[Federal Register Volume 89, Number 58 (Monday, March 25, 2024)]
[Notices]
[Pages 20751-20755]
From the Federal Register Online via the Government Publishing Office [www.gpo.gov]
[FR Doc No: 2024-06155]



[[Page 20751]]

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DEPARTMENT OF TRANSPORTATION

Pipeline and Hazardous Materials Safety Administration

[Docket No.: PHMSA-2022-0085]


Pipeline Safety: Information Collection Activities: Mitigation of 
Ruptures on Onshore Gas Transmission and Gathering, Hazardous Liquid, 
and Carbon Dioxide Pipeline Segments Using Rupture-Mitigation Valves or 
Alternative Equivalent Technologies and Blending of Hydrogen Gas and 
Natural Gas Within Gas Pipelines

AGENCY: Pipeline and Hazardous Materials Safety Administration (PHMSA), 
Department of Transportation (DOT).

ACTION: Notice and request for comments.

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SUMMARY: In accordance with the Paperwork Reduction Act of 1995, PHMSA 
invites public comments on its intent to request the Office of 
Management and Budget's (OMB) approval of changes to existing 
information collections under OMB control numbers 2137-0627 (National 
Registry of Pipeline and LNG Operators), 2137-0635 (Pipeline 
Operators), 2137-0635 (Incident Reports for Natural Gas Pipeline 
Operators), 2137-0629 (Annual Report for Gas Distribution Operators), 
2137-0522 (Annual Reports for Gas Pipeline Operators), 2137-0614 
(Hazardous Liquid Pipeline Operator Annual Reports), and 2137-0596 
(National Pipeline Mapping Program). The proposed information 
collection changes would provide data necessary to demonstrate an 
alternative approach to the implementation of Recommendation P-11-11 
made by the National Transportation Safety Board (NTSB) and allow PHMSA 
to identify trends related to the blending of hydrogen gas and natural 
gas within gas pipelines from operator-submitted data.

DATES: Interested persons are invited to submit comments on or before 
May 24, 2024.

ADDRESSES: Comments may be submitted in the following ways:
    E-Gov Website: https://www.regulations.gov. This site allows the 
public to enter comments on any Federal Register notice issued by any 
agency.
    Fax: 1-202-493-2251.
    Mail: Docket Management System; U.S. Department of Transportation, 
1200 New Jersey Avenue SE, West Building, Ground Floor, Room W12-140, 
Washington, DC 20590-0001.
    Hand Delivery: U.S. Department of Transportation Docket Management 
System, West Building Ground Floor, Room W12-140, 1200 New Jersey 
Avenue SE, Washington, DC 20590-0001, between 9:00 a.m. and 5:00 p.m., 
ET, Monday through Friday, except federal holidays.
    Instructions: Please include the docket number, PHMSA-2022-0085, at 
the beginning of your comments. If you submit your comments by mail, 
submit two copies. If you wish to receive confirmation that PHMSA has 
received your comments, include a self-addressed stamped postcard with 
the following statement: ``Comments on: PHMSA-2022-0085.'' The Docket 
Clerk will date stamp the postcard prior to returning it to you via the 
U.S. mail. Internet users may submit comments at https://www.regulations.gov. Please note that, due to delays in the delivery of 
U.S. mail to federal offices in Washington, DC, we recommend submitting 
comments to the docket via the internet, fax, or professional courier 
to ensure their timely receipt at the DOT.

    Note:  Comments are posted without changes or edits to https://www.regulations.gov, including any personal information provided. 
There is also a privacy statement published on https://www.regulations.gov, which is also provided below.

