PURPOSE: This amendment modifies the rule to address
amendments of 49 CFR part 191 promulgated between January 2021 and December
2021, modifies the notification criteria for Missouri incidents, and makes
clarification and editorial changes.
(1) Scope. (191.1)
(A) This rule prescribes requirements for the
reporting of incidents, safety-related conditions, annual pipeline summary
data, National Operator Registry information, and other miscellaneous
conditions by operators of gas pipeline facilities and underground natural gas
storage facilities located in Missouri and under the jurisdiction of the
commission. This rule applies to onshore gathering lines, including Type R
gathering lines as determined in
20 CSR
4240-40.030(1)(E). (192.8)
(B) Subsections (11)(B) and (11)(C) and
section (12) do not apply to the onshore gathering of gas-
1. Through a pipeline that operates at less
than zero (0) pound per square inch gauge (psig) (0 kPa); or
2. Through a pipeline that is not a regulated
onshore gathering line.
(2) Definitions. (191.3) As used in this rule
and in the PHMSA Forms referenced in this rule-
(A) Administrator means the administrator of
PHMSA or his or her delegate;
(B)
Commission means the Public Service Commission. Designated commission personnel
means the Pipeline Safety Program Manager at the address contained in
subsection (5)(E) for correspondence and means the list of staff personnel
supplied to operators for telephonic notices;
(C) Confirmed discovery means when it can be
reasonably determined, based on information available to the operator at the
time a reportable event has occurred, even if only based on a preliminary
evaluation;
(D) Federal incident
means any of the following events:
1. An event
that involves a release of gas from a pipeline, gas from an underground natural
gas storage facility (UNGSF), liquefied natural gas (LNG), liquefied petroleum
gas, refrigerant gas, or gas from an LNG facility, and that results in one (1)
or more of the following consequences:
A. A
death or personal injury necessitating inpatient hospitalization; or
B. Estimated property damage of one hundred
twenty-two thousand dollars ($122,000) or more, including loss to the operator
and others, or both, but excluding the cost of gas lost. For adjustments for
inflation observed in calendar year 2021 onwards, changes to the reporting
threshold will be posted on PHMSA's website. These changes will be determined
in accordance with appendix A to 49 CFR part
191; or
C. Unintentional estimated gas loss of three
(3) million cubic feet or more;
2. An event that results in an emergency
shutdown of an LNG facility or an UNGSF. Activation of an emergency shutdown
system for reasons other than an actual emergency does not constitute an
incident; or
3. An event that is
significant, in the judgment of the operator, even though it did not meet the
criteria of paragraphs (2)(D)1. or (2)(D)2.
(E) Gas means natural gas, flammable gas,
manufactured gas, or gas which is toxic or corrosive;
(F) LNG facility means a pipeline facility
that is used for liquefying natural gas or synthetic gas or transferring,
storing, or vaporizing liquefied natural gas;
(G) LNG plant means an LNG facility or system
of LNG facilities functioning as a unit;
(H) Master meter system means a pipeline
system for distributing gas within, but not limited to, a definable area, such
as a mobile home park, housing project, or apartment complex, where the
operator purchases metered gas from an outside source for resale through a gas
distribution pipeline system. The gas distribution pipeline system supplies the
ultimate consumer who either purchases the gas directly through a meter or by
other means, for instance, by rents;
(I) Municipality means a city, village, or
town;
(J) Operator means a person
who engages in the transportation of gas;
(K) Person means any individual, firm, joint
venture, partnership, corporation, association, county, state, municipality,
political subdivision, cooperative association, or joint stock association, and
includes any trustee, receiver, assignee, or personal representative of
them;
(L) Pipeline or pipeline
system means all parts of those physical facilities through which gas moves in
transportation including, but not limited to, pipe, valves, and other
appurtenances attached to pipe, compressor units, metering stations, regulator
stations, delivery stations, holders, and fabricated assemblies;
(M) PHMSA means the Pipeline and Hazardous
Materials Safety Administration of the United States Department of
Transportation;
(N) Regulated
onshore gathering means a Type A, Type B, or Type C gas gathering pipeline
system as determined in
20 CSR
4240-40.030(1)(E) (192.8);
(O) Reporting-regulated gathering means a
Type R gathering line as determined in
20 CSR
4240-40.030(1)(E). (192.8) A Type R
gathering line is subject only to this rule;
(P) Transportation of gas means the gathering,
transmission, or distribution of gas by pipeline, or the storage of gas, in or
affecting intrastate, interstate, or foreign commerce; and
(Q) Underground natural gas storage facility (UNGSF)
means a gas pipeline facility that stores natural gas in an underground
facility incidental to the transportation of natural gas, including-
1. A depleted hydrocarbon reservoir, an
aquifer reservoir, or a solution-mined cavern; and
2. In addition to the reservoir or cavern, a
UNGSF includes injection, withdrawal, monitoring, and observation wells;
wellbores and downhole components; wellheads and associated wellhead piping;
wing-valve assemblies that isolate the wellhead from connected piping beyond
the wing-valve assemblies; and any other equipment, facility, right-of-way, or
building used in the underground storage of natural gas.
