{"operation":"document","citation":"23 CAR pt. 500 191-A","title":"Appendix A to Part 191 - Procedure for determining reporting threshold","source_type":"regulation","agency":"Arkansas Public Service Commission","status":"current","official":true,"published_on":null,"effective_on":null,"summary":"APPENDIX A TO PART 191 PROCEDURE FOR DETERMINING REPORTING THRESHOLD I. Property Damage Threshold Formula Each year after calendar year 2021, the Administrator will publish a notice on PHMSA's website announcing the updates to the property damage threshold criterion that will take effect on July 1 o","machine_formats":{"json":"https://regulus.evalyn.ai/document/ar-car-23-500-appendix-191-a.json","markdown":"https://regulus.evalyn.ai/document/ar-car-23-500-appendix-191-a.md"},"app_url":"https://regulus.evalyn.ai/document/ar-car-23-500-appendix-191-a","source_url":"https://codeofarrules.arkansas.gov/Rules/Rule?chapterID=40&levelType=part&partID=1394&subChapterID=392&titleID=23","body":"APPENDIX A TO PART 191 PROCEDURE FOR DETERMINING REPORTING THRESHOLD I. Property Damage Threshold Formula Each year after calendar year 2021, the Administrator will publish a notice on PHMSA's website announcing the updates to the property damage threshold criterion that will take effect on July 1 of that year and will remain in effect until the June 30 of the next year. The property damage threshold used in the definition of an Incident at § 191.3 shall be determined in accordance with the following formula: Where: Tr is the revised damage threshold, Tp is the previous damage threshold, CPIr is the average Consumer Price Indices for all Urban Consumers (CPI-U) published by the Bureau of Labor Statistics each month during the most recent complete calendar year, and CPIp is the average CPI-U for the calendar year used to establish the previous property damage criteria. PART 192 - TRANSPORTATION OF NATURAL AND OTHER GAS BY PIPELINE: MINIMUM SAFETY STANDARDS SUBPART A - GENERAL § 192.1 Scope (a) Part 192 prescribes minimum safety requirements for pipeline facilities and the transportation of gas within the State of Arkansas. Requirements of the Arkansas Gas Pipeline Code shall take precedence over any other requirements pertaining to construction, operation, and maintenance of gas facilities under the jurisdiction of the Arkansas Public Service Commission. (b) This part does not apply to gathering of gas through a pipeline that operates at less than 0 p.s.i.g. (0kPa), and through a pipeline that is not a regulated onshore gathering line (as determined in §192.8); however, it shall apply to the gathering, transmission or distribution of gas containing 100 or more parts-per-million of hydrogen sulfide from the custodial transfer meter through any pipeline, rural or non-rural, to and through any pipeline facility that removes hydrogen sulfide, except that portion of such a pipeline or pipeline facility that is located within the fenced boundary of a petroleum refinery. § 192.3 Definitions As used in this part: Abandoned means permanently removed from service. Active Corrosion means continuing corrosion that, unless controlled, could result in a condition that is detrimental to public safety. Administrator means the Administrator of the Pipeline and Hazardous Materials Safety Administration or any person to whom authority in the matter concerned has been delegated by the U.S. Secretary of Transportation. Alarm means an audible or visible means of indicating to the controller that equipment or processes are outside operator-defined, safety-related parameters. Business District means a location where gas mains are utilized to serve customers that are predominately commercial in nature and where the street and/or sidewalk paving generally extends from the centerline of a thoroughfare to the established building line on either side. Change to a segment of pipeline means a physical change in the pipeline or significant changes in operating pressure. Commission means, unless the context otherwise requires, the Arkansas Public Service Commission or any person or entity to whom the Commission has delegated authority in the matter concerned. Close interval survey means a series of closely and properly spaced pipe-to-electrolyte potential measurements taken over the pipe to assess the adequacy of cathodic protection or to identify locations where a current may be leaving the pipeline that may cause corrosion and for the purpose of quantifying voltage (IR) drops other than those across the structure electrolyte boundary, such as when performed as a current interrupted, depolarized, or native survey. Composite Materials means materials used to make pipe or components manufactured with a combination of either steel or plastic, or both, and with a reinforcing material to maintain its circumferential or longitudinal strength. 