    Privacy Act Statement: In accordance with 5 U.S.C. 553(c), DOT 
solicits comments from the public for certain notices. DOT posts these 
comments, without edit, including any personal information the 
commenter provides, to https://www.regulations.gov, as described in the 
system of records notice (DOT/ALL-14 FDMS), which can be reviewed at 
www.dot.gov/privacy.
    Docket: For access to the docket or to read background documents or 
comments received, go to https://www.regulations.gov and follow the 
online instructions for accessing the docket. Alternatively, you may 
review the documents in person at the physical address listed above for 
mail and hand delivery.
    Confidential Business Information: Confidential Business 
Information (CBI) is commercial or financial information that is both 
customarily and actually treated as private by its owner. Under the 
Freedom of Information Act (FOIA; 5 U.S.C. 552), CBI is exempt from 
public disclosure. If your comments responsive to this notice contain 
commercial or financial information that is customarily treated as 
private, that you actually treat as private, and that is relevant or 
responsive to this notice, it is important that you clearly designate 
the submitted comments as CBI. Pursuant to 49 CFR 190.343, you may ask 
PHMSA to give confidential treatment to information you give to the 
Agency by taking the following steps: (1) mark each page of the 
original document submission containing CBI as ``Confidential;'' (2) 
send PHMSA a second copy of the original document with the CBI deleted, 
along with the original document; and (3) explain why the information 
you are submitting is CBI. Unless you are notified otherwise, PHMSA 
will treat such marked submissions as confidential under FOIA, and they 
will not be placed in the public docket of this notice. Submissions 
containing CBI should be sent to Angela Hill, U.S. Department of 
Transportation, Pipeline and Hazardous Materials Safety Administration, 
1200 New Jersey Avenue SE, PHP-30, Washington, DC 20590-0001. Any 
commentary PHMSA receives that is not specifically designated as CBI 
will be placed in the public docket for this matter.

FOR FURTHER INFORMATION CONTACT: Angela Hill by phone at 202-366-1246 
or by email at [email protected].

SUPPLEMENTARY INFORMATION:

I. Background

A. Mitigation of Ruptures on Onshore Gas Transmission and Gathering, 
Hazardous Liquid, and Carbon Dioxide Pipeline Segments Using Rupture-
Mitigation Valves or Alternative Equivalent Technologies

    On September 9, 2010, at about 6:11 p.m. PT, a 30-inch diameter 
segment of an intrastate natural gas transmission pipeline known as 
Line 132, owned and operated by the Pacific Gas and Electric Company 
(PG&E), ruptured in a residential area in San Bruno, California. PG&E's 
dispatch center first received notification of an explosion at 6:18 
p.m. by an off-duty employee. Additional notifications were received in 
the next several minutes from other employees observing the accident 
fire or observing pressure drops in PG&E's supervisory control and data 
acquisition (SCADA) center. Shortly after 6:50 p.m., while processing 
available information about the ongoing event, PG&E personnel 
recognized the rupture was occurring on Line 132. PG&E subsequently 
began isolating the pipeline segment affected by the rupture by closing 
remotely operated valves at 7:29 p.m., and technicians manually closed 
two additional valves at 7:30 p.m. and 7:46 p.m., respectively, fully 
isolating the affected segment. It took a total of 95 minutes from the 
start of the rupture for PG&E to stop the flow of gas in the affected 
segment and isolate the

[[Page 20752]]

