dead cells assist mode

This proposed regulatory amendment would apply to gas distribution, gas transmission, offshore gas gathering, and Type A regulated onshore gas gathering pipelines. 72. Total Annual Burden Hours: And PHMSA has no reporting requirements for intentional releases of gas at all. However, since gas migration can be affected greatly by soil and weather conditions, the 2,000 square feet element of this approach may not be pipeline in accordance with 192.9, but they are not required to have procedures for other subparts M and I requirements. Each operator is required to submit geospatial data appropriate for use in the NPMS or data in a format that can be readily converted to geospatial data; the name and address of the person with primary operational control (to be known as its operator), and a means for a member of the public to contact the operator for additional information about the pipeline facilities it operates. all Regulatory Requirements Lag Commercially Available, Advanced Leak Detection Technologies, Automobile-Based Leak Detection Equipment, Integration of Advanced Technologies and Practices Within Advanced Leak Detection Programs, 5. While EPA identified between 9498 LNG storage facilities as active each year from 20112017, only 8 such facilities reported emissions under Subpart W during that timeframe. Despite recently expanded requirements that operators of certain gas gathering pipelines maintain sufficient damage prevention programs under 192.614, PHMSA regulations do not currently require operators of gas gathering pipelines to submit geospatial location data into NPMS. 262. the Federal Register. U.S. Methane Emissions Reduction Action Plan Viewed against those considerations and the compliance costs estimated in the Preliminary RIA, PHMSA expects its proposed amendments will be a cost-effective approach to achieving the commercial, public safety and environmental benefits discussed in this NPRM and its supporting documents. (2012). PHMSA has not proposed that offshore gas gathering pipelines would be subject to its proposed default requirement within 192.763 for any leak be considered a grade 2 leak at a minimum. UNGSFs are subject to specific safety requirements set forth in 192.12. For example, the BPX Energy presentation at the 2021 EPA Methane Detection Technology Workshop noted that the company's stationary sensors refresh every 15 minutes. Because of these significant risks to public safety and the environment posed by Types B and C gathering lines, PHMSA has proposed that no later than December 27, 2021) to update their inspection and maintenance plans to address these self-executing requirements.[194]. An operator must document each emergency release without mitigation described in paragraph (b) of this section, including the justification for release without mitigation. Gas transmission (192.706), distribution (192.723), offshore gas gathering, and Type A, Type B, and certain Type C gathering (192.9 and 192.706) pipeline operators must perform periodic leakage surveys. 8, 2015, pp. Distribution pipelines made of copper, wrought iron, and non-polyethylene plastic also exist but are less common. Second, PHMSA is not proposing to refer to hazards or leaks hazardous to public safety where an explicit reference to environmental hazards would either be unnecessary ( PHMSA estimates that it may receive 508 requests to extend the deadline for remedying leaks on average per year (341 from gas gathering operators and 167 from gas transmission operators), and that each of these requests would require approximately 8 hours to prepare. PHMSA proposes to revise 192.167(a)(2) governing on new, replaced, relocated, or otherwise changed compressor stations on gas transmission and part 192-regulated onshore gas gathering pipelines to state that blowdowns of those facilities during emergency shutdowns must be directed toward locations where the released gas would not create a hazard to Only individuals qualified under subpart N of this part may conduct leakage survey, investigation, grading, and repair. Pipeline Accident Report: Atmos Energy Corporation Natural Gas-Fueled Explosion: Dallas, Texas: February 23, 2018. NTSB/PAR21/01. PHMSA solicits comment on whether, within a final rule in this proceeding, it would be appropriate to require NPMS participation for Type R gathering pipelines not regulated under part 192. https://www.regulations.gov/ Start Printed Page 31953 equivalents) of the annual GHG emissions in 2019 within the United States, whereas carbon dioxide made up 79 percent of the total GHG emissions over the same period. 