(3) Immediate Notice of Federal
Incidents. (191.5)
(A) At the earliest
practicable moment following discovery, but no later than one (1) hour after
confirmed discovery, each operator shall give notice, in accordance with
subsection (3)(B), of each federal incident as defined in section (2)
(191.3).
(B) Each notice required
by subsection (3)(A) must be made to the National Response Center either by
telephone to (800) 424-8802 or electronically at
www.nrc.uscg.mil and must include
the following information:
1. Names of
operator and person making report and their telephone numbers;
2. Location of the incident;
3. Time of the incident;
4. Number of fatalities and personal
injuries, if any; and
5. All other
significant facts known by the operator that are relevant to the cause of the
incident or extent of the damages.
(C) Within forty-eight (48) hours after the
confirmed discovery of an incident, to the extent practicable, an operator must
revise or confirm its initial telephonic notice required in subsection (3)(B)
with an estimate of the amount of gas released, an estimate of the number of
fatalities and injuries, and all other significant facts that are known by the
operator that are relevant to the cause of the incident or extent of the
damages. If there are no changes or revisions to the initial report, the
operator must confirm the estimates in its initial report.
(4) Immediate Notice of Missouri Incidents.
(A) Within two (2) hours following discovery
by the operator, or as soon thereafter as practicable if emergency efforts to
protect life and property would be hindered, each gas operator must notify
designated
commission personnel by telephone of the following events within
areas served by the operator:
1. An event that
involves a release of gas involving the operator's actions or pipeline system,
or where there is a suspicion by the operator that the event may involve a
release of gas involving the operator's actions or pipeline system, and results
in one (1) or more of the following consequences:
A. A death;
B. A personal injury involving medical care
administered in an emergency room or health care facility, whether inpatient or
outpatient, beyond initial treatment and prompt release after evaluation by a
health care professional; or
C.
Estimated property damage of seventeen thousand five hundred dollars ($17,500)
or more, including loss to the gas operator or others, or both, and including
the cost of gas lost;
2.
An event that is significant, in the judgement of the operator, even though it
did not meet the criteria of paragraph (4)(A)1.; or
3. An event that is reported as a Federal
incident under section (3).
(5) Report Submission Requirements. (191.7)
(A) Reports to PHMSA.
1. An operator must submit each report
required by sections (6)-(11) electronically to the Pipeline and Hazardous
Materials Safety Administration at
http://portal.phmsa.dot.gov/pipeline
unless an alternative reporting method is authorized in accordance with
subsection (5)(D).
2. A copy of
each online submission to PHMSA must also be submitted concurrently to
designated commission personnel. The copy submitted to designated commission
personnel must be clearly marked to indicate the date of the online submission
to PHMSA.
(B) Missouri
incident reports.
1. This subsection applies
to events that meet the criteria in subsection (4)(A) but are not a federal
incident reported under subsection (5)(A). Within thirty (30) days of a
telephone notification made under subsection (4)(A), each gas operator must
submit the applicable U.S. Department of Transportation Form PHMSA F 7100.1,
PHMSA F 7100.2, or PHMSA F 7100.3 to designated commission personnel.
Additional information required in subsections (6)(B) and (9)(B) for federal
incidents is also required for these events.
2. The incident report forms for gas
distribution systems (PHMSA F 7100.1, revised May 2021), gas transmission and
gathering pipeline systems (PHMSA F 7100.2, revised January 2020), and LNG
facilities (PHMSA F 7100.3, revised April 2019) are incorporated by reference
in subsection (5)(G).