rupture site, and 91 minutes from the start of the rupture for the 
intensity of the fire to decrease enough so that firefighters could 
approach the rupture site and begin containment efforts.
    In its investigation report on the incident,\1\ the NTSB concluded 
the 95 minutes that PG&E took to stop the flow of gas by isolating the 
rupture site was excessive. If the gas had been shut off earlier, 
thereby removing fuel flow, the fire would likely have been smaller and 
resulted in less damage. Also, buildings that would have otherwise 
provided protection to residents in a shorter-duration fire were 
compromised because of the elevated heat. In addition to exposing 
residents and their property to increased risk, the prolonged fire was 
also detrimental to emergency responders, who were put at increased 
risk by having to be close to the fire for a longer time and were not 
available to respond to other potential emergencies while they were 
waiting for the fire to subside. This delay,--which contributed to the 
seriousness and extent of property damage and increased risk to 
residents and emergency responders,--in combination with the failure of 
the SCADA center to expedite shutdown of the remote valves, contributed 
to the severity of the incident.
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    \1\ NTSB, Accident Report PAR-11/01, ``Natural Gas Transmission 
Pipeline Rupture and Fire, San Bruno, California, September 9, 
2010'' (Aug. 30, 2011), https://www.ntsb.gov/investigations/AccidentReports/Reports/PAR1101.pdf.
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    On Sunday, July 25, 2010, a segment of a 30-inch-diameter pipeline, 
owned and operated by Enbridge Incorporated (Enbridge), ruptured in a 
wetland in Marshall, Michigan, releasing an estimated 843,444 gallons 
of crude oil. The NTSB also investigated that accident \2\ and 
identified similar rupture identification and response inadequacies as 
noted in its investigation of the PG&E incident at San Bruno.
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    \2\ NTSB, Accident Report PAR-12/01, ``Hazardous Liquid Pipeline 
Rupture and Release, Marshall, Michigan, July 25, 2010'' (Aug. 10, 
2012), https://www.ntsb.gov/investigations/AccidentReports/Reports/PAR1201.pdf.
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    Following these ruptures, the Pipeline Safety, Regulatory 
Certainty, and Job Creation Act of 2011 \3\ was enacted, containing 
several pipeline safety mandates related to the PG&E and Enbridge 
ruptures. In particular, the legislation required PHMSA to issue 
regulations requiring the use of automatic shut-off valves or remote-
control valves, or equivalent technology, on newly constructed or 
entirely replaced gas transmission and hazardous liquid pipeline 
facilities.\4\
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    \3\ 2011 Pipeline Safety Act; Public Law 112-90.
    \4\ 49 U.S.C. 60102(n). (This statutory mandate was subsequently 
revised, establishing a new deadline for PHMSA to issue a final 
rule. See 49 U.S.C. 60102 note.)
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    Following the PG&E incident, the NTSB recommended, in its 
Recommendation P-11-11, that PHMSA amend Sec.  192.935(c) to directly 
require that automatic shut-off valves or remote-control valves \5\ in 
high consequence areas and in class 3 and 4 locations be installed and 
spaced at intervals that consider the factors listed in that 
regulation. In response to that NTSB recommendation, and in 
consideration of other mandates, recommendations, and comments, PHMSA 
issued regulations in the final rule titled ``Requirement of Valve 
Installation and Minimum Rupture Detection Standards'' (Valve Rule).\6\
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    \5\ 49 CFR 192.3: 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.
    \6\ 87 FR 20940 (Apr. 8, 2022) (subsequently amended by 88 FR 
50056 (Aug. 1, 2023)). In developing the Valve Rule, PHMSA 
considered NTSB safety recommendations following the PG&E incident; 
GAO recommendations on the ability of operators to respond to 
commodity releases in high-consequence areas (HCA); technical 
reports commissioned by PHMSA on valves and leak detection; comments 
received on related topics through advance notices of proposed 
rulemakings (ANPRM) and the notice of proposed rulemaking (NPRM) 
published in February 2020; and feedback from members of the public, 
environmental advocacy organizations, state pipeline safety 
regulators, and industry representatives during Gas Pipeline 
Advisory Committee and Liquid Pipeline Advisory Committee meetings. 
See 87 FR 20941.
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    PHMSA collects information from pipeline operators on annual 
reports, which includes information such as total pipeline mileage, 
types of facilities, commodities transported, miles by material, and 
installation dates. These annual reports are widely used by safety 
researchers, government agencies, industry professionals, and PHMSA 
personnel for, among other things, inspection planning and future 
rulemaking. PHMSA's annual report forms do not currently collect 
information that could measure the effectiveness of the Valve Rule and 
provide the NTSB the necessary information as part of an alternative 
approach to close Recommendation P-11-11.
    Accordingly, PHMSA is proposing to collect data to determine the 
current utilization of RMVs and measure the usage of RMVs because of 
the requirements in the Valve Rule and industry safety initiatives. 
Specifically, PHMSA proposes to modify the annual report forms listed 
below for gas transmission, gas gathering, hazardous liquid, and carbon 
dioxide pipelines, and the associated instructions, to collect the 
number of miles of onshore gas transmission, gas gathering, hazardous 
liquid, and carbon dioxide pipelines that are located between RMVs or 
alternative equivalent technologies. This mileage would be further 
categorized by the pipeline outside diameter and location relative to 
HCAs and class locations, as applicable. PHMSA recognizes that the 
Valve Rule, through the subsequent amendments by 88 FR 50056, does not 
apply to gas gathering lines or hazardous liquid gathering lines, but 
is asking operators to report the miles of onshore Type A and Type C 
gas gathering lines and onshore hazardous liquid gathering lines 
(excluding regulated rural and reporting-regulated gathering lines) 
that would be within a shut-off segment, as defined by Sec. Sec.  
192.634 and 195.418, respectively, if those definitions applied. The 
forms PHMSA is proposing to modify include:

