section to be tied in or separately. | |||
| 49:49:3.1.1.2.11.5.20.9 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | E | Subpart E—Pressure Testing | § 195.310 Records. | PHMSA | [Amdt. 195-34, 50 FR 34474, Aug. 26, 1985, as amended by Amdt. 195-51, 59 FR 29385, June 7, 1994; Amdt. 195-63, 63 FR 37506, July 13, 1998; Amdt. 195-78, 68 FR 53528, Sept. 11, 2003] | (a) A record must be made of each pressure test required by this subpart, and the record of the latest test must be retained as long as the facility tested is in use. (b) The record required by paragraph (a) of this section must include: (1) The pressure recording charts; (2) Test instrument calibration data; (3) The name of the operator, the name of the person responsible for making the test, and the name of the test company used, if any; (4) The date and time of the test; (5) The minimum test pressure; (6) The test medium; (7) A description of the facility tested and the test apparatus; (8) An explanation of any pressure discontinuities, including test failures, that appear on the pressure recording charts; (9) Where elevation differences in the section under test exceed 100 feet (30 meters), a profile of the pipeline that shows the elevation and test sites over the entire length of the test section; and (10) Temperature of the test medium or pipe during the test period. | |||
| 49:49:3.1.1.2.11.6.20.1 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | F | Subpart F—Operation and Maintenance | § 195.400 Scope. | PHMSA | This subpart prescribes minimum requirements for operating and maintaining pipeline systems constructed with steel pipe. | ||||
| 49:49:3.1.1.2.11.6.20.10 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | F | Subpart F—Operation and Maintenance | § 195.412 Inspection of rights-of-way and crossings under navigable waters. | PHMSA | [Amdt. 195-22, 46 FR 38360, July 27, 1981, as amended by Amdt. 195-24, 47 FR 46852, Oct. 21, 1982; Amdt. 195-52, 59 FR 33397, June 28, 1994] | (a) Each operator shall, at intervals not exceeding 3 weeks, but at least 26 times each calendar year, inspect the surface conditions on or adjacent to each pipeline right-of-way. Methods of inspection include walking, driving, flying or other appropriate means of traversing the right-of-way. (b) Except for offshore pipelines, each operator shall, at intervals not exceeding 5 years, inspect each crossing under a navigable waterway to determine the condition of the crossing. | |||
| 49:49:3.1.1.2.11.6.20.11 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | F | Subpart F—Operation and Maintenance | § 195.413 Underwater inspection and reburial of pipelines in the Gulf of America and its inlets. | PHMSA | [Amdt. 195-82, 69 FR 48407, Aug. 10, 2004, as amended by Amdt. 195-108, 90 FR 21436, May 20, 2025] | (a) Except for gathering lines of 4 1/2 inches (114mm) nominal outside diameter or smaller, each operator shall prepare and follow a procedure to identify its pipelines in the Gulf of America 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. (b) Each operator shall conduct appropriate periodic underwater inspections of its pipelines in the Gulf of America and its inlets in waters less than 15 feet (4.6 meters) deep as measured from mean low water based on the identified risk. (c) If an operator discovers that its pipeline is an exposed underwater pipeline or poses a hazard to navigation, the operator shall— (1) Promptly, but not later than 24 hours after discovery, notify the National Response Center, telephone: 1-800-424-8802, of the location and, if available, the geographic coordinates of that pipeline. (2) Promptly, but not later than 7 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 (3) Within 6 months after discovery, or not later than November 1 of the following year if the 6 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. (i) An operator may employ engineered alternatives to burial that meet or exceed the level of protection provided by burial. (ii) 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;… | |||
| 49:49:3.1.1.2.11.6.20.12 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | F | Subpart F—Operation and Maintenance | § 195.414 Inspections of pipelines in areas affected by extreme weather and natural disasters. | PHMSA | [Amdt. 195-102, 84 FR 52295, Oct. 1, 2019] | (a) General. Following an extreme weather event or natural disaster that has the likelihood of damage to infrastructure by the scouring or movement of the soil surrounding the pipeline, such as a named tropical storm or hurricane; a flood that exceeds the river, shoreline, or creek high-water banks in the area of the pipeline; a landslide in the area of the pipeline; or an earthquake in the area of the pipeline, an operator must inspect all potentially affected pipeline facilities to detect conditions that could adversely affect the safe operation of that pipeline. (b) Inspection method. An operator must consider the nature of the event and the physical characteristics, operating conditions, location, and prior history of the affected pipeline in determining the appropriate method for performing the initial inspection to determine the extent of any damage and the need for the additional assessments required under paragraph (a) of this section. (c) Time period. The inspection required under paragraph (a) of this section must commence within 