(C)
Safety-related Conditions. An operator must submit concurrently to PHMSA and
designated commission personnel a safety-related condition report required by
section (12) (191.23). A safety-related condition report can be submitted by
electronic mail or telefacsimile (fax) as provided for in section
(13).
(D) Alternative Reporting
Method.
1. If electronic reporting imposes an
undue burden and hardship, an operator may submit a written request for an
alternative reporting method to the Information Resources Manager, Office of
Pipeline Safety, Pipeline and Hazardous Materials Safety Administration,
PHP-10, 1200 New Jersey Avenue SE, Washington DC 20590-0001. The request must
describe the undue burden and hardship. PHMSA will review the request and may
authorize, in writing, an alternative reporting method. An authorization will
state the period for which it is valid, which may be indefinite. An operator
must contact PHMSA at (202) 366-8075, or electronically to
informationresourcesmanager@dot.gov or make arrangements for submitting a
report that is due after a request for alternative reporting is submitted, but
before an authorization or denial is received.
2. A copy of each report using an alternate
reporting method must also be submitted concurrently to designated commission
personnel. The copy submitted to designated commission personnel must be
clearly marked to indicate the date of submission to PHMSA.
(E) Address for Designated
Commission Personnel. The address for the designated commission personnel is
Pipeline Safety Program Manager, Missouri Public Service Commission, PO Box
360, Jefferson City, MO 65102. The email address for designated commission
personnel is PipelineSafetyPro-gramManager@psc.mo.gov.
(F) National Pipeline Mapping System (NPMS).
An operator must provide the NPMS data to the address identified in the NPMS
Operator Standards manual available at
http://www.npms.phmsa.dot.gov or by
contacting the PHMSA geographic information systems manager at (202)
366-4595.
(G) Forms incorporated by
reference.
1. The following forms are
incorporated by reference and made part of this rule.
A. U.S. Department of Transportation Form
PHMSA F 1000.1, revised January 2020. The PHMSA F 1000.1 form is the Operator
Identification (OPID) Assignment Request form and does not include any
amendments or additions to the January 2020 version.
B. U.S. Department of Transportation Form
PHMSA F 1000.2, revised January 2020. The PHMSA F 1000.2 form is the National
Registry Notification form for reporting changes including operator name
change, change in entity operating, shared safety program change, change in
ownership for gas facilities, construction or rehabilitation of gas facilities,
change in ownership for LNG, and construction for LNG. The PHMSA F 1000.2 form
does not include any amendments or additions to the January 2020
version.
C. U.S. Department of
Transportation Form PHMSA F 7100.1, revised May 2021. The PHMSA F 7100.1 form
is the incident report form for gas distribution systems and does not include
any amendments or additions to the May 2021 version.
D. U.S. Department of Transportation Form
PHMSA F 7100.1-1, revised May 2021. The PHMSA F 7100.1-1 form is the annual
report form for gas distribution systems and does not include any amendments or
additions to the May 2021 version.
E. Reserved.
F. U.S. Department of Transportation Form
PHMSA F 7100.2, revised January 2020. The PHMSA F 7100.2 form is the incident
report form for gas transmission and gathering pipeline systems and does not
include any amendments or additions to the January 2020 version.
G. U.S. Department of Transportation Form
PHMSA F 7100.2-1, revised October 2021. The PHMSA F 7100.2-1 form is the annual
report form for gas transmission and gathering pipeline systems and does not
include any amendments or additions to the October 2021 version.
H. U.S. Department of Transportation Form
PHMSA F 7100.3, revised April 2019. The PHMSA F 7100.3 form is the incident
report form for LNG facilities and does not include any amendments or additions
to the April 2019 version.
I. U.S.
Department of Transportation Form PHMSA F 7100.3-1, revised October 2014. The
PHMSA F 7100.3-1 form is the annual report form for LNG facilities and does not
include any amendments or additions to the October 2014 version.
J. U.S. Department of Transportation Form
PHMSA 7100.41, approved August 2017. The PHMSA F 7100.4-1 form is the annual
report form for underground natural gas storage facilities and does not include
any amendments or additions to the August 2017 version.
K. U.S. Department of Transportation Form
PHMSA 7100.2-2, approved March 2022. The PHMSA F 7100.2-2 form is the incident
report form for reporting-regulated gathering pipeline systems and does not
include any amendments or additions to the March 2022 version.
L. U.S. Department of Transportation Form
PHMSA 7100.2-3, approved March 2022. The PHMSA F 7100.2-3 form is the annual
report form for reporting-regulated gathering pipeline systems and does not
include any amendments or additions to the March 2022
version.