51. PHMSA invites comments on the value of introducing requirements for continuous monitoring systems, via stationary gas detection systems, pressure monitoring, or other means (including requirements for the use of specific methods or technologies), on other types of pipeline facilities (including whether continuous monitoring would be most appropriate at any particular facilities or locations, or in other particular conditions) within a final rule in this rulemaking proceeding. Leak repair extensions under 192.760(h) may be requested only if (1) the leak repair pursuant to an alternative schedule would not result in increased public safety risk, and (2) the operator can demonstrate that the prescribed repair schedule is impracticable, an alternative repair schedule is necessary for safety, or remediation within the specified time frame would result in the release of more gas to the environment than would otherwise occur if the leak were allowed to continue. Technol. The Committee periodically reviews requests for updates and may create a task group, if necessary, to issue new or amended guidance of versions of the GPTC Guide. These proposed documentation requirements would support periodic evaluation and improvement of their ALDPs pursuant to proposed 192.763(a)(4) as well as regulatory oversight activity by PHMSA and its State partners. i.e., As described in section II.C, equipment venting, blowdowns, and other vented emissions of methane account for a large portion of the total methane emissions from U.S. natural gas pipeline facilitiesparticularly natural gas transmission pipelines. [63] British Columbia, Minister's Statement on 619 Lives Lost During 2021 Heat Dome (June 7, 2022). 337 Issue 6614. [232] (3) Gas distribution pipeline systems protected by a distributed anode system, in the area of deficient readings identified during a cathodic protection survey pursuant to 195.463 and appendix D, until the cathodic protection deficiency is remediated. A surveyor typically uses a flame ionization detector (FID), infrared gas detector, optical gas imaging (OGI) device,) or other gas detector to sample gas above a buried pipeline, inside underground structures, and possibly in the soil. 59. pressure) and other conditions ( Issued in Washington, DC, on May 4, 2023, under authority delegated in 49 CFR 1.97. 60117. Williams et al., Rapid Intensification of the Emerging Southwestern North American Megadrought in 20202021, 12 This proposal would replace the existing requirement at 192.723 to use leak detection equipment and is described in more detail under the discussion of that section below. https://www.regulations.gov/. Start Printed Page 31920 Gas Gathering RIA at 15. Leaks of toxic or corrosive gases from part 192-regulated pipeline facilities can have serious public safety consequences. We study the Gaussian case first. 49 U.S.C. Start Printed Page 31928 In Class 3 locations, the minimum patrol frequency at highway and railroad crossings is four times each calendar year. Similarly, PHMSA also refers to part 192-regulated gas pipelines to collectively refer to gas transmission, distribution, offshore gathering, and Types A, B, and C onshore gathering pipelines subject to part 192 requirements. With respect to the meaning of the term failure, operators have applied the definition in the instructions for the Gas Transmission and Gas Gathering Pipeline System Annual Report,[283] On May 2, 2019, PHMSA issued another advisory bulletin to remind operators of the risks to pipeline facilities from large earth movement, including subsidence and erosion events that can be intensified due to climate change. regulatory oversight of those facilities. All Type A gathering pipelines would therefore be subject to the proposals introduced within the NPRM for transmission lines, including each of the following: revised definitions, to include a definition of leak or hazardous leak to account for environmental hazards in connection The National Environmental Policy Act (NEPA, 42 U.S.C. [198] Consistent with that historical approach, PHMSA regulations permit reliance on non-instrumented leak detection methods such as smell or visual surveys of gas transmission pipeline infrastructure and rights of way that are more appropriate for discovering ruptures or accumulated gas than smaller leaks. 14. Title: but is much more potent in trapping heat in the atmosphere. Other areas of industry interest are aerial sensing platforms and continuous monitoring. E&E News PHMSA also proposes to allow downgrading a leak grade only if a repair has been attempted. PHMSA regulations currently require only annual right-of-way patrols on most gas transmission, offshore gathering, and Type A-regulated onshore gathering lines. (3) all bare steel, unprotected steel, and cast-iron systems), leakage surveys must be performed once every 3 calendar years, with an interval between surveys not to exceed 39 months. 174. 112778 (2022). White House Office of Domestic Climate Policy, Defaults to 5 samples. Start Printed Page 31910 PHMSA invites comment on the value of either explicitly listing leak-prone materials (either within part 192 or within periodically-issued implementing guidance). PHMSA proposes to characterize a grade 2 leak as a leak with a probable future hazard to public safety or a significant hazard to the environment. PHMSA has, pursuant to section 114 of the PIPES Act of 2020, initiated a study on the best available technology or practices to reduce methane emissions associated with design, construction, operations, and maintenance of pipeline facilities, and will initiate a rulemaking based on the results of that study. Summary of Transmission and Regulated Gathering Leakage Survey Amendments. 