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. Customer Meter means the meter that measures the transfer of gas from an operator to a consumer. Distribution center means the initial point where gas enters piping used primarily to deliver gas to customers who purchase it for consumption, as opposed to customers who purchase it for resale, for example: (1) At a metering location; (2) A pressure reduction location; or (3) Where there is a reduction in the volume of gas, such as a lateral off a transmission line. Distribution Line means a pipeline other than a gathering or transmission line. Dry gas or dry natural gas means gas above its dew point and without condensed liquids. Electrical Survey means a series of closely spaced pipe-to-soil readings over pipelines which are subsequently analyzed to identify locations where a corrosive current is leaving the pipeline. Engineering critical assessment (ECA) means a documented analytical procedure based on fracture mechanics principles, relevant material properties (mechanical and fracture resistance properties), operating history, operational environment, in-service degradation, possible failure mechanisms, initial and final defect sizes, and usage of future operating and maintenance procedures to determine the maximum tolerable sizes for imperfections based upon the pipeline segment maximum allowable operating pressure. Entirely replaced onshore transmission pipeline segments means, for the purposes of §§ 192.179 and 192.634, where 2 or more miles, in the aggregate, of onshore transmission pipeline have been replaced within any 5 contiguous miles of pipeline within an 24-month period. This definition does not apply to any gathering line. Gas means natural, manufactured, liquefied natural, flammable gas or gas which is toxic or corrosive. Gathering Line means a pipeline that transports gas from a current production facility to a transmission line or main. Hard spot means an area on steel pipe material with a minimum dimension greater than two inches (50.8 mm) in any direction and hardness greater than or equal to Rockwell 35 HRC (Brinell 327 HB or Vickers 345 HV10). High Pressure Distribution System means a distribution system in which the gas pressure in the main is higher than the pressure provided to the customer. Key Valves means shut off valves in a distribution system or transmission line which may be necessary to isolate segments of a system or line for emergency purposes. In-line inspection (ILI) means an inspection of a pipeline from the interior of the pipe using an inspection tool also called intelligent or smart pigging. This definition includes tethered and self- propelled inspection tools. In-line inspection tool or instrumented internal inspection device means an instrumented device or vehicle that uses a non-destructive testing technique to inspect the pipeline from the inside in order to identify and characterize flaws to analyze pipeline integrity; also known as an intelligent or smart pig. Line Section means a continuous run of transmission line between adjacent compressor stations, between a compressor station and storage facilities, between a compressor station and a block valve, or between adjacent block valves. Listed Specification means a specification listed in Section I of Appendix B to Part 192. Low-Pressure Distribution System means a distribution system in which the gas pressure in the main is substantially the same as the pressure provided to the customer. Main means a distribution line that serves as a common source of supply for more than one service line. Master Meter System means a pipeline system for distribution gas within, but not limited to, a definable area (such as a mobile home park, housing project, or apartment complex) where the operator purchases metered gas from an outside source for resale through a gas distribution pipeline system. The gas distribution pipeline system supplies the ultimate consumer who either purchases the gas directly through a meter or by other means, such as rents. Maximum Actual Operating Pressure means the maximum pressure that occurs during normal operations over a period of one year. Maximum Allowable Operating Pressure (MAOP) means the maximum pressure at which a pipeline or segment of a pipeline may be operated under this code. Mobile Home Park means two or more mobile homes located on a contiguous tract of land. Moderate consequence area means: (1) An onshore area that is within a potential impact circle, as defined in § 192.903, containing either: (i) Five or more buildings intended for human occupancy; or (ii) Any portion of the paved surface, including shoulders, of a designated interstate, other freeway, or expressway, as well as any other principal arterial roadway with 4 or more lanes, as defined in the Federal Highway Administration's Highway Functional Classification Concepts, Criteria and Procedures, Section 3.1 (see: https://www.fhwa.dot.gov/planning/processes/statewide/related/highway_functional _classifications/fcauab.pdf), and that does not meet the definition of high consequence area, as defined in § 192.903. (2) The length of the moderate consequence area extends axially along the length of the pipeline from the outermost