 Form PHMSA F 7100.2-1 Annual Report for Calendar Year 20_ 
Natural and Other Gas Transmission and Gathering Pipeline Systems
 Form PHMSA F 7000-1.1 Annual Report for Calendar Year 20_ 
Hazardous Liquid and Carbon Dioxide Pipeline Systems

    PHMSA will provide the collected information to the NTSB to 
illustrate the current utilization of RMVs; measure the implementation 
of the Valve Rule; and support closure of Recommendation P-11-11. PHMSA 
anticipates that the collection of this pipeline mileage information 
would also allow the Agency to identify the proactive approach taken by 
industry, in advance of the Valve Rule, to install RMVs and reduce the 
consequences of pipeline releases; measure, over time, the 
effectiveness of the Valve Rule; and identify trends related to 
pipeline mileage within shutoff segments to inform future rulemakings.

B. Blending Hydrogen Gas Into Natural Gas Pipelines

    Hydrogen gas and natural gas (and blends of the same) are, pursuant 
to Sec.  192.3, subject to PHMSA's part 192 regulations governing gas 
pipelines. Hydrogen gas is an energy carrier that could play an 
important role in reducing emissions associated with difficult-to-
decarbonize sectors, including peaking and load-following electricity 
and industrial heating. Blending hydrogen gas into natural gas 
pipelines has been proposed as an approach for achieving near-term

[[Page 20753]]

