Notice2024-06155
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
Primary source
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Published
March 25, 2024
Issuing agencies
Transportation DepartmentPipeline and Hazardous Materials Safety Administration
Abstract
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.
Full Text
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<title>Federal Register, Volume 89 Issue 58 (Monday, March 25, 2024)</title>
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[Federal Register Volume 89, Number 58 (Monday, March 25, 2024)]
[Notices]
[Pages 20751-20755]
From the Federal Register Online via the Government Publishing Office [<a href="http://www.gpo.gov">www.gpo.gov</a>]
[FR Doc No: 2024-06155]
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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: <a href="https://www.regulations.gov">https://www.regulations.gov</a>. 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 <a href="https://www.regulations.gov">https://www.regulations.gov</a>. 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 <a href="https://www.regulations.gov">https://www.regulations.gov</a>, including any personal information provided.
There is also a privacy statement published on <a href="https://www.regulations.gov">https://www.regulations.gov</a>, 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 <a href="https://www.regulations.gov">https://www.regulations.gov</a>, as described in the
system of records notice (DOT/ALL-14 FDMS), which can be reviewed at
<a href="http://www.dot.gov/privacy">www.dot.gov/privacy</a>.
Docket: For access to the docket or to read background documents or
comments received, go to <a href="https://www.regulations.gov">https://www.regulations.gov</a> 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 <a href="/cdn-cgi/l/email-protection#abeac5cccec7ca85e3c2c7c7ebcfc4df85ccc4dd"><span class="__cf_email__" data-cfemail="aaebc4cdcfc6cb84e2c3c6c6eacec5de84cdc5dc">[email protected]</span></a>.
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), <a href="https://www.ntsb.gov/investigations/AccidentReports/Reports/PAR1101.pdf">https://www.ntsb.gov/investigations/AccidentReports/Reports/PAR1101.pdf</a>.
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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), <a href="https://www.ntsb.gov/investigations/AccidentReports/Reports/PAR1201.pdf">https://www.ntsb.gov/investigations/AccidentReports/Reports/PAR1201.pdf</a>.
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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:
<bullet> Form PHMSA F 7100.2-1 Annual Report for Calendar Year 20_
Natural and Other Gas Transmission and Gathering Pipeline Systems
<bullet> 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.<SUP>9 10 11</SUP> 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. <a href="https://www.nrel.gov/docs/fy23osti/81704.pdf">https://www.nrel.gov/docs/fy23osti/81704.pdf</a>.
\8\ U.S. Department of Energy, ``HyBlend: Opportunities for
Hydrogen Blending in Natural Gas Pipelines,'' (December 2022).
<a href="https://www.energy.gov/sites/default/files/2022-12/hyblend-tech-summary-120722.pdf">https://www.energy.gov/sites/default/files/2022-12/hyblend-tech-summary-120722.pdf</a>.
\9\ Congressional Research Service, ``Pipeline Transportation of
Hydrogen: Regulation, Research, and Policy,'' (March 2, 2021).
<a href="https://crsreports.congress.gov/product/pdf/R/R46700">https://crsreports.congress.gov/product/pdf/R/R46700</a>. 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, <a href="https://www.socalgas.com/sites/default/files/2020-11/Utilities_Joint_Application_Prelim_H2_Injection_Standard_11-20-20.pdf">https://www.socalgas.com/sites/default/files/2020-11/Utilities_Joint_Application_Prelim_H2_Injection_Standard_11-20-20.pdf</a>.
\11\ Clean Energy Group, ``Hydrogen Projects in the US,'' (Last
accessed February 15, 2024). <a href="https://www.cleanegroup.org/initiatives/hydrogen/projects-in-the-us/">https://www.cleanegroup.org/initiatives/hydrogen/projects-in-the-us/</a>.
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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.'')
<bullet> Form PHMSA F 1000.1 OPID Assignment Request
<bullet> Form PHMSA F 1000.2 National Registry Notification
<bullet> Form PHMSA F 7100.1-1 Annual Report for Calendar Year 20_ Gas
Distribution System
<bullet> Form PHMSA F 7100.2-1 Annual Report for Calendar Year 20_
Natural and Other Gas Transmission and Gathering Pipeline Systems
<bullet> Form PHMSA F 7100.1 Incident Report--Gas Distribution System
<bullet> 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
[[Page 20754]]
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
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</html>Indexed from Federal Register on March 25, 2024.
This is legal information, not legal advice. Laws vary by jurisdiction and change frequently. Always verify current law with official sources and consult a licensed attorney in your jurisdiction for advice on your specific situation.