edge of the first potential impact circle containing either 5 or more buildings intended for human occupancy; or any portion of the paved surface, including shoulders, of any designated interstate, freeway, or expressway, as well as any other principal arterial roadway with 4 or more lanes, to the outermost edge of the last contiguous potential impact circle that contains either 5 or more buildings intended for human occupancy, or any portion of the paved surface, including shoulders, of any designated interstate, freeway, or expressway, as well as any other principal arterial roadway with 4 or more lanes. Municipality means a city, county or any other political subdivision of the State of Arkansas. Notification of potential rupture means the notification to, or observation by, an operator of indicia identified in § 192.635 of a potential unintentional or uncontrolled release of a large volume of gas from a pipeline. This definition does not apply to any gathering line. Operator means a person who: (1) Engages in the transportation of gas; or (2) Operates a distribution system within a mobile home park, public housing authority, or multiple building complex if: (A) The system: (i) Is not owned, nor the responsibility of a public or municipal utility; and (ii) Is used to transport gas from a master meter or a public/municipal utility main to consumers who may or may not be metered; and (B) The gas distributed is not consumed solely by the owner/operator. Person means an individual, firm, joint venture, partnership, corporation, association, State, municipality, cooperative association, or joint stock association, and includes any trustee, receiver, assignee, or personal representative thereof. Petroleum Gas means propane, propylene, butane (normal butane or isobutanes), and butylene (including isomers), or mixtures composed predominantly of these gases, having a vapor pressure not exceeding 208 p.s.i.g. (1434 kPa) gage at 100°F (38°C). Petroleum Refinery means an industrial or manufacturing facility or plant primarily engaged in producing gasoline, kerosene, distillate fuel oils, residual fuel oils, lubricants or other products through the processing of petroleum crude oil that is subject to: (A) The federal Environmental Protection Agency Standards of Performance for New Stationary Sources set forth in Subpart GGG of 40 CFR part 60 or successor regulations; (B) The federal Environmental Protection Agency Chemical Accident Prevention Provisions set forth in Subparts, A, B, D, E, F, G, and H of 40 CFR Part 68 or successor regulations; and (C) The federal Occupational Safety and Health Administration Regulations governing process safety management of highly hazardous chemicals set forth in 29 CFR §1910.119 or successor regulations. Pipe means any pipe or tubing used in the transportation of gas, including pipe-type holders. Pipeline or Pipeline System means all parts of those physical facilities through which gas moves in transportation, including, but not limited to, pipe, valves and other appurtenances attached to pipe, compressor units, metering stations, regulator stations, delivery stations, holders, and fabricated assemblies. Pipeline Environment includes soil resistivity (high or low), soil moisture (wet or dry), soil contaminants that may promote corrosive activity, and other known conditions that could affect the probability of active corrosion. Pipeline Facilities includes without limitation, new and existing pipe, pipe rights-of-way, and any equipment, facility or building used in the transportation of gas or the treatment of gas during the course of transportation of gas. Private Line System means a natural gas pipeline or pipeline system that is not a master meter system; is not owned by, nor the responsibility of a public or municipal utility; is used to transport gas that is not consumed solely by the owner/operator from a public or municipal utility meter to consumers who may or may not be metered. Production Facilities includes without limitation, piping or equipment used in the production, extraction, recovery, lifting, stabilization, separation or treatment of natural gas or associated storage or measurement from the wellhead to a meter where the gas is transferred to a custodian other than the well operator for gathering or transport, commonly known as a \"custodial transfer meter.\" Production Process means the extraction of gas from the geological source of supply to the surface of the earth, thence through the lines and equipment used to treat, compress and measure the gas between the wellhead and the meter where it is either sold or delivered to a custodian other than the well operator for gathering and transport to a place of sale, sometimes called \"custodial transfer meter.