emissions reductions; however, numerous challenges and uncertainties 
complicate this approach to natural gas decarbonization.\7\ PHMSA is 
aware of proposed demonstration projects aimed to address technical 
barriers to blending hydrogen gas into natural gas pipelines.\8\ PHMSA 
is also aware of certain transmission and distribution pipeline 
operators who have historically transported blended natural gas and 
hydrogen gas product streams, and other operators who are beginning to 
consider the practice of blending natural gas with hydrogen gas in 
existing gas pipelines.9 10 11 PHMSA anticipates that 
natural gas and hydrogen gas blending could become a widespread, long-
term, and integral practice to meet energy and emissions reduction 
needs in the U.S. PHMSA recognizes that information gaps must be 
resolved to demonstrate the integrity of existing gas pipeline systems 
to transport blends of natural gas and hydrogen gas (even at lower 
concentrations of hydrogen gas within the blend). However, until 
further research is performed, PHMSA expects operators to take a 
measured and cautious approach, and to account for risks to pipeline 
integrity, public safety, and environmental protection in the 
performance of the requirements of part 192.
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    \7\ Topolski et al, ``Hydrogen Blending into Natural Gas 
Pipeline Infrastructure: Review of the State of Technology,'' 
National Renewable Energy Laboratory, (October 2022); NREL/TP5400-
81704. https://www.nrel.gov/docs/fy23osti/81704.pdf.
    \8\ U.S. Department of Energy, ``HyBlend: Opportunities for 
Hydrogen Blending in Natural Gas Pipelines,'' (December 2022). 
https://www.energy.gov/sites/default/files/2022-12/hyblend-tech-summary-120722.pdf.
    \9\ Congressional Research Service, ``Pipeline Transportation of 
Hydrogen: Regulation, Research, and Policy,'' (March 2, 2021). 
https://crsreports.congress.gov/product/pdf/R/R46700. More than a 
century ago, domestic pipelines commonly shipped hydrogen (blended 
with methane and other gases), but the advent of natural gas 
production from North American reserves in the 1940s generally ended 
this practice as the new natural gas supplies replaced hydrogen and 
hydrogen blends. Today, nearly all U.S. pipeline shipment of 
hydrogen is in dedicated hydrogen infrastructure, although there are 
proposals to ship hydrogen-methane blends once again in U.S. natural 
gas pipelines as one aspect of a national energy strategy.
    \10\ Southern California Gas Company, San Diego Gas & Electric 
Company, Pacific Gas and Electric Company, and Southwest Gas 
Corporation, Joint Application Regarding Hydrogen-Related Additions 
or Revisions to the Standard Renewable Gas Interconnection Tariff, 
Before the Public Utilities Commission of the State of California, 
November 20, 2020, https://www.socalgas.com/sites/default/files/2020-11/Utilities_Joint_Application_Prelim_H2_Injection_Standard_11-20-20.pdf.
    \11\ Clean Energy Group, ``Hydrogen Projects in the US,'' (Last 
accessed February 15, 2024). https://www.cleanegroup.org/initiatives/hydrogen/projects-in-the-us/.
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    PHMSA collects construction, operation, and incident data for 
pipelines transporting hydrogen gas and natural gas separately in its 
operator identification (OPID) assignment request, national registry 
notification, and annual and incident reports.\12\ These reports do not 
currently include a commodity selection for natural gas and hydrogen 
gas blends.
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    \12\ Operator Identification Number. (See Sec.  191.22)
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    PHMSA proposes to modify the forms listed below, and the associated 
instructions, to allow operators of gas pipelines transporting blended 
natural gas and hydrogen gas to select one of three new commodity 
values corresponding to various percentages of hydrogen gas by volume. 
PHMSA proposes adding three commodity values with the following 
percentage ranges of hydrogen: (1) greater than zero percent but less 
than or equal to five percent; (2) greater than five percent but less 
than 20 percent; and (3) greater than or equal to 20 percent.\13\ The 
forms that PHMSA is proposing to modify include:
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    \13\ Zhongquan Zhou and Daniel Ersoy, ``Review Studies of 
Hydrogen Use in Natural Gas Distribution Systems,'' Gas Technology 
Institute, prepared for National Renewable Energy Laboratory, 
(December 16, 2010), p. 15. (``If less than 20% hydrogen is 
introduced into distribution system, the overall risk is not 
significant.'')

 Form PHMSA F 1000.1 OPID Assignment Request
 Form PHMSA F 1000.2 National Registry Notification
 Form PHMSA F 7100.1-1 Annual Report for Calendar Year 20_ Gas 
Distribution System
 Form PHMSA F 7100.2-1 Annual Report for Calendar Year 20_ 
Natural and Other Gas Transmission and Gathering Pipeline Systems
 Form PHMSA F 7100.1 Incident Report--Gas Distribution System
 Form PHMSA F 7100.2 Incident Report--Gas Transmission, Gas 
Gathering, and Underground Natural Gas Storage Facilities

    PHMSA anticipates that the collection of these additional 
commodities and the resulting separation of associated construction, 
operation, and incident data will allow the Agency to identify trends 
relating to the transportation of natural gas and hydrogen gas blends 
in gas pipelines to inform future rulemakings. As discussed in Section 
II below, PHMSA expects that operators who decide to transport blended 
natural gas and hydrogen gas in only part of their system would see 
incremental cost increases in the form of additional annual reporting 
requirements. PHMSA expects no additional annual reporting burden for 
operators who decide to transport blended natural gas and hydrogen gas 
in their entire system. PHMSA also expects no additional burden for 
national registry notifications and incident reports.
    As part of this information collection, PHMSA would amend the 
National Pipeline Mapping System (NPMS) to include gas transmission 
commodity selections corresponding to natural gas and hydrogen gas 
blends with no additional burden.