2. The forms
listed in paragraph (5)(D)1. are published by the U.S. Department of
Transportation Office of Pipeline Safety, PHP-10, 1200 New Jersey Avenue SE,
Washington, DC 20590-0001. The forms are available at
www.phmsa.dot.gov/forms/pipeline-forms
or upon request from the pipeline safety program manager at the address given
in subsection (5)(E).
(6) Distribution System-Federal Incident
Report. (191.9)
(A) Except as provided in
subsection (6)(C), each operator of a distribution pipeline system must submit
U.S. Department of Transportation Form PHMSA F 7100.1 as soon as practicable
but not more than thirty (30) days after detection of an incident required to
be reported under section (3) (191.5). See the report submission requirements
in subsection (5)(A). The incident report form (revised May 2021) is
incorporated by reference in subsection (5)(G).
(B) When additional relevant information is
obtained after the report is submitted under subsection (6)(A), the operator
shall make supplementary reports, as deemed necessary, with a clear reference
by date and subject to the original report.
(C) The incident report required by this
section need not be submitted with respect to master meter
systems.
(7) Distribution
System-Annual Report.
(A) Annual Report.
(191.11)
1. Except as provided in paragraph
(7)(A)3., each operator of a distribution pipeline system must submit an annual
report for that system on U.S. Department of Transportation Form PHMSA F
7100.1-1. This report must be submitted each year, not later than March 15, for
the preceding calendar year. See the report submission requirements in
subsection (5)(A).
2. The annual
report form (revised May 2021) is incorporated by reference in subsection
(5)(G).
3. The annual report
requirement in this subsection does not apply to a master meter system, a
petroleum gas system that serves fewer than one hundred (100) customers from a
single source, or an individual service line directly connected to a production
pipeline or a gathering line other than a regulated gathering line as
determined in
20 CSR
4240-40.030(1)(E).
(192.8)
(B)
Reserved.
(8)
Distribution Systems Reporting Transmission Pipelines-Transmission or Gathering
Systems Reporting Distribution Pipelines. (191.13) Each operator primarily
engaged in gas distribution who also operates gas transmission or gathering
pipelines shall submit separate reports for these pipelines as required by
sections (9) and (10) (191.15 and 191.17). Each operator primarily engaged in
gas transmission or gathering who also operates gas distribution pipelines
shall submit separate reports for these pipelines as required by sections (6)
and (7) (191.9 and 191.11).
(9)
Transmission Systems; Gathering Systems; Liquefied Natural Gas Facilities; and
Underground Natural Gas Storage Facilities-Federal Incident Report. (191.15)
(A) Transmission or gathering.
1. Each operator of a transmission or a
regulated onshore gathering pipeline system must submit U.S. Department of
Transportation Form PHMSA F 7100.2 as soon as practicable but not more than
thirty (30) days after detection of an incident required to be reported under
section (3). (191.5) See the report submission requirements in subsection
(5)(A). The incident report form (revised January 2020) is incorporated by
reference in subsection (5)(G).
2.
Each operator of a reporting-regulated gathering pipeline system must submit
U.S. Department of Transportation Form PHMSA F 7100.2-2 as soon as practicable
but not more than thirty (30) days after detection of an incident required to
be reported under section (3) (191.5) that occurs after May 16, 2022. See the
report submission requirements in subsection (5)(A). The incident report form
(revised March 2022) is incorporated by reference in subsection
(5)(G).
(B) LNG. Each
operator of a liquefied natural gas plant or facility must submit U.S.
Department of Transportation Form PHMSA F 7100.3 as soon as practicable but not
more than thirty (30) days after detection of an incident required to be
reported under section (3) (191.5). See the report submission requirements in
subsection (5)(A). The incident report form (revised April 2019) is
incorporated by reference in subsection (5)(G).
(C) Underground natural gas storage facility.
Each operator of an UNGSF must submit U.S. Department of Transportation Form
PHMSA F 7100.2 as soon as practicable but not more than thirty (30) days after
detection of an incident required to be reported under section (3). (191.5) See
the report submission requirements in subsection (5)(A). The incident report
form (revised January 2020) is incorporated by reference in subsection
(5)(G).
(D) Supplemental Report.