\" Rupture-mitigation valve (RMV) means an automatic shut-off valve (ASV) or a remote-control valve (RCV) that a pipeline operator uses to minimize the volume of gas released from the pipeline and to mitigate the consequences of a rupture. This definition does not apply to any gathering line. Service Line means a distribution line that transports gas from a common source of supply to an individual customer, to two adjacent or adjoining residential or small commercial customers, or to multiple residential or small commercial customers served through a meter header or manifold. A service line ends at the outlet of the customer meter or at the connection to a piping, whichever is further downstream, or at the connection to customer piping if there is no meter. Service Regulator means the device on a service line that controls the pressure of gas delivered from a higher pressure to the pressure provided to the customer. A service regulator may serve one customer or multiple customers through a meter header or manifold. SMYS means specific minimum yield strength, and is: (1) For steel pipe manufactured in accordance with a listed specification, the yield strength specified as a minimum in that specification; or (2) For steel pipe manufactured in accordance with an unknown or unlisted specification, the yield strength determined in accordance with § 192.107(b). Supervisory Control and Data Acquisition (SCADA) System means a computer-based system or systems used by a controller in a control room that collects and displays information about a pipeline facility and may have the ability to send commands back to the pipeline facility. Test Failure means a break or rupture that occurs during strength proof testing of transmission or gathering lines that are of such magnitude as to require repair before continuation of the test. Transmission Line means a pipeline, other than a gathering line, that: (1) Transports gas from a gathering line or storage facility to a gas distribution center, storage facility or large volume customer that is not down-stream from a gas distribution center; (2) Operates at a hoop stress of 20 percent or more of SMYS; (3) Transports gas within a storage field; or (4) Is voluntarily designated by the operator as a transmission pipeline. NOTE: A large volume customer may receive similar volumes of gas as a distribution center, and includes factories, power plants, and institutional users of gas. Transportation of Gas means the gathering, transmission or distribution of gas by pipeline or the storage of gas in or affecting interstate, intrastate, or foreign commerce. Underground natural gas storage facility (UNGSF) means a gas pipeline facility that stores natural gas underground incidental to the transportation of natural gas, including: (1) (i) A depleted hydrocarbon reservoir; (ii) An aquifer reservoir; or (iii) A solution-mined salt cavern. (2) In addition to the reservoir or cavern, a UNGSF includes injection, withdrawal, monitoring, and observation wells; wellbores and downhole components; wellheads and associated wellhead piping; wing-valve assemblies that isolate the wellhead from connected piping beyond the wing-valve assemblies; and any other equipment, facility, right-of-way, or building used in the underground storage of natural gas. Welder means a person who performs manual or semi-automatic welding. Welding operator means a person who operates machine or automatic welding equipment. Weak link means a device or method used when pulling polyethylene pipe, typically through methods such as horizontal directional drilling, to ensure that damage will not occur to the pipeline by exceeding the maximum tensile stresses allowed. Wrinkle bend means a bend in the pipe that: (1) Was formed in the field during construction such that the inside radius of the bend has one or more ripples with: (i) An amplitude greater than or equal to 1.5 times the wall thickness of the pipe, measured from peak to valley of the ripple; or (ii) With ripples less than 1.5 times the wall thickness of the pipe and with a wrinkle length (peak to peak) to wrinkle height (peak to valley) ratio under 12. (2) (i) If the length of the wrinkle bend cannot be reliably determined, then wrinkle bend means a bend in the pipe where (h/D)*100 exceeds 2 when S is less than 37,000 psi (255 MPa), where (h/D)*100 exceeds (47000-S)/10,000 +1 for psi [(324-S)/69 +1 for MPa] when S is greater than 37,000 psi (255 MPa) but less than 47,000 psi (324 MPa), and where (h/D)*100 exceeds 1 when S is 47,000 psi (324 MPa) or more. (ii) Where: (A) D = Outside diameter of the pipe, in. (mm); (B) h = Crest-to-trough height of the ripple, in. (mm); and (C) S = Maximum operating hoop stress, psi (S/145, MPa). § 192.5 Class Locations (a) This section classifies pipeline locations for the purposes of this part. The following criteria apply to classifications under this section. (1) A \"class location unit\" is an area that extends 220 yards (200 meters) on either side of the centerline of any continuous 1-mile (1.6 kilometers) length of pipeline. (2) Each separate dwelling unit in a multiple dwelling unit building is counted as a separate building intended for human occupancy. (b) Except as provided in paragraph (c) of this section, pipeline locations are classified as follows: (1) A