II. Summary of Impacted Collection

    Code of Federal Regulations Title 5, Section 1320.8(d), requires 
PHMSA to provide interested members of the public and affected entities 
an opportunity to comment on information collection and recordkeeping 
requests. This notice identifies recurring annual information 
collections that PHMSA will submit to OMB for approval.
    The following information is provided for these information 
collections: (1) Title of the information collection; (2) OMB control 
number; (3) Current expiration date; (4) Type of request; (5) Abstract 
of the information collection activity; (6) Description of affected 
public; (7) Estimate of total annual reporting and recordkeeping 
burden; and (8) Frequency of collection.
    PHMSA requests comments on the following information:
    1. Title: National Registry of Pipeline and LNG Operators.
    OMB Control Number: 2137-0627.
    Current Expiration Date: 3/31/2025.
    Type of Request: Revision of information collection.
    Abstract: The National Registry of Pipeline and LNG Operators 
serves as the storehouse for the reporting requirements for an operator 
regulated or subject to reporting requirements under 49 CFR parts 192, 
193, or 195. This mandatory information collection requires 
jurisdictional pipeline operators to submit required data to the 
National Registry of Pipeline and LNG Operators and notify PHMSA when 
they experience significant asset changes, including new construction, 
that affect PHMSA's ability to accurately monitor and assess pipeline 
safety performance. Certain types of changes to, or within, an 
operator's facilities or pipeline network represent potential safety-
altering activities for which PHMSA may need to inspect, investigate, 
or otherwise oversee to ensure that any public safety concerns are 
adequately and proactively addressed. The forms for assigning and 
maintaining information are the OPID Assignment Request Form (PHMSA F 
1000.1) and National Registry Notification Form (PHMSA F 1000.2).\14\ 
The purpose of