72 hours after the cessation of the event, defined as the point in time when the affected area can be safely accessed by the personnel and equipment required to perform the inspection as determined under paragraph (b) of this section. In the event that the operator is unable to commence the inspection due to the unavailability of personnel or equipment, the operator must notify the appropriate PHMSA Region Director as soon as practicable. (d) Remedial action. An operator must take prompt and appropriate remedial action to ensure the safe operation of a pipeline based on the information obtained as a result of performing the inspection required under paragraph (a) of this section. Such actions might include, but are not limited to: (1) Reducing the operating pressure or shutting down the pipeline; (2) Modifying, repairing, or replacing any damaged pipeline facilities; (3) Preventing, mitigating, or eliminating any unsafe conditions in the pipeline right-of-way; (4… | |||
| 49:49:3.1.1.2.11.6.20.13 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | F | Subpart F—Operation and Maintenance | § 195.415 [Reserved] | PHMSA | |||||
| 49:49:3.1.1.2.11.6.20.14 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | F | Subpart F—Operation and Maintenance | § 195.416 Pipeline assessments. | PHMSA | [Amdt. 195-102, 84 FR 52295, Oct. 1, 2019] | (a) Scope. This section applies to onshore line pipe that can accommodate inspection by means of in-line inspection tools and is not subject to the integrity management requirements in § 195.452. (b) General. An operator must perform an initial assessment of each of its pipeline segments by October 1, 2029, and perform periodic assessments of its pipeline segments at least once every 10 calendar years from the year of the prior assessment or as otherwise necessary to ensure public safety or the protection of the environment. (c) Method. Except as specified in paragraph (d) of this section, an operator must perform the integrity assessment for the range of relevant threats to the pipeline segment by the use of an appropriate in-line inspection tool(s). When performing an assessment using an in-line inspection tool, an operator must comply with § 195.591. An operator must explicitly consider uncertainties in reported results (including tool tolerance, anomaly findings, and unity chart plots or other equivalent methods for determining uncertainties) in identifying anomalies. If this is impracticable based on operational limits, including operating pressure, low flow, and pipeline length or availability of in-line inspection tool technology for the pipe diameter, then the operator must perform the assessment using the appropriate method(s) in paragraphs (c)(1), (2), or (3) of this section for the range of relevant threats being assessed. The methods an operator selects to assess low-frequency electric resistance welded pipe, pipe with a seam factor less than 1.0 as defined in § 195.106(e) or lap-welded pipe susceptible to longitudinal seam failure must be capable of assessing seam integrity, cracking, and of detecting corrosion and deformation anomalies. The following alternative assessment methods may be used as specified in this paragraph: (1) A pressure test conducted in accordance with subpart E of this part; (2) External corrosion direct assessment in accordance with § 195.588; or (3) Other technology… | |||
| 49:49:3.1.1.2.11.6.20.15 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | F | Subpart F—Operation and Maintenance | § 195.417 Notification of potential rupture. | PHMSA | [Amdt. 195-105, 87 FR 20989, Apr. 8, 2022, as amended by Amdt. 195-106, 88 FR 50062, Aug. 1, 2023] | (a) As used in this part, a notification of potential rupture means the notification to, 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 hazardous liquids or carbon dioxide from a pipeline: (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 product demand, receipts, or deliveries; (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 (3) Any unanticipated or unexplained rapid release of a large volume of hazardous liquid or carbon dioxide, a fire, or an explosion, in the immediate vicinity of the pipeline. (b) A notification of potential rupture occurs when an operator first receives notice of or observes an event specified in paragraph (a) of this section. (c) The requirements of this section do not apply to gathering lines. | |||
| 49:49:3.1.1.2.11.6.20.16 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | F | Subpart F—Operation and Maintenance | § 195.418 Valves: Onshore valve shut-off for rupture mitigation. | PHMSA | [Amdt. 195-105, 87 FR 20989, Apr. 8, 2022, as amended by Amdt. 195-106, 88 FR 50063, Aug. 1, 2023] | (a) Applicability. For newly constructed and entirely replaced onshore hazardous liquid or carbon dioxide pipeline segments, as defined at § 195.2, with diameters of 6 inches or greater that could affect high-consequence areas or are located in high consequence areas (HCA), and that have been installed after April 10, 2023, an operator must install or use existing rupture-mitigation valves (RMV), as defined at § 195.2, or alternative equivalent technologies according to the requirements of this section and § 195.419. RMVs and alternative equivalent technologies must be operational within 14 days of placing the new or replaced pipeline segment in service. An