180. Advanced Leak Detection Programs192.763, 1. The Committee also has members from the regulatory community, including PHMSA, the National Transportation Safety Board (NTSB), and other Federal and State regulatory agencies. Operator procedures may supplement those proposed minimum grade 1 criteria as desired. In this case, the time period for repair is the remaining time allowed for repair under its new grade measured from the time the leak was detected. PHMSA solicits comment on whether it would be appropriate to apply any of the requirements proposed herein to Type R gathering pipelines not currently regulated under part 192. [277] Upon notifying the distribution operator, a subsequent reinspection found that hazardous conditions remained at nine leak locations. State of New York Department of Public Service, Case 21G0165, 2020 Pipeline Safety Performance Measures Report at Appendix K (June 17, 2021). 305. Due to precipitation, wind, and wet soil conditions, the operator's RMLD survey was ineffective and the operator's barhole[176] Sources of Emissions From Gas Pipeline Facilities, Methane Emissions DataAll Natural Gas Pipeline Facilities, Methane Emissions DataNatural Gas Distribution Pipelines, Methane Emissions DataNatural Gas Transmission and Storage, Methane Emissions DataGathering Pipelines, 1. 26. Moreover, this requirement would ensure that operators of Type B gathering lines are prepared to take appropriate immediate and continuous actions in response to a grade 1 leak, which could require activation of an emergency response plan. [294] 195. 51615169., doi:10.1021/es505116p. 91,000 miles of Type C gas gathering pipelines are subject to 192.703(c). PHMSA estimates that it would take operators, on average, 80 hours annually to develop these records. e.g., While incident reports provide valuable information on major emissions events with critical safety consequences, existing incident reporting criteria and the exclusion of intentional releases from reporting requirements means the current reporting scheme does not capture data on many significant emissions events. Initiatives) responding to congressional mandates in title II of The PIPES Act of 2020 directing PHMSA to, among other things, amend its subpart P distribution IM program requirements. https://www.whitehouse.gov/briefing-room/statements-releases/2021/01/27/fact-sheet-president-biden-takes-executive-actions-to-tackle-the-climate-crisis-at-home-and-abroad-create-jobs-and-restore-scientific-integrity-across-federal-government/. Section 192.8 also defines three types of regulated onshore gas gathering pipelines subject to part 192 requirements: Type A, Type B, and Type C gathering pipelines. must manage leak detection and repair, instead giving operators considerable discretion to determine when and how they address leaks on their pipelines. PHMSA proposes to introduce requirements for reporting large-volume releases of gas from all gas pipeline facilities, including intentional releases, that are not currently captured by the definition of an incident in part 191. The jump, penalty-value and min_size I vary. Amendments to subpart O requirements pursuant to the RIN2 Final Rule will not disturb the pertinent requirements of that subpart described above. These markup elements allow the user to see how the document follows the 12866 (Regulatory Planning and Review),[296] soap bubble testing) or technologies ( https://agupubs.onlinelibrary.wiley.com/toc/24711403/2021/5/6 PHMSA proposes, in 192.706(a), to allow operators to request the use of human senses, in lieu of leak detection equipment, when conducting a leak survey if the operator provides advance notification to PHMSA in accordance with 192.18. Grade 2 leaks with a repair deadline of less than 30 days must be re-evaluated at least once every 2 weeks until the repair is complete. For example, in a presentation on the Fugitive Emissions Abatement Simulation Toolkit (FEAST) model at the 2021 EPA Methane Detection Technology Workshop, modeling based on controlled tests and field evaluations demonstrated that at a given detection threshold, survey frequency is directly proportional to fugitive emissions reductions. [116] (June 1996) (the 1996 GRI/EPA Report). documents in the last year, by the Energy Department According to the findings from the 3rd and 4th National Climate Assessment Reports released by the U.S. Pipeline safety stakeholdersincluding journalists, operators, emergency responders, excavators, elected officials, public interest advocates, and PHMSA and State regulatorsuse the NPMS to obtain important pipeline-safety related information, including the locations of pipelines and related infrastructure, the names and contact information of pipeline operators, and other attributes of pipelines such as commodities transported and diameter. 