Class 1 location is any class location unit that has 10 or fewer buildings intended for human occupancy. (2) A Class 2 location is any class location unit that has more than 10 but fewer than 46 buildings intended for human occupancy. (3) A Class 3 location is: (i) Any class location unit that has 46 or more buildings intended for human occupancy; or (ii) An area where the pipeline lies within 100 yards (91 meters) of either a building or a small, well-defined outside area (such as a playground, recreation area, outdoor theater, or other place of public assembly) that is occupied by 20 or more persons on at least 5 days a week for 10 weeks in any 12-month period. (The days and weeks need not be consecutive.) (4) A Class 4 location is any class location unit where buildings with four or more stories above ground are prevalent. (c) The boundaries of Class locations 2, 3, and 4 may be adjusted as follows: (1) A Class 4 location ends 220 yards (200 meters) from the nearest building with four or more stories above ground. (2) When all buildings intended for human occupancy within a Class 2 or 3 location are in a single cluster, the class location ends 220 yards (200 meters) from the nearest building in the cluster. (d) An operator must have records that document the current class location of each gas transmission pipeline segment and that demonstrate how the operator determined each current class location in accordance with this section. § 192.7 What documents are incorporated by reference partly or wholly in this part? (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 (IBR) material is available for inspection at the Pipeline and Hazardous Materials Safety Administration (PHMSA) 1200 New Jersey Avenue SE, Washington, DC 20590; 202-366-4046; https://www.phmsa.dot.gov/pipeline/regs and at the National Archives and Records Administration (NARA). Contact PHMSA at: Office of Pipeline Safety, Pipeline and Hazardous Material Safety Administration, 1200 New Jersey Avenue SE, Washington, DC 20590; 202-366-4046; 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.html or email fr.inspection@nara.gov. It is also available from the sources in the following paragraphs of this section (b) American Petroleum Institute (API), 200 Massachusetts Ave. NW, Suite 1100, Washington, DC 20001, and phone: 202-682-8000, website: https://www.api.org. (1) API Recommended Practice 5L1, \"Recommend Practice for Railroad Transportation of Line Pipe,\" 7th edition, September 2009, (API RP 5L1), IBR approved for § 192.65(a). (2) API Recommended Practice 5LT, \"Recommended Practice for Truck Transportation of Line Pipe,\" First edition, March 2012, (API RP 5LT), IBR approved for § 192.65(c). (3) API Recommended Practice 5LW, \"Recommended Practice for Transportation of Line Pipe on Barges and Marine Vessels,\" 3rd edition, September 2009, (API RP 5LW), IBR approved for § 192.65(b). (4) API Recommended Practice 80, \"Guidelines for the Definition of Onshore Gas Gathering Lines\" 1st edition, April 2000, (API RP 80), IBR approved for § 192.8(a). (5) API Recommended Practice 1162, \"Public Awareness Programs for Pipeline 1st edition, December 2003, (API RP 1162), IBR approved for § 192.616(a), (b), and (c). (6) API Recommended Practice 1165, Practice for Pipeline SCADA First edition, January 2007, (API RP 1165), IBR approved for § 192.631(c). (7) API Specification 5L, Line Pipe, 46th edition, April 2018, including Errata 1 (May 2018), (API Spec 5L); IBR approved for §§ 192.55(e); 192.112(a), (b), (c), (d), and (e); 192.113; appendix B to part 192. (8) API Specification 6D, Specification for Pipeline and Piping Valves, 24th edition, August 2014, including Errata 1 through 10 (October 2014 through July 2021), Addendum 1 (March 2015), and Addendum 2 (June 2016), (API Spec 6D); IBR approved for § 192.145(a). (9) API Standard 1104, Welding of Pipelines and Related Facilities, 21st edition, September 2013, including Errata 1 through 5 (April 2014 through September 2018), Addendum 1 (2014), and Addendum 2 (2016), (API Std 1104); IBR approved for §§ 192.225(a); 192.227(a); 192.229(b) and (c); 192.241(c); appendix B to part 192. (10) API Recommended Practice 1170, \"Designa and Operation of Solution-mined Salt Caverns Used for Natural Gas Storage,\" First edition, July 2015 (API RP 1170), IBR approved for § 192.12. (11) API Recommended Practice 1171, \"Functional Integrity of Natural Gas Storage in Depleted Hydrocarbon Reservoirs and Aquifer Reservoirs,\" First edition, September 2015, (API RP 1171), IBR approved for § 192.12 (c) American Society of Mechanical Engineers (ASME), Three Park Avenue, New York, NY 10016, 800- 843-2763; email: CustomerCare@asme.org; website: www.asme.org/. (1) (ASME/ANSI B16.1-2005, \"Gray Iron Pipe Flanges and Flanged Fittings: (Classes 25, 125, and 250),\" August 31, 2006, (ASME/ANSI B16.1), IBR approved for § 192.147(c). (2) ASME/ANSI B16.5-2003, \"Pipe Flanges and Flanged Fittings,\" October 2004, (ASME/ANSI B16.5), IBR approved for §§ 192.147(a), 192.607(f). (3) ASME