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this information collection is to maintain an accurate assessment of 
the nation's pipeline infrastructure, and to keep abreast of conditions 
that could potentially compromise the safety and economic viability of 
the U.S. pipeline system. PHMSA proposes to revise forms PHMSA F 1000.1 
and PHMSA F 1000.2 to allow operators to select, as a commodity, a 
natural gas and hydrogen gas blend. PHMSA does not expect the burden on 
operators to increase because of this change.
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    \14\ Operator Identification Number. (See Sec.  191.22.)
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    Affected Public: Pipeline Operators.
    Annual Reporting and Recordkeeping Burden:
    Total Annual Responses: 744.
    Total Annual Burden Hours: 744.
    Frequency of Collection: On Occasion.
    2. Title: Incident Reports for Natural Gas Pipeline Operators.
    OMB Control Number: 2137-0635.
    Current Expiration Date: 10/31/2024.
    Type of Request: Revision of an information collection.
    Abstract: Operators of natural gas pipelines and liquefied natural 
gas (LNG) facilities are required to report incidents, on occasion, to 
PHMSA per the requirements in 49 CFR part 191. This mandatory 
information collection covers the collection of incident report data 
from natural and other gas pipeline operators. This information is an 
essential part of PHMSA's overall effort to minimize natural gas 
transmission, gathering, and distribution pipeline failures. The 
reports contained within this information collection support the DOT's 
strategic goal of safety. PHMSA proposes to revise forms PHMSA F 7100.1 
and PHMSA F 7100.2 to collect information on the percentage of hydrogen 
gas by volume released during a reportable incident from a gas pipeline 
transporting blended natural gas and hydrogen gas. PHMSA does not 
expect the burden on operators for incident reporting to increase 
because of this change.
    Affected Public: Natural and Other Gas Pipeline Operators.
    Annual Reporting and Recordkeeping Burden:
    Total Annual Responses: 999.
    Total Annual Burden Hours: 4,456.
    Frequency of Collection: On Occasion.
    3. Title: Annual Report for Gas Distribution Operators.
    OMB Control Number: 2137-0629.
    Current Expiration Date: 5/31/2024.
    Type of Request: Revision of an information collection.
    Abstract: This mandatory information collection covers the 
collection of annual report data from gas distribution pipeline 
operators. Operators of gas distribution pipeline systems are required 
to submit annual report data to the Office of Pipeline Safety in 
accordance with the regulations stipulated in 49 CFR part 191 by way of 
form PHMSA F 7100.1-1. The form is to be submitted once for each 
calendar year. The annual report form collects data about the pipe 
material, size, and age. The form also collects data on leaks from 
these systems as well as excavation damages. PHMSA uses the information 
to track the extent of gas distribution systems and normalize incident 
and leak rates. PHMSA proposes to revise form PHMSA F 7100.1-1 to 
collect information on the percentage of hydrogen gas by volume 
transported in a blend of natural gas and hydrogen gas. PHMSA currently 
estimates that gas distribution operators spend 20 hours annually 
compiling and submitting annual report data. PHMSA considers hydrogen 
blended gas a separate commodity and, as a result, may require gas 
distribution operators to submit a separate annual report should they 
decide to distribute blended natural gas and hydrogen gas only in a 
portion of their system. This would result in additional reporting 
burdens for those operators. PHMSA is not aware of any comprehensive 
data currently available that would allow the Agency to quantify the 
number of gas distribution pipeline operators that might distribute 
blended natural gas and hydrogen gas. PHMSA conservatively estimates 
that 13 gas distribution pipeline operators would be required to submit 
an additional annual report for each calendar year affected by this 
notice. Accordingly, PHMSA expects the burden on gas distribution 
pipeline operators to submit annual report data to increase by 13 
responses and 260 hours because of this change.
    Affected Public: Gas Distribution Pipeline Operators.
    Annual Reporting and Recordkeeping Burden:
    Total Annual Responses: 1,459.
    Total Annual Burden Hours: 29,180.
    Frequency of Collection: Annual.
    4. Title: Annual Reports for Gas Pipeline Operators.
    OMB Control Number: 2137-0522.
    Current Expiration Date: 3/31/2026.
    Type of Request: Revision of an information collection.
    Abstract: This mandatory information collection covers the 
collection of annual and incident report data from gas pipeline 
operators. PHMSA currently estimates that 1,810 natural and other gas 
pipeline operators spend an average of 54 hours submitting annual 
report data to PHMSA each year. PHMSA is proposing to revise form PHMSA 
F 7100.2-1 to collect data on how many miles of pipeline segments have 
RMVs or alternative equivalent technology to mitigate the consequences 
of a potential rupture. PHMSA believes that operators currently have 
this information available within their integrity management plans but 
acknowledges it may take operators some time to compile the data needed 
to comply with this information collection request. As such, PHMSA 
proposes to add one hour to the approved burden for form PHMSA F 
7100.2-1 to account for the proposed changes related to rupture 
mitigation valves. This will bring the burden for completing the annual 
report up to 55 hours per operator.
    PHMSA also proposes to revise form PHMSA F 7100.2-1 to collect 
information on the percentage of hydrogen gas by volume transported in 
a blend of natural gas and hydrogen gas. PHMSA expects that the burden 
on operators for reporting blended natural gas and hydrogen gas would 
result in incremental cost increases for operators who decide to 
transport blended natural gas and hydrogen gas in the form of an 
additional annual report for the operators engaging in such 
transportation. PHMSA is not aware of comprehensive data that is 
currently available and would allow the Agency to quantify the number 
of pipeline operators who might transport blended natural gas and 
hydrogen gas. PHMSA conservatively estimates that seven gas pipeline 
operators would be required to submit an additional annual report for 
each calendar year affected by this notice. Accordingly, PHMSA expects 
the burden on operators to submit annual report data to increase by 
seven responses and 385 hours because of this change.
    Affected Public: Natural and Other Gas Pipeline Operators.
    Annual Reporting and Recordkeeping Burden:
    Total Annual Responses: 2,452.
    Total Annual Burden Hours: 106,791.
    Frequency of Collection: Annual.
    5. Title: Hazardous Liquid Pipeline Operator Annual Reports.
    OMB Control Number: 2137-0614.
    Current Expiration Date: 03/31/2026.
    Type of Request: Revision of an information collection.
    Abstract: Owners and operators of hazardous liquid pipelines are 
required to provide PHMSA with safety-related documentation relative to 
the annual operation of their pipeline. PHMSA uses the provided 
information to compile a national pipeline inventory, identify safety 
problems, and target inspections. PHMSA currently estimates that 475 
operators of hazardous liquid and/or carbon dioxide pipeline systems 
spend an average of 26 hours annually