1/2 Section 192.706 currently requires gas transmission and Types A and B gathering pipelines that are not odorized to be surveyed with leak detection equipment at least twice each calendar year in Class 3 locations, and at least four times each calendar year in Class 4 locations. All gas transmission pipelines are subject to maintenance requirements at part 192, subpart M. Section 192.706 requires gas transmission operators to perform leakage surveys on most gas transmission pipelines at least once every calendar year. In that same panel, another operator reported that aerial surveys were not cost-effective for all of their facilities, but that aerial surveys, especially those mounted on UAS, have the additional advantage of being able to maneuver around locations or facilities that may be difficult for operator personnel to safely access with traditional equipment. Pg. This mandatory information collection covers the collection of data from operators of natural gas pipelines, UNGSFs, and LNG facilities for annual reports. extreme temperatures and flooding) are likely to be the most significant, and because these communities tend to have limited adaptive opportunities due to a greater dependence on climate-sensitive resources (such as local water and food supplies), economic opportunities ( (2017); Distribution pipelines are typically a part of a distribution system that transports gas received from a transmission pipeline by a distribution center (often located at the so-called city gate), and then to homes and businesses through a network of gas mains and service pipelines. However, despite the significant environmental impact of those emissions, PHMSA and State pipeline safety regulations have largely avoided explicit restrictions on vented emissions. [59] 64 FR 43255 (Aug. 10, 1999). 295. PHMSA further proposes that each ALDP must be validated and documented with engineering tests and analyses, and that such records should be maintained for five years after the date that ALDP is no longer used by the operator. equivalent per year.[77]. (last accessed July 25, 2022). As previously discussed in section II.C., leaks on gas transmission line pipe are less common than leaks on gas distribution pipeline pipe. requires Federal agencies to consider the consequences of major Federal actions and prepare a detailed statement on actions significantly affecting the quality of the human environment. that agencies use to create their documents. False positives require confirmation by operator personnel, and therefore cut into the cost-effectiveness of such surveys. Second, PHMSA provides States with damage prevention grants to establish and improve comprehensive State damage prevention programs. also suggested that applying prescriptive regulations could potentially limit the development of different technologies and innovations, stating that providing operators with flexibility can create opportunities and incentives for developing new technologies and innovations in leak detection and measurement. 2000) (API RP 80). EDF commented that parts-per-billion detection is important in this effort in light of the potential for hidden underground leaks, where only a small volume of gas may migrate through the pavement despite a significant leak buried under the street. Current Expiration Date: 23. For example, recent analysis using top-down methods from the International Energy Agency (IEA) released in early 2022 found that global methane emissions from the energy sector are about 70% greater than the official statistics reported by national governments. specifically. Start Printed Page 31919 https://primis.phmsa.dot.gov/meetings/MtgHome.mtg?mtg=152. PHMSA proposes to require that an operator's procedures must provide for pinpointing the location of all leak indications with the use of handheld leak detection equipment (192.763(a)(2)(ii)). Abstract: The meeting itself included presentations and panel discussions from representatives from PHMSA, EPA, NAPSR, EDF, PST, the United Association of Plumbers and Pipefitters, GPTC, AGA, American Public Gas Association, INGAA, GPA, Pipeline Regulatory Consultants, Gas Technology Institute, the Methane Emissions Technology Evaluation Center (METEC) at Colorado State University, QuakeWrap Inc., Bridger Photonics, Safetylics, ProFlex Technologies, ABB, the Federal Energy Regulatory Commission, and the National Association of Regulatory Utility Commissioners. This new large-volume gas release reporting requirement would be applicable to all gas pipeline facility operators, including (but not limited to) operators of jurisdictional underground storage and LNG facilities, as well as Type R gas gathering pipelines. Operators must consider ways to improve their leak detection programs based on leak detection performance data and advances in technology. Pipeline and Hazardous Materials Safety Administration (PHMSA), Department of Transportation (DOT). As described above in section II.C.2, incidents and leaks occur on Type B and Type C gathering pipelines just as they occur on Type A pipelines. Any distribution pipeline protected by a distributed anode system where the cathodic protections survey under 195.463 showed a deficient reading during the most recent cathodic protection survey. Summaries of each E.O. PHMSA proposes defining minimum standards for leak survey practices and equipment on gas distribution pipelines through reference to the proposed ALDP performance standard in 192.763. 