B16.40-2008, \"Manually Operated Thermoplastic Gas Shutoffs and Valves in Gas Distribution Systems,\" March 18, 2008, approved by ANSI, (ASME B16.40- 2008), IBR approved for Item I, Appendix B to Part 192. (4) ASME/ANSI B31G-1991 (Reaffirmed 2004, \"Manual for Determining the Remaining Strength of Corroded Pipelines,\" 2004, (ASME/ANSI B31G), IBR approved for §§ 192.485(c), 192.632(a), 192.712(b), and 192.933(a). (5) ASME B31.8-2018, Gas Transmission and Distribution Piping Systems, Issued November 20, 2018, (ASME B31.8); IBR approved for §§ 192.112(b); 192.619(a). (6) ASME/ANSI B31.8S-2004, \"Supplement to B31.8 on Managing System Integrity of Gas Pipelines,\" approved January 14, 2005 (ASME/ANSI B31.8S-2004), IBR approved for §§ 192.714(d); 192.933(d). (7) ASME B31.8S-2018, Managing System Integrity of Gas Pipelines, Issued November 28, 2018, (ASME B31.8S); IBR approved for §§ 192.13(d); 192.714(c); 192.903 note to Potential impact radius; 192.907 introductory text and (b); 192.911 introductory text, (i), and (k) through (m); 192.913(a) through (c); 192.917(a) through (e); 192.921(a); 192.923(b); 192.925(b); 192.933(c); 192.935(b); 192.937(c); 192.939(a); 192.945(a). (8) ASME B36.10M-2018, Welded and Seamless Wrought Steel Pipe, Issued October 12, 2018, (ASME B36.10M); IBR approved for § 192.279. (9) ASME Boiler & Pressure Vessel Code, Section VIII, Division 2 \"Rules, Rules for Construction of Pressure Vessels\" 2007 edition, July 1, 2007, (ASME BPVC, Section VIII, Division 2), IBR approved for §§ 192.153(b), (d); and 192.165(b). (10) ASME Boiler & Pressure Vessel Code, Section IX: \"Qualification Standard for Welding and Brazing Procedures, Welders, Brazers, and Welding and Brazing 2007 edition, July 1, 2007, ASME BPVC, Section IX, IBR approved for §§ 192.225(a); 192.227(a); and Item II, Appendix B to Part 192. (11) API Standard 1163, \"In-Line Inspection Systems Qualification,\" Second edition, April 2013, Reaffirmed August 2018, (API STD 1163), IBR approved for § 192.493. (d) American Society for Nondestructive Testing (ASNT), P.O. Box 28518, 1711 Arlingate Lane, Columbus, OH 43228, phone: 800-222-2768, website: https://www.asnt.org/. (1) ANSI/ASNT ILI-PQ-2005 (2010), \"In-line Inspection Personnel Qualification and Certification,\" Reapproved October 11, 2010, (ANSI/ASNT-PQ), IBR approved for § 192.493. (2) [Reserved] (e) ASTM International (ASTM), 100 Barr Harbor Drive, P.O. Box C700, West Conshohocken, PA 19428; phone: (610) 832-9585; email: service@astm.org; website: www.astm.org. (1) ASTM A53/A53M-20, Standard Specification for Pipe, Steel, Black and Hot- Dipped, Zinc-Coated, Welded and Seamless, approved July 1, 2020, (ASTM A53/A53M); IBR approved for § 192.113; appendix B to part 192. (2) ASTM A106/A106M-19A, Standard Specification for Seamless Carbon Steel Pipe for High-Temperature Service, approved November 1, 2019, (ASTM A106/A106M); IBR approved for § 192.113; appendix B to part 192. (3) ASTM A333/A333M-18, Standard Specification for Seamless and Welded Steel Pipe for Low-Temperature Service and Other Applications with Required Notch Toughness, approved November 1, 2018, (ASTM A333/A333M); IBR approved for § 192.113; appendix B to part 192. (4) ASTM A372/A372M-10, \"Standard Specification for Carbon and Alloy Steel Forgings for Thin-Walled Pressure Vessels,\" approved October 1, 2010, (ASTM A372/A372M), IBR approved for § 192.177(b). (5) ASTM A381/A381M-18, Standard Specification for Metal-Arc-Welded Carbon or High-Strength Low-Alloy Steel Pipe for Use with High-Pressure Transmission Systems, approved November 1, 2018, (ASTM A381); IBR approved for § 192.113; appendix B to part 192. (6) ASTM A578/A578M-96 (reapproved 2001), \"Standard Specification for Straight- Beam Ultrasonic Examination of Plain and Clad Steel Plates for Special Applications,\" (ASTM A578/A578M), IBR approved for § 192.112(c). (7) ASTM A671/A671M-20, Standard Specification for Electric-Fusion-Welded Steel Pipe for Atmospheric and Lower Temperatures, approved March 1, 2020, (ASTM A671/A671M); IBR approved for § 192.113; appendix B to part 192. (8) ASTM A672/A672M 09, \"Standard Specification for Electric- Fusion-Welded Steel Pipe for High-Pressure Service at Moderate Temperature,\" approved October 1, 2009, (ASTM A672/672M), IBR approved for § 192.113 and Item I, Appendix B to Part 192. (9) ASTM A691/A691M-19, Standard Specification for Carbon and Alloy Steel Pipe, Electric-Fusion-Welded for High-Pressure Service at High Temperatures, approved November 1, 2019, (ASTM A691/A691M); IBR approved for § 192.113; appendix B to part 192. (10) ASTM D638-03, \"Standard Test Method for Tensile Properties of Plastics,\" 2003, (ASTM D638), IBR approved for § 192.283(a) and (b). (11) ASTM D2513-18a, \"Standard Specification for Polyethylene (PE) Gas Pressure Pipe, Tubing, and Fittings,\" approved August 1, 2018, (ASTM D2513), IBR approved for Item I, Appendix B to Part 192. (12) ASTM D2517-00, \"Standard Specification for Reinforced Epoxy Resin Gas Pressure Pipe and Fittings,\" (ASTM D 2517), IBR approved