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, 20751-20755 [2024-06155]
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Federal Register / Vol. 89, No. 58 / Monday, March 25, 2024 / Notices
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
Pipeline and Hazardous
Materials Safety Administration
(PHMSA), Department of Transportation
(DOT).
ACTION: Notice and request for
comments.
AGENCY:
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.
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SUMMARY:
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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 selfaddressed 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
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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 Angela.Hill@dot.gov.
SUPPLEMENTARY INFORMATION:
I. Background
A. Mitigation of Ruptures on Onshore
Gas Transmission and Gathering,
Hazardous Liquid, and Carbon Dioxide
Pipeline Segments Using RuptureMitigation 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
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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 shorterduration 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.
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.
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 remotecontrol valves, or equivalent technology,
on newly constructed or entirely
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.
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.
3 2011 Pipeline Safety Act; Public Law 112–90.
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replaced gas transmission and
hazardous liquid pipeline facilities.4
Following the PG&E incident, the
NTSB recommended, in its
Recommendation P–11–11, that PHMSA
amend § 192.935(c) to directly require
that automatic shut-off valves or remotecontrol 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
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
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.)
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 highconsequence 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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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 §§ 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 20l Natural
and Other Gas Transmission and
Gathering Pipeline Systems
• Form PHMSA F 7000–1.1 Annual
Report for Calendar Year 20l
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
§ 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
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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.
PHMSA collects construction,
operation, and incident data for
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/projectsin-the-us/.
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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.
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:
• 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 20l Gas
Distribution System
• Form PHMSA F 7100.2–1 Annual
Report for Calendar Year 20l 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
12 Operator
Identification Number. (See § 191.22)
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.’’)
13 Zhongquan
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20753
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 safetyaltering 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
14 Operator
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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.
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
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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
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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
E:\FR\FM\25MRN1.SGM
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Federal Register / Vol. 89, No. 58 / Monday, March 25, 2024 / Notices
khammond on DSKJM1Z7X2PROD with NOTICES
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
VerDate Sep<11>2014
18:08 Mar 22, 2024
Jkt 262001
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.
20755
DEPARTMENT OF THE TREASURY
Office of Foreign Assets Control
Notice of OFAC Sanctions Actions
Office of Foreign Assets
Control, Treasury.
AGENCY:
ACTION:
Notice.
The U.S. Department of the
Treasury’s Office of Foreign Assets
Control (OFAC) is publishing the names
of one or more persons that have been
placed on OFAC’s List of Specially
Designated Nationals and Blocked
Persons (SDN List) based on OFAC’s
determination that one or more
applicable legal criteria were satisfied.
All property and interests in property
subject to U.S. jurisdiction of these
persons are blocked, and U.S. persons
are generally prohibited from engaging
in transactions with them.
SUMMARY:
See SUPPLEMENTARY INFORMATION
section for applicable date(s).
DATES:
FOR FURTHER INFORMATION CONTACT:
OFAC: Bradley T. Smith, Director, tel.:
202–622–2490; Associate Director for
Global Targeting, tel.: 202–622–2420;
Assistant Director for Licensing, tel.:
202–622–2480; Assistant Director for
Regulatory Affairs, tel.: 202–622–4855;
or the Assistant Director for Sanctions
Compliance & Evaluation, tel.: 202–622–
2490.
SUPPLEMENTARY INFORMATION:
Electronic Availability
The SDN List and additional
information concerning OFAC sanctions
programs are available on OFAC’s
website (https://www.treasury.gov/ofac).
Notice of OFAC Actions
[FR Doc. 2024–06155 Filed 3–22–24; 8:45 am]
On March 20, 2024, OFAC
determined that the property and
interests in property subject to U.S.
jurisdiction of the following persons are
blocked under the relevant sanctions
authority listed below.
BILLING CODE 4910–60–P
BILLING CODE 4810–AL–P
PO 00000
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]]>Agencies
[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.
-----------------------------------------------------------------------
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.
---------------------------------------------------------------------------
\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.
---------------------------------------------------------------------------
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.
---------------------------------------------------------------------------
\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.)
---------------------------------------------------------------------------
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\
---------------------------------------------------------------------------
\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.
---------------------------------------------------------------------------
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.
---------------------------------------------------------------------------
\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.
---------------------------------------------------------------------------
\12\ Operator Identification Number. (See Sec. 191.22)
---------------------------------------------------------------------------
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:
---------------------------------------------------------------------------
\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
[[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.
---------------------------------------------------------------------------
\14\ Operator Identification Number. (See Sec. 191.22.)
---------------------------------------------------------------------------
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
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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