270. PHMSA proposes an exception from 191.23 safety-related condition reporting requirements for events that are reported as large-volume gas releases. E.O. sayler.palabrica@dot.gov. Approximately 40 of the Committee's members, including PHMSA, are voting members. More about time series analysis: Time traveling with Data Science (Part 1) Time Traveling with Data Science: Outlier Detection (Part 3) Change point detection: Different types of change points Start Printed Page 31976. Valves, flanges and certain other facilities. EPA annually updates the methodology in the GHGI to improve accuracy and completeness. For example, an operator may vent a grade 1 leak by drilling multiple barholes into the soil in the immediate vicinity of the leak or by leaving vault boxes open to the atmosphere before grading the leak. NTSB recommended that the International Code Council, the National Fire Protection Association, and the Gas Technology Institute (GTI) cooperate to develop standards and incorporate provisions in applicable national codes to require methane detection systems for all types of residential occupancies with gas service. requires agencies consider whether the impacts associated with significant variations between domestic and international regulatory approaches are unnecessary or may impair the ability of American business to export and compete internationally. Requirements for Type A gathering pipelines are defined in 192.9(c), which requires that a Type A pipeline comply with the requirements of part 192 for transmission lines, subject to specific exceptions listed in that paragraph. The concentration of each potential leak indication measured in-plume is likely to be lower than the concentration measured in the immediate vicinity of the emissions source during a leak investigation. [219] 224. 49. Start Printed Page 31942 information, PHMSA's current assessment is that the proposed 192.763(b) ALDP performance standard represents a threshold of detection demanding enough to ensure that operator ALDPs are capable of detecting nearly all leaks on gas gathering, transmission, and distribution pipelines. Inventory of U.S. Greenhouse Gas Emissions and Sinks: 19902020, Annex 3.61 See, e.g., Further, 49 U.S.C. 1, 2022). The Cybersecurity & Infrastructure Security Agency (CISA) and the Pipeline Cybersecurity Initiative (PCI) of the U.S. Department of Homeland Security also conduct ongoing activities to address cybersecurity risks to U.S. pipeline infrastructure and may introduce other cybersecurity requirements and guidance for gas pipeline operators.[312]. [73] Expiration Date: Indeed, a review of publicly available information on the initiatives identified by AGA et al. with human senses or animal senses) only for gas transmission and Types A, B, or C gathering pipelines in non-HCA, Class 1 and Class 2 locations, and then only with prior notification and review by PHMSA pursuant to 192.18. (3) Each operator must re-evaluate each grade 3 leak at least once every six months until repair of the leak is complete. PHMSA has preliminarily determined that the proposed rule could result in a significant economic impact on a substantial number of small entities, depending on the degree to which operators are able to pass-through costs. 74. (c) See In 192.169, revise paragraph (b) as follows: (b) Each vent line that exhausts gas from the pressure relief valves of a compressor station must extend to a location where the gas may be discharged without hazard to public safety. PHMSA proposes regulatory amendments that implement congressional mandates in the Protecting our Infrastructure of Pipelines and Enhancing Safety Act of 2020 to reduce methane emissions from new and existing gas transmission pipelines, distribution pipelines, regulated (Types A, B, C and offshore) gas gathering pipelines, underground natural gas storage facilities, and liquefied natural gas facilities. PHMSA Regulations Pertinent to Unintentional Releases of Methane and Other Gases, Part 192Regulated Gas Gathering Pipelines, 2. This is similar in principle to the existing continuous improvement requirements under IM requirements in part 192, subparts O and P, as well as requirements for certain operators to periodically review procedures under 192.605(b)(8) and (c)(4). Therefore, the total number of leaks on Types A and B gathering lines not subject to any meaningful Federal repair requirements is likely even higher. Start Printed Page 31907 The urgency of reducing methane emissions to stave off or avoid the worst Some grade 2 leaks that are evaluated by the criteria listed above may justify a scheduled repair within 5 working days, whereas others might justify repair within 30 days. n_bkps (int) number of breakpoints to find before stopping. If gas cannot be supplied in sufficient quantity to prevent the formation of a mixture of gas and air hazardous to public safety, a slug of inert gas must be introduced into the pipeline before the gas. The form also collects data on leaks from these systems as well as excavation damages. 