for §§ 192.191(a); 192.281(d); 192.283(a); and Item I, Appendix B to Part 192. (13) ASTM D2564-12, \"Standard Specification for Solvent Cements for Poly (Vinyl Chloride)(PVC) Plastic Piping Systems,\" August 1, 2012, (ASTM D2564- 12), IBR approved for §192.281(b)(2). (14) ASTM F1055- 98 (Reapproved 2006), \"Standard Specification for Electrofusion Type Polyethylene Fittings for Outside Diameter Controlled Polyethylene Pipe and Tubing,\" March 1, 2006, (ASTM F1055-98 (2006)), IBR approved for § 192.283(a), Item I, Appendix B to Part 192. (15) ASTM F1055-98 (Reapproved 2006), \"Standard Specification for Electrofusion Type Polyethylene Fittings for Outside Diameter Controlled Polyethylene Pipe and Tubing,\" March 1,2006, ASTM F1055-98 (2006)), IBR approved for §192.283(a), Item I Appendix B to Part 192 ASTM F1924-12), \"Standard Specification for Plastic Mechanical Fittings for Use on Outside Diameter Controlled Polyethylene Gas Distribution Pipe and Tubing, \" April 1, 2012 (ASTM F1924-12), IBR approved for Item 1 Appendix B to Part 192. (16) ASTM F1948-12, (Standard Specification for Metallic Mechanical Fittings for Use on Outside Diameter Controlled Thermoplastic Gas Distribution Pipe and Tubing,\" April 1, 2012, (ASTM F1948-12), IBR approved for Item I, Appendix B to Part 192. (17) ASTM F1973-13, \"Standard Specification for Factory Assembled Anodeless Risers and Transition Fittings in Polyethylene (PE) and Polyamide 11 (PA11) and Polyamide 12 (PA12) Fuel Gas Distribution Systems,\" May 1, 2013, (ASTM F1973- 13), IBR approved for §192.204(b); and Item I, Appendix B to Part 192. (18) ASTM F2145-13, 'Standard Specification for Polyamide 11 (PA11) and Polyamide 12 (PA12) Mechanical Fittings for Use on Outside Diameter Controlled Polyamide 11 and Polyamide 12 Pipe and Tubing,\" May 1, 2013, (ASTM F2145-13), IBR approved for Item 1, Appendix B to Part 192. (19) ASTM F2600-09, \"Standard Specification for Electrofusion Type Polyamide-11 Fittings for Outside Diameter Controlled Polyamide-11 Pipe an Tubing,\" April 1, 2009, (ASTM F 2600-09) IBR approved for Item I, Appendix B to Part 192. (20) ASTM F2620-19,\"Standard Practice for Heat Fusion Joining of Polyethylene Pipe and Fittings,\" approved February 1, 2019, (ASTM F2620), IBR approved for §§192.281(c) and 192.285(b). (21) ASTM 2767-12, \"Specification for Electrofusion Type Polyamide-12 Fittings for Outside Diameter Controlled Polyamide-12 Pipe and Tubing for Gas Distribution.\" Oct 15, 2012, (ASTM F2767-12), IBR approved for Item I, Appendix B to Part 192. (22) ASTM F2785-12, \"Standard Specification for Polyamide 12 Gas Pressure Pipe, Tubing and Fittings,\" Aug. 1 2012, (ASTM F2785-12), IBR approved for Item 1, Appendix B to Part 192. (23) ASTM F2817-10, \"Standard Specification for Poly (Vinyl Chloride) (PVC) Gas Pressure Pipe and Fittings for Maintenance or Repair,\" Feb. 1, 2010 (ASTM F2817-10), IBR approved for Item 1, Appendix B to Pat 192. (24) ASTM F2945-12a \"Standard Specification for Polyamide 11 Gas Pressure Pipe, Tubing and Fittings,\" Nov 27, 2012 (ASTM F2945-12a), IBR approved for Item I, Appendix B to Part 192. (f) [Reserved] (g) Manufacturers Standardization Society of the Valve and Fittings Industry, Inc. (MSS), 127 Park St. NE., Vienna, VA 22180, phone: 703-281-6613, email: info@msshq.org; website: http://www.msshq.org/. (1) ANSI/MSS SP-44-2019, Steel Pipeline Flanges, published April 2020, (MSS SP- 44); IBR approved for § 192.147(a). (2) [Reserved] (h) NACE International (NACE), 1440 South Creek Drive, Houston, TX 77084: phone: 281-228- 6223 or 800-797-6223 Web site: http://www.nace.org/Publications/. (1) NACE Standard Practice 0102-2010 \"In-Line Inspection of Pipelines,\" Revised 2010-03-13, (NACE SP0102), IBR approved for §§ 192.150(a) and 192.493. (2) NACE SP0204-2008, Standard Practice, \"Stress Corrosion Cracking (SCC) Direct Assessment Methodology,\" reaffirmed September 18, 2008, (NACE SP0204); IBR approved for §§ 192.923(b); 192.929(b) introductory text, (b)(1) through (3), (b)(5) introductory text, and (b)(5)(i). (3) NACE SP0206-2006, Standard Practice, \"Internal Corrosion Direct Assessment Methodology for Pipelines Carrying Normally Dry Natural Gas (DG-ICDA),\" approved December 1, 2006, (NACE SP0206), IBR approved for §§ 192.923(b); 192.927(b), (c) introductory text, and (c)(1) through (4). (4) ANSI/NACE SP0502-2010, Standard Practice, \"Pipeline External Corrosion Direct Assessment revised June 24, 2010, (NACE SP0502), IBR approved for §§ 192.923(b); 192.925(b); 192.931(d); 192.935(b) and 192.939(a). (i) National Fire Protection Association (NFPA), 1 Batterymarch Park, Quincy, Massachusetts 02169, phone: (617) 984-7275; website: www.nfpa.org. (1) NFPA-30 (2012), \"Flammable and Combustible Liquids Code,\" 2012 edition, June 20, 2011, including Errata 30-12-1 (September 27, 2011) and Errata 30-12-2 (November 14, 2011), (NFPA-30), IBR approved for § 192.735(b). (2) NFPA 58, Liquefied Petroleum Gas Code, 2020 edition, effective August 25, 2019, (NFPA 58); IBR approved for § 192.11. (3) NFPA 