PURPOSE: This rule prescribes requirements and procedures for reporting certain gas-related incidents and safety-related conditions and for filing annual reports. It applies to gas systems subject to the safety jurisdiction of the Public Service Commission.

PUBLISHER’S NOTE: The secretary of state has determined that publication of the entire text of the material that is incorporated by reference as a portion of this rule would be unduly cumbersome or expensive. This material as incorporated by reference in this rule shall be maintained by the agency at its headquarters and shall be made available to the public for inspection and copying at no more than the actual cost of reproduction. This note applies only to the reference material. The entire text of the rule is printed here.

AGENCY NOTE: This rule is similar to the Minimum Federal Safety Standards contained in 49 CFR part 191, Code of Federal Regulations. Parallel citations to Part 191 are provided for gas operator convenience and to promote public safety.

1. (1) Scope. (191.1)

   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)1.

   2. (B) Subsections (11)(B) and (11)(C) and section (12) do not apply to the onshore gathering of gas—

      1. 1. Through a pipeline that operates at less than zero (0)

pound per square inch gauge (psig) (0 kPa); or

1. 2. Through a pipeline that is not a regulated onshore gath-

ering line.

1. (2) Definitions. (191.3) As used in this rule and in the PHMSA forms referenced in this rule—

   1. (A) Administrator means the administrator of PHMSA or his or her delegate;
   2. (B) Commission means the Public Service Commission. Designated commission personnel means the Pipeline Safety Program Manager at the address contained in subsection (5)

2. (E) for correspondence and means the list of staff personnel supplied to operators for telephonic notices;

   1. (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;

   2. (D) Federal incident means any of the following events:

      1. 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:

1. A. A death or personal injury necessitating inpatient

hospitalization; or

1. B. Estimated property damage of one hundred forty-five

thousand four hundred dollars ($145,400) or more, including loss to the operator and others, or both, but excluding the cost of gas lost; or

1. C. Unintentional estimated gas loss of three (3) million

cubic feet or more;

1. 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

1. 3. An event that is significant, in the judgment of the oper-

ator, even though it did not meet the criteria of paragraph (2) (D)1. or (2)(D)2.

1. (E) Gas means natural gas, flammable gas, manufactured gas, or gas which is toxic or corrosive;
2. (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;
3. (G) LNG plant means an LNG facility or system of LNG facilities functioning as a unit;
4. (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;
5. (I) Municipality means a city, village, or town;
6. (J) Operator means a person who engages in the transportation of gas;
7. (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;
8. (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;
9. (M) PHMSA means the Pipeline and Hazardous Materials Safety Administration of the United States Department of Transportation;
10. (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)1.;
11. (O) Reporting-regulated gathering means a Type R gathering line as determined in 20 CSR 4240-40.030(1)(E)1. A Type R gathering line is subject only to this rule;
12. (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

13. (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. 1. A depleted hydrocarbon reservoir, an aquifer reservoir,

or a solution-mined cavern; and

1. 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.

1. (3) Immediate Notice of Federal Incidents. (191.5)

   1. (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).

   2. (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. 1. Names of operator and person making report and their

telephone numbers;

1. 2. Location of the incident;
2. 3. Time of the incident;
3. 4. Number of fatalities and personal injuries, if any; and
4. 5. All other significant facts known by the operator that are

relevant to the cause of the incident or extent of the damages.

1. (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.

1. (4) Immediate Notice of Missouri Incidents.

   1. (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. 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:

1. A. A death;
2. 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

1. C. Estimated property damage of nineteen thousand

two hundred dollars ($19,200) or more, including loss to the gas operator or others, or both, and including the cost of gas lost;

1. 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

1. 3. An event that is reported as a federal incident under

section (3).

1. (B) Exceeding the two- (2-) hour notification time period in subsection (4)(A) requires submission of a written explanation of reasons with the operator’s incident report when submitting the report to designated commission personnel. See section (5) for report submission requirements.

1. (5) Report Submission Requirements. (191.7)

   1. (A) Reports to PHMSA.

      1. 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).

1. 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.

1. (B) Missouri incident reports.

   1. 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.

1. 2. The incident report forms for gas distribution systems

(PHMSA F 7100.1), gas transmission pipeline systems, gas gathering pipeline systems, and underground natural gas storage facilities (PHMSA F 7100.2), Type R (reporting-regulated) gas gathering pipeline systems (PHMSA F 7100.2.2), and LNG facilities (PHMSA F 7100.3) are incorporated by reference in subsection (5)(G).

1. (C) Safety-related conditions. An operator must submit concurrently to PHMSA and designated commission personnel a safety-related condition report required by section (12). A safety-related condition report can be submitted by electronic mail or telefacsimile (fax) as provided for in section (13).

2. (D) Alternative reporting method.

   1. 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.

1. 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 PipelineSafetyProgramManager@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 www.npms. phmsa.dot.gov or by contacting the PHMSA geographic information systems manager at (202) 366–4595. (G) Forms incorporated by reference.