253. characterized methane concentration as a more appropriate metric for evaluating the public safety risks from explosion than for estimating the amount of methane going to atmosphere. Records validating equipment calibration and failures indicating recalibration is necessary must be maintained for 5 years after the date the individual device is retired by the operator. An emissions rate of 10 CFH correlates to emissions of ca. The grading criteria from GPTC Guide Appendix G19211 and Appendix G19211A are discussed below (hereafter, references to the GPTC Guide refer specifically to Appendix G19211 and 11A unless otherwise specified). https://unfccc.int/process-and-meetings/the-paris-agreement/the-paris-agreement. 37. www.dot.gov/privacy. [227] PHMSA regulations cover several types of gas pipeline facilities, including gas gathering pipelines, gas transmission pipelines, gas distribution pipelines, LNG facilities, and UNGSFs. ruptures is a Python library for off-line change point detection. Several stakeholders at the 2021 Public Meeting emphasized the importance of flexibility in PHMSA's consideration of advanced leak detection standards, recommending that PHMSA assess the suite of leak detection technologies that are currently commercially available and introduce requirements that promote continued development of advanced technologies. Impacts, Risks, and Adaptation in the United States: Fourth National Climate Assessment, Volume IINortheast de minimis, Gas Gathering RIA at 15; PHMSA, Annual Report Mileage for Natural Gas Transmission and Gathering Systems. (Aug. 1, 2022), focused on ensuring compliance with pertinent Federal and State requirements that (as explained above) generally lack meaningful requirements for timely grading and repair of leaks other than hazardous leaks. For those leaks from gas transmission, regulated gathering, and distribution facilities that are not considered hazardous under current PHMSA regulations, some operators may incorporate the GPTC Guide leak identification, grading, and mitigation criteria within their inspection and maintenance procedures, using the LEAKS mnemonic as an aide to their personnel tasked with managing leak detection and remediation. Proposed alternatives are most helpful when they are supported by a discussion of their value for public safety and environmental protection, as well as their technical feasibility, cost-effectiveness, and practicability. Eric S. Blake and David A. Zelinsky. PHMSA received 7 comments from individual pipeline operators, leak detection technology service providers, public safety groups, and industry trade organizations, as summarized below. This revision would [128] Paragraph (b)(1) provides minimum criteria for grade 1 leaks that would need to be included in operators' leak grading procedures as they demonstrate that a leak poses an existing or probable hazard to public safety or grave hazard to the environment. Further, OIRA has not designated this NPRM as a significant energy action. [85] The EPA's proposed emission standards, including emissions monitoring, repair, and maintenance requirements, would apply to numerous types of facilities (including pneumatic controllers and pumps, storage vessels, and sweetening units amongst others) across a defined source category. See49 U.S.C. PHMSA also notes that boil-offs of LNG storage tanks at part 193 LNG facilities to accommodate maintenance activity are similar in function to blowdowns on part 192 pipeline facilitiesand similarly can be significant contributors of methane emissions if released to atmosphere. (4) Prepare, update, and follow a manual of written procedures for conducting operations, maintenance, and emergency response in accordance with 192.605. While any leak of methane from a gas pipeline system necessarily entails environmental harm proportional to the amount of methane released to the atmosphere, PHMSA proposes introducing minimum sensitivity standards for leak detection equipment at 192.763 (discussed below) in recognition that some leaks are so small that the harm they present does not warrant expending the resources necessary to detect and repair them, particularly where the leak is approaching the limits of detection with commercially available advanced technologies. PHMSA's references to part 192 within this NPRMincluding the proposed amended regulatory text at its conclusionreflect the regulatory text and organization