59, Utility LP-Gas Plant Code, 2018 edition, effective September 6, 2017, (NFPA 59); IBR approved for § 192.11. (4) NFPA 70, National Electrical Code (NEC), 2017 edition, effective August 24, 2016, (NFPA 70); IBR approved for §§ 192.163(e); 192.189(c). (j) Pipeline Research Council International, Inc. (PRCI), c/o Technical Toolboxes, 3801 Kirby Drive, Suite 520, P.O. Box 980550, Houston, TX 77098, phone: 713-630-0505, toll free: 866-866-6766, Web site: http://www.ttoolboxes.com/. (Contract number PR3-805.) (1) AGA, Pipeline Research Committee Project, PR-3-805, \"A Modified Criterion for Evaluating the Remaining Strength of Corroded Pipe,\" (December 22, 1989), (PRCI PR-3-805 (R-STRENG)), IBR approved for §§ 192.485(c); 192.632(a); 192.712(b); 192.933(a) and (d). (2) [Reserved] (k) Plastics Pipe Institute, Inc. (PPI),105 Decker Court, Suite 825 Irving TX 75062, phone: 469-499-1044, http://www.plasticpipe.org/. (1) PPI TR-3/2012,HDB/HDS/PDB/SDB/MRS/CRS, Policies, \"Policies and Procedures for Developing Hydrostatic Design Basis (HDB), Hydrostatic Design Stresses (HDS), Pressure Design Basis (PDB), Strength Design Basis (SDB), Minimum Required Strength (MRS) Ratings, and Categorized Required Strength (CRS) for Thermoplastic Piping Materials or Pipe,\" updated November 2012, (PPI TR-3/2012), IBR approved for §192.121. (2) PPI TR-4, HDB/HDS/SDB/MRS, Listed Materials, \"PPI Listing of Hydrostatic Design Basis (HDB), Hydrostatic Design Stress (HDS), Strength Design Basis (SDB), Pressure Design Basis (PDB) and Minimum Required Strength (MRS) Rating For Thermoplastic Piping Materials or Pipe,\" updated March 2011, (PPI TR- 4/2012), IBR approved for § 192.121. § 192.8 How are onshore gathering lines and regulated onshore gathering lines determined? (a) An operator must use API RP 80 (incorporated by reference, see § 192.7), to determine if an onshore pipeline (or part of a connected series of pipelines) is an onshore gathering line. The determination is subject to the limitations listed below. After making this determination, an operator must determine if the onshore gathering line is a regulated onshore gathering line under paragraph (b) of this section. (1) The beginning of gathering, under section 2.2(a)(1) of API RP 80, may not extend beyond the furthermost downstream point in a production operation as defined in section 2.3 of API RP 80. This furthermost downstream point does not include equipment that can be used in either production or transportation, such as separators or dehydrators, unless that equipment is involved in the processes of \"production and preparation for transportation or delivery of hydrocarbon gas\" within the meaning of \"production operation.\" (2) The endpoint of gathering, under section 2.2(a)(1)(A) of API RP 80, may not extend beyond the first downstream natural gas processing plant, unless the operator can demonstrate, using sound engineering principles, that gathering extends to a further downstream plant. (3) If the endpoint of gathering, under section 2.2(a)(1)(C) of API RP 80, is determined by the commingling of gas from separate production fields, the fields may not be more than 50 miles from each other, unless the Administrator finds a longer separation distance is justified in a particular case (see 49 CFR § 190.9). (4) The endpoint of gathering, under section 2.2(a)(1)(D) of API RP 80, may not extend beyond the furthermost downstream compressor used to increase gathering line pressure for delivery to another pipeline. (5) For new, replaced, relocated, or otherwise changed gas gathering pipelines installed after May 16, 2022, the endpoint of gathering under sections 2.2(a)(1)(E) and 2.2.1.2.6 of API RP 80 (incorporated by reference, see § 192.7) - also known as \"incidental gathering\" - may not be used if the pipeline terminates 10 or more miles downstream from the furthermost downstream endpoint as defined in paragraphs 2.2(a)(1)(A) through (a)(1)(D) of API RP 80 (incorporated by reference, see § 192.7) and this section. If an \"incidental gathering\" pipeline is 10 miles or more in length, the entire portion of the pipeline that is designated as an incidental gathering line under 2.2(a)(1)(E) and 2.2.1.2.6 of API RP 80 shall be classified as a transmission pipeline subject to all applicable regulations in this chapter for transmission pipelines. (b) Each operator must determine and maintain for the life of the pipeline records documenting the methodology by which it calculated the beginning and end points of each onshore gathering pipeline it operates, as described in the second column of table 1 to paragraph (c)(2) of this section, by: (1) November 16, 2022, or before the pipeline is placed into operation, whichever is later; or (2) An alternative deadline approved by the Pipeline and Hazardous Materials Safety Administration (PHMSA). The operator must notify PHMSA and State or local pipeline safety authorities, as applicable, no later than 90 days in advance of the deadline in paragrap","truncated":true,"body_characters":581516}