Where additional related information is obtained after an operator submits a
report under subsection (9)(A), (9)(B), or (9)(C), the operator must make a
supplemental report as soon as practicable with a clear reference by date to
the original report.
(10)
Transmission Systems; Gathering Systems; Liquefied Natural Gas Facilities; and
Underground Natural Gas Storage Facilities- Annual Report. (191.17)
(A) Transmission or gathering.
1. Each operator of a transmission or a
regulated onshore gathering pipeline system must submit an annual report for
that system on U.S. Department of Transportation Form PHMSA F 7100.2-1. This
report must be submitted each year, not later than March 15, for the preceding
calendar year. See the report submission requirements in subsection (5)(A). The
annual report form (revised October 2021) is incorporated by reference in
subsection (5)(G).
2. Type R
gathering. Beginning with an initial annual report submitted in March 2023 for
the 2022 calendar year, each operator of a reporting-regulated gas gathering
pipeline system must submit an annual report for that system on U.S. Department
of Transportation Form PHMSA F 7100.2-3. This report must be submitted each
year, not later than March 15, for the preceding calendar year. See the report
submission requirements in subsection (5)(A). The annual report form (revised
March 2022) is incorporated by reference in subsection (5)(G).
(B) LNG. Each operator of a
liquefied natural gas facility must submit an annual report for that system on
U.S. Department of Transportation Form PHMSA F 7100.3-1 This report must be
submitted each year, not later than March 15, for the preceding calendar year.
See the report submission requirements in subsection (5)(A). The annual report
form (revised October 2014) is incorporated by reference in subsection
(5)(G).
(C) Underground natural gas
storage facility. Each operator of an UNGSF must submit an annual report
through U.S. Department of Transportation Form PHMSA 7100.4-1. This report must
be submitted each year, no later than March 15, for the preceding calendar
year. See the report submission requirements in subsection (5)(A). The annual
report form (August 2017) is incorporated by reference in subsection
(5)(G).
(11) National
Registry of Pipeline and LNG Operators (191.22)
(A) OPID Request.
1. Effective January 1, 2012, each operator
of a gas pipeline, gas pipeline facility, UNGSF, LNG plant, or LNG facility
must obtain from PHMSA an Operator Identification Number (OPID). An OPID is
assigned to an operator for the pipeline, pipeline facility, or pipeline system
for which the operator has primary responsibility. To obtain an OPID, an
operator must complete an OPID Assignment Request (U.S. Department of
Transportation Form PHMSA F 1000.1) through the National Registry of Operators
at
https://portal.phmsa.dot.gov unless
an alternative reporting method is authorized in accordance with subsection
(5)(D). A copy of each submission to PHMSA must also be submitted concurrently
to designated
commission personnel-see addresses in subsection
(5)(E).
2. The OPID Assignment
Request form ( January 2020) is incorporated by reference in subsection
(5)(G).
(B) OPID
Validation. An operator who has already been assigned one (1) or more OPIDs by
January 1, 2011, must validate the information associated with each OPID
through the National Registry of Operators at
https://portal.phmsa.dot.gov,
and correct that information as necessary, no later than September 30, 2012
(PHMSA Advisory Bulletin ADB-2012-04 extended the deadline from June 30, 2012,
to September 30, 2012).
(C)
Changes. Each operator of a gas pipeline, gas pipeline facility, UNGSF, LNG
plant, or LNG facility must notify PHMSA electronically through the National
Registry of Operators at
https://portal.phmsa.dot.gov of
certain events. A copy of each online notification must also be submitted
concurrently to designated
commission personnel-see addresses in subsection
(5)(E).
1. An operator must notify PHMSA of
any of the following events not later than sixty (60) days before the event
occurs:
A. Construction or any planned
rehabilitation, replacement, modification, upgrade, uprate, or update of a
facility, other than a section of line pipe, that costs ten (10) million
dollars or more. If sixty- (60-) day notice is not feasible because of an
emergency, an operator must notify PHMSA as soon as practicable;
B. Construction of ten (10) or more miles of
a new pipeline;
C. Construction of
a new LNG plant, LNG facility, or UNGSF;
D. Maintenance of an UNGSF that involves the
plugging or abandonment of a well, or that requires a workover rig and costs
two hundred thousand dollars ($200,000) or more for an individual well,
including its wellhead. If sixty- (60-) day notice is not feasible due to an
emergency, an operator must promptly respond to the emergency and notify PHMSA
as soon as practicable;
E. Reversal
of product flow direction when the reversal is expected to last more than
thirty (30) days. This notification is not required for pipeline systems
already designed for bi-directional flow; or
F. A pipeline converted for service under
20 CSR
4240-40.030(1)(H) (192.14), or a
change in commodity as reported on the annual report as required by section
(10) (191.17).