as amended by the RIN2 Final Rule unless otherwise noted. Therefore, the proposed revision would help ensure baseline regulatory requirements for personnel qualification are met when performing those activities. Pipeline operator leak detection and repair practices are similarly insufficient to meet the risks to the environment and public safety from leaks of methane and other gases from gas pipeline infrastructure. Vented and other releases of cryogenic LNG to the atmosphere also present unique safety hazards and can cause flammable vapor clouds, jet or pool fires in the presence of an ignition source, or a sudden and explosive phase change if LNG encounters a warm surface such as water. Atmosphere Data from Lamb et al. Most of the pipeline facilities for which PHMSA proposes leak detection and repair requirements (and associated recordkeeping requirements) are already subject to such requirementsthis NPRM simply proposes to enhance and expand those requirements. Modern systems are predominately polyethylene plastic and protected steel ( The proposed broad-based incorporation of the PIPES Act of 2020 section 114 mandate would promote operator compliance efforts by aligning Submit a formal comment. Specifically, PHMSA proposes to require that an ALDP must be capable of detecting all leaks that produce a reading of 5 ppm or greater of gas when measured from a distance of 5 feet from the pipeline, or within a wall-to-wall paved area. Change point detection: a general formulation for more information about stopping rules of sequential algorithms. 71. at 51 (Jan. 2022). before Incident reports for gas distribution (Form F7100.1), transmission and part-192 regulated gathering (Form F7100.2), and Type R gathering pipelines (Form F7100.2.2) provide limited information regarding unintentional releases, as only unintentional releases of at least 3 MMCF need be reported. EPAHQOAR202103170183. PHMSA also proposes to require a minimum sensitivity for leak detection equipment used in leakage surveys and leak investigations. et seq.) U.S. 213. NOAA National Centers for Environmental Information, 281. 229. PHMSA proposes to revise 192.727(b) and (c) governing abandonment of gas transmission, distribution, offshore gathering, and Type A gathering pipelines to provide that the existing exception for small gas purge volumes in those paragraphs would be available if purging would not create a risk to public safety specifically. Compendium of State Pipeline Safety Requirements and Initiatives Providing Increased Public Safety Levels Compared to Code of Federal Regulations, Third Edition documents in the last year, 1476 65 FR 67249 (Nov. 9, 2000). The current pipeline safety regulations do not include A stationary gas sampler must be located near potential leak locations in order to detect leaks, laser-based systems must have potential leak sources or migration paths within the line of sight and effective range of the device, though some newer devices are capable of scanning. Aside from the public safety risks discussed above, leaks from gas distribution, transmission, and gathering pipelines are also a significant contributor to climate change. For example, for distribution main leaks, an emission factor in kg CH4 One type of technology may not always be appropriate for every flammable, corrosive, or toxic gas, each type of pipeline facility or even across This would result in an additional 593 responses and 7,116 burden hours for this information collection. See New Jersey adopted an energy-related master plan in their overall State-wide climate goals that specifically directs the State utility commission to establish a standard for the use of advanced leak detection technologies when performing leakage surveys. GHGI data on the natural gas transmission and storage segment reflects both onshore and offshore sources. Comments and data on this question are especially helpful to PHMSA when they are supported by research or operational experience with the exclusive use of human senses for leakage surveys, along with the potential safety and environmental benefits and potential costs of a particular approach (including whether that approach would be technically feasible, cost-effective, and practicable). Hurricane Nicholas in the Gulf of Mexico in September 2021 caused widespread flooding and weeks of blackouts on the U.S. Gulf Coast, much as the increasingly long wildfire season in California is now routinely accompanied by threats of rolling blackouts. PHMSA's proposed grade 1 leak criteria resemble those in the GPTC Guide and, consistent with that framework, are intended to prioritize for immediate repair those leaks that pose a significant hazard to people and property. Monthly Global Climate Report for Annual 2021 The requested revision would revise form PHMSA F7100.11, the Gas Distribution Annual Report, to collect the total number of leaks identified within a calendar year, emissions from leaks by grade, and estimated emissions from other sources by source categories. PHMSA