operator may request an extension of this 14-day operation requirement if it can demonstrate to PHMSA, in accordance with the notification procedures in § 195.18, that application of that requirement would be economically, technically, or operationally infeasible. The requirements of this section apply to all applicable pipe replacements, even those that do not otherwise directly involve the addition or replacement of a valve. (b) Maximum spacing between valves. RMVs and alternative equivalent technology must be installed in accordance with the following requirements: (1) Shut-off Segment. For purposes of this section, a “shut-off segment” means the segment of pipeline located between the upstream valve closest to the upstream endpoint of the replaced pipeline segment in the HCA or the pipeline segment that could affect an HCA and the downstream valve closest to the downstream endpoint of the replaced pipeline segment of the HCA or the pipeline segment that could affect an HCA so that the entirety of the segment that could affect the HCA or the segment within the HCA is between at least two RMVs or alternative equivalent technologies. If any crossover or lateral pipe for commodity receipts or deliveries connects to the replaced segment between the upstream and downstream valves, the shut-off segment also extends to a valve on the crossover connection(s… | |||
| 49:49:3.1.1.2.11.6.20.17 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | F | Subpart F—Operation and Maintenance | § 195.419 Valve capabilities. | PHMSA | [Amdt. 195-105, 87 FR 20989, Apr. 8, 2022, as amended by Amdt. 195-106, 88 FR 50063, Aug. 1, 2023] | (a) Scope. The requirements in this section apply to rupture-mitigation valves (RMV), as defined in § 195.2, or alternative equivalent technology, installed pursuant to §§ 195.258 and 195.418. (b) Rupture identification and valve shut-off time. If an operator observes or is notified of a release of hazardous liquid or carbon dioxide that may be representative of an unintentional or uncontrolled release event meeting a notification of potential rupture ( see §§ 195.2 and 195.417), including any unexplained flow rate changes, pressure changes, equipment functions, or other pipeline instrumentation indications observed by the operator, the operator must, as soon as practicable but within 30 minutes of rupture identification ( see § 195.402(e)(4)), identify the rupture and fully close any RMVs or alternative equivalent technologies necessary to minimize the volume of hazardous liquid or carbon dioxide released from a pipeline and mitigate the consequences of a rupture. (c) Valve shut-off capability. A valve must have the actuation capability necessary to close an RMV or alternative equivalent technology to mitigate the consequences of a rupture in accordance with the requirements of this section. (d) Valve monitoring and operational capabilities. An RMV, as defined in § 195.2, or alternative equivalent technology, must be capable of being monitored or controlled by either remote or onsite personnel as follows: (1) Operated during normal, abnormal, and emergency operating conditions; (2) Monitored for valve status ( i.e., open, closed, or partial closed/open), upstream pressure, and downstream pressure. For automatic shut-off valves (ASV), an operator does not need to monitor remotely a valve's status if the operator has the capability to monitor pressures or flow rate within each pipeline segment located between RMVs or alternative equivalent technologies to identify and locate a rupture. Pipeline segments that use an alternative equivalent technology must have the capability to monitor pressures and … | |||
| 49:49:3.1.1.2.11.6.20.18 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | F | Subpart F—Operation and Maintenance | § 195.420 Valve maintenance. | PHMSA | [Amdt. 195-22, 46 FR 38360, July 27, 1981; 47 FR 32721, July 29, 1982, as amended by Amdt. 195-24, 47 FR 46852, Oct. 21, 1982; Amdt. 195-105, 87 FR 20991, Apr. 8, 2022; Amdt. 195-106, 88 FR 50063, Aug. 1, 2023] | (a) Each operator shall maintain each valve that is necessary for the safe operation of its pipeline systems in good working order at all times. (b) Each operator must, at least twice each calendar year, but at intervals not exceeding 7 1/2 months, inspect each mainline valve to determine that it is functioning properly. Each rupture-mitigation valve (RMV), as defined in § 195.2 and not contained in a gathering line, or alternative equivalent technology that is installed under § 195.258(c) or § 195.418, must also be partially operated. Operators are not required to close the valve fully during the inspection; a minimum 25 percent valve closure is sufficient to demonstrate compliance, unless the operator has operational information that requires an additional closure percentage for maintaining reliability. (c) Each operator shall provide protection for each valve from unauthorized operation and from vandalism. (d) For each remote-control valve (RCV) installed in accordance with § 195.258(c) or § 195.418, an operator must conduct a point-to-point verification between SCADA system displays and the installed valves, sensors, and communications equipment, in accordance with § 195.446(c) and (e). (e) For each alternative equivalent technology installed under § 195.258(c) or (d) or § 195.418(a) that is manually or locally operated ( i.e., not an RMV, as that term is defined in § 195.2): (1) Operators must achieve a response time of 30 minutes or less, as required by § 195.419(b), through an initial drill and through periodic validation as required by paragraph (e)(2) of this section. An operator must review each phase of the drill response and document the results to validate the total response time, including the identification of a rupture, and valve shut-off time as being less than or equal to 30 minutes after rupture identification. (2) Within each pipeline system, and within each operating or maintenance field work unit, operators must randomly select an authorized rupture-mitigation alternative equivalent… | |||