1. 1. The following forms are incorporated by reference and

made part of this rule.

1. A. U.S. Department of Transportation Form PHMSA F

1000.1, revised March 2022. The PHMSA F 1000.1 form is the Operator Identification (OPID) Assignment Request form and does not include any amendments or additions to the March 2022 version.

1. B. U.S. Department of Transportation Form PHMSA F

1000.2, revised March 2022. 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 March 2022 version.

1. C. U.S. Department of Transportation Form PHMSA F

7100.1, revised September 2023. 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 September 2023 version.

1. D. U.S. Department of Transportation Form PHMSA F

7100.1-1, revised June 2023. 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 June 2023 version.

1. E. Reserved.
2. F. U.S. Department of Transportation Form PHMSA F

7100.2, revised September 2023. The PHMSA F 7100.2 form is the incident report form for gas transmission pipeline systems, gas gathering pipeline systems, and underground natural gas storage facilities and does not include any amendments or additions to the September 2023 version.

1. G. U.S. Department of Transportation Form PHMSA F

7100.2-1, revised August 2023. 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 August 2023 version.

1. H. U.S. Department of Transportation Form PHMSA F

7100.3, revised September 2023. The PHMSA F 7100.3 form is the incident report form for LNG facilities and does not include any amendments or additions to the September 2023 version.

1. 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.

1. J. U.S. Department of Transportation Form PHMSA F

7100.4-1, approved March 1, 2022. 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 March 1, 2022, version.

1. K. U.S. Department of Transportation Form PHMSA F

7100.2.2, approved March 2022. The PHMSA F 7100.2.2 form is the incident report form for Type R (reporting-regulated) gas gathering pipeline systems and does not include any amendments or additions to the March 2022 version.

1. L. U.S. Department of Transportation Form PHMSA F

7100.2-3, approved March 2022. The PHMSA F 7100.2-3 form is the annual report form for Type R (reporting-regulated) gas gathering pipeline systems and does not include any amendments or additions to the March 2022 version.

1. 2. The forms listed in paragraph (5)(G)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 https://www.phmsa.dot.gov/ forms/operator-reports-submitted-phmsa-forms-and-instructions or upon request from the pipeline safety program manager at the address given in subsection (5)(E).

1. (6) Distribution System—Federal Incident Report. (191.9)

   1. (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). See the report submission requirements in subsection (5)(A). The incident report form is incorporated by reference in subsection (5)(G).
   2. (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.
   3. (C) The incident report required by this section need not be submitted with respect to master meter systems.

2. (7) Distribution System—Annual Report.

   1. (A) Annual report. (191.11)

      1. 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).

1. 2. The annual report form is incorporated by reference in

subsection (5)(G).

1. 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)1.

1. (B) Reserved.

1. (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). 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).

2. (9) Transmission Systems; Gathering Systems; Liquefied Natural Gas Facilities; and Underground Natural Gas Storage Facilities—Federal Incident Report. (191.15)

   1. (A) Transmission or gathering.

      1. 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). See the report submission requirements in subsection (5)(A). The incident report form is incorporated by reference in subsection (5)(G).

1. 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) that occurs after May 16, 2022. See the report submission requirements in subsection (5)(A). The incident report form is incorporated by reference in subsection (5)(G).

1. (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

1. (30) days after detection of an incident required to be reported under section (3). See the report submission requirements in subsection (5)(A). The incident report form is incorporated by reference in subsection (5)(G).

   1. (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). See the report submission requirements in subsection (5)(A). The incident report form is incorporated by reference in subsection (5)(G).
   2. (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.

2. (10) Transmission Systems; Gathering Systems; Liquefied Natural Gas Facilities; and Underground Natural Gas Storage Facilities—Annual Report. (191.17)

   1. (A) Transmission or gathering.

      1. 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 is incorporated by reference in subsection (5)(G).

1. 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 is incorporated by reference in subsection (5)(G).

1. (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 is incorporated by reference in subsection (5)(G).
2. (C) Underground natural gas storage facility. Each operator of an UNGSF must submit an annual report through U.S. Department of Transportation Form PHMSA F 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 is incorporated by reference in subsection (5)(G).

1. (11) National Registry of Pipeline and LNG Operators. (191.22)

   1. (A) OPID request.

      1. 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).

1. 2. The OPID Assignment Request form is incorporated by

reference in subsection (5)(G).

1. (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).

2. (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. 1. An operator must notify PHMSA of any of the following

events not later than sixty (60) days before the event occurs:

1. A. Construction or any planned rehabilitation, replace-

ment, 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;

1. B. Construction of ten (10) or more miles of a new

pipeline;

1. C. Construction of a new LNG plant, LNG facility, or

UNGSF;

1. 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;

1. 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 bidirectional flow; or

1. F. A pipeline converted for service under 20 CSR 4240-

40.030(1)(H), or a change in commodity as reported on the annual report as required by section (10).