2. An
operator must notify PHMSA of any of the following events not later than sixty
(60) days after the event occurs:
A. A change
in the primary entity responsible (i.e., with an assigned OPID) for managing or
administering a safety program required by this rule covering pipeline
facilities operated under multiple OPIDs;
B. A change in the name of the
operator;
C. A change in the entity
(e.g., company, municipality) responsible for an existing pipeline, pipeline
segment, pipeline facility, UNGSF, or LNG facility;
D. The acquisition or divestiture of fifty
(50) or more miles of a pipeline or pipeline system subject to
20 CSR
4240-40.030; or
E. The acquisition or divestiture of an
existing UNGSF, or an LNG plant, or LNG facility subject to 49 CFR Part
193
(D) Reporting.
An operator must use the OPID issued by PHMSA for all reporting requirements
covered under
20 CSR 4240-40.020, 40.030,
40.033, and 40.080, and for submissions to the National Pipeline Mapping
System.
(12) Reporting
Safety-Related Conditions. (191.23)
(A) Except
as provided in subsection (12)(B), each operator must report in accordance with
section (13) (191.25) the existence of any of the following safety-related
conditions involving facilities in service:
1.
In the case of the pipeline (other than an LNG facility) that operates at a
hoop stress of twenty percent (20%) or more of its specified minimum yield
strength, general corrosion that has reduced the wall thickness to less than
that required for the maximum allowable operating pressure and localized
corrosion pitting to a degree where leakage might result;
2. In the case of an UNGSF, general corrosion
that has reduced the wall thickness of any metal component to less than that
required for the well's maximum operating pressure, or localized corrosion
pitting to a degree where leakage might result;
3. Unintended movement or abnormal loading by
environmental causes, such as an earthquake, landslide or flood, that impairs
the serviceability of a pipeline or the structural integrity or reliability of
an UNGSF, or an LNG facility that contains, controls, or processes gas or
LNG;
4. Any crack or other material
defect that impairs the structural integrity or reliability of an UNGSF or an
LNG facility that contains, controls, or processes gas or LNG;
5. Any material defect or physical damage
that impairs the serviceability of a pipeline that operates at a hoop stress of
twenty percent (20%) or more of its specified minimum yield strength or an
UNGSF;
6. Any malfunction or
operating error that causes the pressure, plus the margin (build-up) allowed
for operation of pressure limiting or control devices, to exceed either the
maximum allowable operating pressure of a distribution or gathering line, the
maximum well allowable operating pressure of an UNGSF, or the maximum allowable
working pressure of an LNG facility that contains or processes gas or LNG;
7. A leak in a pipeline, UNGSF, or
LNG facility that contains or processes gas or LNG that constitutes an
emergency;
8. Inner tank leakage,
ineffective insulation, or frost heave that impairs the structural integrity of
an LNG storage tank;
9. Any
safety-related condition that could lead to an imminent hazard and causes
(either directly or indirectly by remedial action of the operator), for
purposes other than abandonment, a twenty percent (20%) or more reduction in
operating pressure or shutdown of operation of a pipeline, UNGSF, or an LNG
facility that contains or processes gas or LNG;
10. For transmission pipelines only, each
exceedance of the maximum allowable operating pressure that exceeds the margin
(build-up) allowed for operation of pressure-limiting or control devices as
specified in the applicable requirements of
20 CSR
4240-40.030(4)(FF) and (13)(R)
(192.201 and 192.739). The reporting requirement of this paragraph is not
applicable to gathering lines, distribution lines, LNG facilities, or
underground natural gas storage facilities (see paragraph (12)(A)6.);
and
11. Any malfunction or
operating error that causes the pressure of a UNGSF using a salt cavern for
natural gas storage to fall below its minimum allowable operating pressure, as
defined by the facility's State or Federal operating permit or certificate,
whichever pressure is higher.
(B) A report is not required for any
safety-related condition that-
1. Exists on a
master meter system, a reporting-regulated gathering pipeline, a Type C gas
gathering pipeline with an outside diameter of 12.75 inches or less, a Type C
gathering pipeline covered by the exception in
49 CFR
192.9(f)(1), or a
customer-owned service line;
2. Is
an incident or results in an incident before the deadline for filing the
safety-related condition report;
3.