[[Page 20755]]

submitting annual report data to PHMSA via form PHMSA F7000-1.1, the 
Annual Report for Hazardous Liquid and Carbon Dioxide Pipeline Systems. 
PHMSA is proposing to revise form PHMSA F7000-1.1. to collect data on 
how many miles of pipeline segments have RMVs or alternative equivalent 
technology to mitigate the consequences of a potential rupture. PHMSA 
believes that operators currently have this information available 
within their integrity management plans but acknowledges it may take 
operators some time to compile the data needed to comply with this 
information collection request.
    As such, PHMSA proposes to add one hour to the approved burden for 
form PHMSA F7000-1.1 to account for the proposed changes. This will 
bring the total burden for completing the annual report to 27 hours per 
operator for an overall burden of 12,825 hours across all hazardous 
liquid and carbon dioxide pipeline operators.
    Affected Public: Owners and operators of hazardous liquid and 
carbon dioxide pipelines.
    Annual Reporting and Recordkeeping Burden:
    Total Annual Responses: 950.
    Total Annual Burden Hours: 12,825.
    Frequency of Collection: Annual.
    6. Title: National Pipeline Mapping Program.
    OMB Control Number: 2137-0596.
    Current Expiration Date: 03/31/2026.
    Type of Request: Revision of an information collection.
    Abstract: The Pipeline Safety Improvement Act of 2002 (Pub. L. 107-
355), 49 U.S.C. 60132, ``National Pipeline Mapping System,'' requires 
operators to submit geospatial data appropriate for use in the National 
Pipeline Mapping System 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. PHMSA proposes 
to amend the NPMS to include gas transmission commodity selections for 
natural gas and hydrogen gas blends. PHMSA estimates that no additional 
burden will be incurred by operators as a result of this change.
    Affected Public: Owners and operators of gas transmission pipelines 
and hazardous liquid and carbon dioxide pipelines.
    Annual Reporting and Recordkeeping Burden:
    Total Annual Responses: 1,346.
    Total Annual Burden Hours: 162,208.
    Frequency of Collection: Annual.
    Comments are invited on:
    (a) The need for this information collection for the proper 
performance of the functions of the Agency, including whether the 
information will have practical utility.
    (b) The accuracy of the Agency's estimate of the burden of the 
proposed collection of information, including the validity of the 
methodology and assumptions used.
    (c) Ways to enhance the quality, utility, and clarity of the 
information to be collected.
    (d) Ways to minimize the burden of the collection of information on 
those who are to respond, including the use of appropriate automated, 
electronic, mechanical, or other technological collection techniques.
    (e) Additional information that would be appropriate to collect to 
inform the reduction of risk to people, property, and the environment 
due to excavation damages.
    Authority: The Paperwork Reduction Act of 1995; 44 U.S.C. Chapter 
35, as amended; and 49 CFR 1.48.

    Issued in Washington, DC, on March 19, 2024, under authority 
delegated in 49 CFR 1.97.
Alan K. Mayberry,
Associate Administrator for Pipeline Safety.
[FR Doc. 2024-06155 Filed 3-22-24; 8:45 am]
BILLING CODE 4910-60-P