1. 2. An operator must notify PHMSA of any of the following

events not later than sixty (60) days after the event occurs:

1. 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;

1. B. A change in the name of the operator;
2. C. A change in the entity (e.g., company, municipality)

responsible for an existing pipeline, pipeline segment, pipeline facility, UNGSF, or LNG facility;

1. 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

1. E. The acquisition or divestiture of an existing UNGSF, or

an LNG plant, or LNG facility subject to 49 CFR Part 193.

1. (D) Reporting. An operator must use the OPID issued by PHMSA for all reporting requirements covered under 20 CSR 4240-40.020, 20 CSR 4240-40.030, 20 CSR 4240-40.033, and 20 CSR 4240-40.080, and for submissions to the National Pipeline Mapping System.

1. (12) Reporting Safety-Related Conditions. (191.23)

   1. (A) Except as provided in subsection (12)(B), each operator must report in accordance with section (13) the existence of any of the following safety-related conditions involving facilities in service:

      1. 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;

1. 2. In the case of a 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;

1. 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 a UNGSF, or an LNG facility that contains, controls, or processes gas or LNG;

1. 4. Any crack or other material defect that impairs the

structural integrity or reliability of a UNGSF or an LNG facility that contains, controls, or processes gas or LNG;

1. 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 a UNGSF;

1. 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 a UNGSF, or the maximum allowable working pressure of an LNG facility that contains or processes gas or LNG;

1. 7. A leak in a pipeline, UNGSF, or LNG facility that contains

or processes gas or LNG that constitutes an emergency;

1. 8. Inner tank leakage, ineffective insulation, or frost heave

that impairs the structural integrity of an LNG storage tank;

1. 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;

1. 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). 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

1. 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.

1. (B) A report is not required for any safety-related condition that—

   1. 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 20 CSR 4240-40.030(1) (E)2.E.(I), or a customer-owned service line;

1. 2. Is an incident or results in an incident before the

deadline for filing the safety-related condition report;

1. 3. Exists on a pipeline (other than a 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;

1. 4. Exists on a 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

1. 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—

1. A. Conditions under paragraph (12)(A)1., unless the

condition is localized corrosion pitting on an effectively coated and cathodically protected pipeline; and

1. B. Any condition under paragraph (12)(A)10.

1. (13) Filing Safety-Related Condition Reports. (191.25)

   1. (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
2. (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

3. (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).

   1. (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).
   2. (C) Reports must be filed by email to InformationResourcesManager@dot.gov or by facsimile to

4. (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. 1. Name, principal address, and operator identification

number (OPID) of the operator;

1. 2. Date of report;
2. 3. Name, job title, and business telephone number of the

person submitting the report;

1. 4. Name, job title, and business telephone number of the

person who determined that the condition exists;

1. 5. Date the condition was discovered and date the

condition was first determined to exist;

1. 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;

1. 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

1. 8. The corrective action taken (including reduction of

pressure or shutdown) before the report is submitted and the planned follow-up or future corrective action, including the anticipated schedule for starting and concluding such action.

1. (14) National Pipeline Mapping System (NPMS). (191.29)

   1. (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. 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;

1. 2. The name of and address for the operator; and
2. 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.

1. (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.
2. (C) This section does not apply to gathering pipelines.

AUTHORITY: sections 386.250, 386.310, and 393.140, RSMo 2016.* This rule originally filed as 4 CSR 240-40.020. Original rule filed Feb. 5, 1970, effective Feb. 26, 1970. Amended: Filed Dec. 19, 1975, effective Dec. 29, 1975. Amended: Filed Feb. 8, 1985, effective Aug. 11, 1985. Rescinded and readopted: Filed May 17, 1989, effective Dec. 15, 1989. Amended: Filed Oct. 7, 1994, effective May 28, 1995. Amended: Filed April 9, 1998, effective Nov. 30, 1998. Amended: Filed Dec. 14, 2000, effective May 30, 2001. Amended: Filed Oct. 15, 2007, effective April 30, 2008. Amended: Filed Nov. 29, 2012, effective May 30, 2013. Amended: Filed Nov. 14, 2016, effective June 30, 2017. Amended: Filed June 4, 2018, effective Jan. 30, 2019. Moved to 20 CSR 4240-40.020, effective Aug. 28, 2019. Amended: Filed Dec. 12, 2019, effective July 30, 2020. Amended: Filed June 29, 2021, effective Jan. 30, 2022. Amended: Filed July 29, 2022, effective Feb. 28, 2023. Amended: Filed March 19, 2025, effective Nov. 30, 2025. *Original authority: 386.250, RSMo 1939, amended 1963, 1967, 1977, 1980, 1987, 1988, 1991, 1993, 1995, 1996; 386.310, RSMo 1939, amended 1979, 1989, 1996; and 393.140, RSMo 1939, amended 1949, 1967.