| 49:49:3.1.1.2.11.6.20.19 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | F | Subpart F—Operation and Maintenance | § 195.422 Pipeline repairs. | PHMSA | (a) Each operator shall, in repairing its pipeline systems, insure that the repairs are made in a safe manner and are made so as to prevent damage to persons or property. (b) No operator may use any pipe, valve, or fitting, for replacement in repairing pipeline facilities, unless it is designed and constructed as required by this part. | ||||
| 49:49:3.1.1.2.11.6.20.2 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | F | Subpart F—Operation and Maintenance | § 195.401 General requirements. | PHMSA | [Amdt. 195-22, 46 FR 38360, July 27, 1981, as amended by Amdt. 195-33, 50 FR 15899, Apr. 23, 1985; Amdt. 195-33A, 50 FR 39008, Sept. 26, 1985; Amdt. 195-36, 51 FR 15008, Apr. 22, 1986; Amdt. 195-45, 56 FR 26926, June 12, 1991; Amdt. 195-53, 59 FR 35471, July 12, 1994; Amdt. 195-94, 75 FR 48607, Aug. 11, 2010; Amdt. 195-102, 84 FR 52295, Oct. 1, 2019] | (a) No operator may operate or maintain its pipeline systems at a level of safety lower than that required by this subpart and the procedures it is required to establish under § 195.402(a) of this subpart. (b) An operator must make repairs on its pipeline system according to the following requirements: (1) Non Integrity management repairs. Whenever an operator discovers any condition that could adversely affect the safe operation of its pipeline system, it must correct the condition within a reasonable time. However, if the condition is of such a nature that it presents an immediate hazard to persons or property, the operator may not operate the affected part of the system until it has corrected the unsafe condition. (2) Integrity management repairs. When an operator discovers a condition on a pipeline covered under § 195.452, the operator must correct the condition as prescribed in § 195.452(h). (3) Prioritizing repairs. An operator must consider the risk to people, property, and the environment in prioritizing the correction of any conditions referenced in paragraphs (b)(1) and (2) of this section. (c) Except as provided in § 195.5, no operator may operate any part of any of the following pipelines unless it was designed and constructed as required by this part: (1) An interstate pipeline, other than a low-stress pipeline, on which construction was begun after March 31, 1970, that transports hazardous liquid. (2) An interstate offshore gathering line, other than a low-stress pipeline, on which construction was begun after July 31, 1977, that transports hazardous liquid. (3) An intrastate pipeline, other than a low-stress pipeline, on which construction was begun after October 20, 1985, that transports hazardous liquid. (4) A pipeline on which construction was begun after July 11, 1991, that transports carbon dioxide. (5) A low-stress pipeline on which construction was begun after August 10, 1994. | |||
| 49:49:3.1.1.2.11.6.20.20 | 49 | Transportation | I | D | 195 | PART 195—TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE | F | Subpart F—Operation and Maintenance | § 195.424 Pipe movement. | PHMSA | [Amdt. 195-22, 46 FR 38360, July 27, 1981; 46 FR 38922, July 30, 1981, as amended by Amdt. 195-63, 63 FR 37506, July 13, 1998] | (a) No operator may move any line pipe, unless the pressure in the line section involved is reduced to not more than 50 percent of the maximum operating pressure. (b) No operator may move any pipeline containing highly volatile liquids where materials in the line section involved are joined by welding unless— (1) Movement when the pipeline does not contain highly volatile liquids is impractical; (2) The procedures of the operator under § 195.402 contain precautions to protect the public against the hazard in moving pipelines containing highly volatile liquids, including the use of warnings, where necessary, to evacuate the area close to the pipeline; and (3) The pressure in that line section is reduced to the lower of the following: (i) Fifty percent or less of the maximum operating pressure; or (ii) The lowest practical level that will maintain the highly volatile liquid in a liquid state with continuous flow, but not less than 50 p.s.i. (345 kPa) gage above the vapor pressure of the commodity. (c) No operator may move any pipeline containing highly volatile liquids where materials in the line section involved are not joined by welding unless— (1) The operator complies with paragraphs (b) (1) and (2) of this section; and (2) That line section is isolated to prevent the flow of highly volatile liquid. |
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