proposes to revise this information in conjunction with proposed regulatory changes made in the Pipeline Safety: Gas Pipeline Leak Detection and Repair NPRM which includes various recordkeeping requirements for operators pertaining to leak detection and remediation activities. or 91,000 miles of Type C gas gathering pipelines are subject to 192.706 leakage survey requirements. Areas that are projected to have less total precipitation and higher temperatures will likely become more susceptible to drought and wildfires as a result; as described below, the United States has already seen the acreage affected by wildfires trend upwards in recent decades. [78] [12], Once emitted into the atmosphere, some GHGs can persist in the atmosphere for a long time. PHMSA proposes to clarify that leakage surveys, investigation, and repair activities are covered tasks under part 192, subpart N and therefore covered by operator qualification requirements in that subpart. 312. [102] Finally, an UNGSF is defined at 192.3 as a gas pipeline facility that stores natural gas underground incidental to the transportation of natural gas, including: (1) a depleted hydrocarbon reservoir; (2) an aquifer reservoir; or (3) a solution-mined salt cavern. Consistent with section 113 of the PIPES Act of 2020, PHMSA proposes to require the use of leak detection equipment and practices meeting the ALDP standard in proposed 192.763 (see section IV.B) for leakage surveys on most onshore gas transmission and Types A, B and C gathering pipelines. Because of this, PHMSA expects the burden for completing form PHMSA F7100.11 to increase to 23.5 (17.5+6) hours per report adding a total of 8,676 (6 hours 1,446 operators) hours to the overall burden for this information collection. 219. bubbles from an offshore, submerged pipeline). O, and CH4. Each operator of a gas distribution pipeline must conduct periodic leakage surveys with leak detection equipment in accordance with this section. L. 9639), as amended by the Uruguay Round Agreements Act (Pub. decreased IPCC, These proposed PHMSA20210039, Pipeline Leak Detection, Leak Repair and Methane Emission Reductions Public Meeting at 45 (May 24, 2021). \hat{t}_1,\dots,\hat{t}_K := \arg\min_{t_1,\dots,t_K} V(t_1,\dots,t_K). The value here was calculated assuming a density of methane of 0.01926 kg/ft3. The limitations of PHMSA's existing leakage survey and patrol regulations thus currently allow for extended periods of time during which leaks can degrade into catastrophic integrity failures, allow gas to build up and ignite, or emit a substantial amount of methane or other (flammable, toxic or corrosive) gases to the environment. See, e.g., PHMSA notes that some LNG facility operators may operate transmission pipelines supplying natural gas to their facilities; those operators could use their existing leakage survey practices as a foundation for development of leakage survey requirements tailored to their LNG facilities. European Parliament, EU BriefingFit for 55 Package: Reducing Methane Emissions in the Energy Sector (Mar. This NPRM proposes to implement several provisions of the PIPES Act of 2020, including sections 113 (codified at 49 U.S.C. Emissions from power generation are estimated elsewhere in the GHGI. is equivalent to 25 metric tons of CO2 PHMSA invites comment on whether, within a final rule in this proceeding, there would be value in adopting hydrogen gas pipeline-specific provisions (in lieu of or in addition to the provisions proposed herein). Additionally, most Type C gathering pipelines are, pursuant to 192.9(f)(1), not even subject to PHMSA's minimal existing requirements for leakage surveys (192.706) and repair of hazardous leaks (192.703(c)).[286]. This document has been published in the Federal Register. The operator must maintain records that the leak detection equipment has been validated for five years after the date that the device ceases to be used in the operator's ALDP. 22. This form change is applicable to gas transmission, offshore gas gathering, and Type A, B, and C regulated onshore gas gathering pipelines. 1/2 https://www.eenews.net/articles/interior-threatens-colorado-river-cuts/. [16] If a permanent repair is infeasible, 192.711 merely requires that any temporary measure addresses public safety, again excluding the environment from explicit consideration. 06/02/2023, 204 You may submit comments identified by the docket number PHMSA20210039 by any of the following methods: E-Gov Web: https://www.regulations.gov. 20. 145. Further, the authors of the Brandt study point to limited sample sizes and changing technologies as other potential sources of error in bottom-up emissions estimates. PHMSA proposes to require a relief device be repaired or replaced immediately if it operates above the pressure limits in 192.201(a) or 192.739, fails to operate, or otherwise fails to provide reliable overpressure protection due to the potential consequences of overpressurizing the pipeline. 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