Exists on a pipeline (other than an UNGSF or an LNG facility) that is more than
two hundred twenty (220) yards (two hundred (200) meters) from any building
intended for human occupancy or outdoor place of assembly, except that reports
are required for conditions within the right-of-way of an active railroad,
paved road, street, or highway;
4.
Exists on an UNGSF, where a well or wellhead is isolated, allowing the
reservoir or cavern and all other components of the facility to continue to
operate normally and without pressure restriction; or
5. Is corrected by repair or replacement in
accordance with applicable safety standards before the deadline for filing the
safety-related condition report. Notwithstanding this exception, a report must
be filed for-
A. Conditions under paragraph
(12)(A)1., unless the condition is localized corrosion pitting on an
effectively coated and cathodically protected pipeline; and
B. Any condition under paragraph
(12)(A)10.
(13) Filing Safety-Related Condition Reports.
(191.25)
(A) Each report of a safety-related
condition under paragraphs (12)(A)1.-9. must be filed (received by the
Associate Administrator, Office of Pipeline Safety at PHMSA and designated
commission personnel) in writing within five (5) working days (not including
Saturday, Sunday, or federal holidays) after the day a representative of the
operator first determines that the condition exists, but not later than ten
(10) working days after the day a representative of the operator discovers the
possibility of a condition. Separate conditions may be described in a single
report if they are closely related. Reporting methods and report requirements
are described in subsection (13)(C).
(B) Each report of a maximum allowable
operating pressure exceedance meeting the requirements of criteria in paragraph
(12)(A)10. for a gas transmission pipeline must be filed (received by the
Associate Administrator, Office of Pipeline Safety at PHMSA and designated
commission personnel) in writing within five (5) calendar days of the
exceedance using the reporting methods and report requirements described in
subsection (13)(C).
(C) Reports
must be filed by email to InformationResourcesManager@dot.gov or by facsimile
to (202) 366-7128 for the Office of Pipeline Safety, and by email to
PipelineSafetyProgramManager@psc.mo.gov or by facsimile to (573) 522-1946 for
designated
commission personnel. For a report made pursuant to paragraphs
(12)(A)1.-9., the report must be headed "Safety-Related Condition Report." For
a report made pursuant to paragraph (12)(A)10., the report must be headed
"Maximum Allowable Operating Pressure Exceedances." All reports must provide
the following information:
1. Name, principal
address, and operator identification number (OPID) of the operator;
2. Date of report;
3. Name, job title, and business telephone
number of the person submitting the report;
4. Name, job title, and business telephone
number of the person who determined that the condition exists;
5. Date the condition was discovered and date
the condition was first determined to exist;
6. Location of the condition, with reference
to the state (and town, city, or county), and as appropriate, nearest street
address, survey station number, milepost, landmark, or name of
pipeline;
7. Description of the
condition, including circumstances leading to its discovery, any significant
effects of the condition on safety, and the name of the commodity transported
or stored; and
8. The corrective
action taken (including reduction of pressure or shutdown) before the report is
submitted and the planned followup or future corrective action, including the
anticipated schedule for starting and concluding such action.
(14) National Pipeline
Mapping System (NPMS). (191.29)
(A) Each
operator of a gas transmission pipeline or liquefied natural gas facility must
provide the following geospatial data to PHMSA for that pipeline or facility:
1. Geospatial data, attributes, metadata, and
transmittal letter appropriate for use in the National Pipeline Mapping System.
Acceptable formats and additional information are specified in the NPMS
Operator Standards Manual available at
www.npms.phmsa.dot.gov or by
contacting the PHMSA geographic information systems manager at (202)
366-4595;
2. The name of and
address for the operator; and
3.
The name and contact information of a pipeline company employee, to be
displayed on a public website, who will serve as a contact for questions from
the general public about the operator's NPMS data.
(B) The information required in subsection
(14)(A) must be submitted each year, on or before March 15, representing assets
as of December 31 of the previous year. If no changes have occurred since the
previous year's submission, the operator must comply with the guidance provided
in the NPMS
Operator Standards manual available at
www.npms.phmsa.dot.gov or contact
the PHMSA geographic information systems manager at (202) 366-4595.
(C) This section does not apply to gathering
pipelines.