PURPOSE: This rule prescribes requirements and procedures for reporting certain gasrelated 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 the publication of the entire text of the material which is incorporated by reference as a portion of this rule AND INSURANCE

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, and annual pipeline summary data by operators of gas pipeline facilities located in Missouri and under the jurisdiction of the commission.

   2. (B) This rule does not apply to 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 regu-

lated onshore gathering line (as determined in 20 CSR 4240-40.030(1)(E) (192.8)).

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)(E) for correspondence and means the list of staff personnel supplied to operators for telephonic notices;
   3. (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;

   4. (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, 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 neces-

sitating inpatient hospitalization; or

1. B. Estimated property damage of fifty

thousand dollars ($50,000) 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 underground natural gas storage facility. 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 operator, 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) 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

11. (O) Underground natural gas storage facility means a facility that stores natural gas in an underground facility incident to natural gas transportation, including—

    1. 1. A depleted hydrocarbon reservoir;
    2. 2. An aquifer reservoir; or
    3. 3. A solution-mined salt cavern reservoir,

including associated material and equipment used for injection, withdrawal, monitoring, or observation wells, and wellhead equipment, piping, rights-of-way, property, buildings, compressor units, separators, metering equipment, and regulator equipment.

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) (191.3).

   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 mak-

ing 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

1. 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 medi-

cal 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 ten

thousand dollars ($10,000) 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 dis-

tribution systems (PHMSA F 7100.1, revised October 2014), gas transmission and gathering pipeline systems (PHMSA F 7100.2, revised October 2014), and LNG facilities (PHMSA F 7100.3, revised October 2014) 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) (191.23). 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 alter-

nate 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.

1. (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.
2. (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.

3. (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 20 CSR 4240-40

Form PHMSA F 1000.1, revised April 2019. The PHMSA F 1000.1 form is the Operator Identification (OPID) Assignment Request form and does not include any amendments or additions to the April 2019 version.

1. B. U.S. Department of Transportation

Form PHMSA F 1000.2, revised April 2019. The PHMSA F 1000.2 form is the Operator 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 April 2019 version.

1. C. U.S. Department of Transportation

Form PHMSA F 7100.1, revised October 2014. 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 October 2014 version.

1. D. U.S. Department of Transportation

Form PHMSA F 7100.1-1, revised October 2018. 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 October 2018 version.

1. E. U.S. Department of Transportation

Form PHMSA F 7100.1-2, revised October 2014. The PHMSA F 7100.1-2 form is the report form for mechanical fitting failures and does not include any amendments or additions to the October 2014 version.

1. F. U.S. Department of Transportation

Form PHMSA F 7100.2, revised October 2014. 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 October 2014 version.

1. G. U.S. Department of Transportation

Form PHMSA F 7100.2-1, revised October 2014. 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 2014 version.

1. H. U.S. Department of Transportation

Form PHMSA F 7100.3, revised October 2014. The PHMSA F 7100.3 form is the incident report form for LNG facilities and does not include any amendments or additions to the October 2014 version.

1. I. U.S. Department of Transportation

Form PHMSA F 7100.3-1, revised August 2017. 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 August 2017 version.

1. J. U.S. Department of Transportation AND INSURANCE

Form PHMSA 7100.4-1, 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.

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 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)

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

1. (3) (191.5). See the report submission requirements in subsection (5)(A). The incident report form (revised October 2014) is incorporated by reference in subsection (5)(G).

   1. (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.
   2. (C) The incident report required by this section need not be submitted with respect to master meter systems.

2. (7) Distribution System—Annual Report and Mechanical Fitting Failure Reports.

   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 (revised

October 2018) 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 or to a petroleum gas system which serves fewer than one hundred (100) customers from a single source.

1. (B) Mechanical Fitting Failure Reports. (191.12)

   1. 1. Each mechanical fitting failure, as

required by 20 CSR 4240-40.030(17)(E) (192.1009), must be submitted on a Mechanical Fitting Failure Report Form (U.S. Department of Transportation Form PHMSA F 7100.1–2). An operator must submit a mechanical fitting failure report for each mechanical fitting failure that occurs within a calendar year not later than March 15 of the following year. Alternatively, an operator may elect to submit its reports throughout the year. In addition, an operator must also report this information to designated commission personnel.

1. 2. The Mechanical Fitting Failure

Report Form (October 2014) is incorporated by reference in subsection (5)(G).

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) (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).

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. Each operator of a transmission or a 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 October 2014) is incorporated by reference in subsection (5)(G).
   2. (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. (3) (191.5). See the report submission requirements in subsection (5)(A). The incident report form (revised October 2014) is incorporated by reference in subsection (5)(G).

   1. (C) Underground natural gas storage facility. Each operator of an underground natural gas storage facility 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

4. (3) (191.5). The incident report form (revised October 2014) is incorporated by reference in subsection (5)(G).

   1. (D) Supplemental Report. When additional related information is obtained after a report is submitted 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.

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

   1. (A) Transmission or Gathering. Each operator of a transmission or a 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 2014) is incorporated by reference in subsection (5)(G).
   2. (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 August 2017) is incorporated by reference in subsection (5)(G).
   3. (C) Underground natural gas storage facility. Each operator of an underground natural gas storage facility must submit an annual report on U.S. Department of Transportation Form PHMSA 7100.4-1 by 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).

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

   1. (A) OPID Request.

      1. 1. Effective January 1, 2012, each oper-

ator of a gas pipeline, gas pipeline facility, underground natural gas storage facility, LNG plant, or LNG facility must obtain from PHMSA an Operator Identification Number (OPID). An OPID is assigned to an operator for the pipeline 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 Pipeline and LNG Operators at http://portal.phmsa.dot.gov/pipeline 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

(April 2019) is incorporated by reference in subsection (5)(G).

1. (B) OPID Validation. An operator who has already been assigned one (1) or more OPID by January 1, 2011, must validate the information associated with each OPID through the National Registry of Pipeline and LNG Operators at http://opsweb.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, underground natural gas storage facility, LNG plant, or LNG facility must notify PHMSA electronically through the National Registry of Pipeline and LNG Operators at http://portal.phmsa.dot.gov/pipeline 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 reha-

bilitation, 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;

1. B. Construction of ten (10) or more

miles of a new or replacement pipeline;

1. C. Construction of a new LNG plant

or LNG facility;

1. D. Construction of a new under-

ground natural gas storage facility or the abandonment, drilling, or well workover (including replacement of wellhead, tubing, or a new casing) of an injection, withdrawal, monitoring, or observation well for an underground natural gas storage facility;

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 bi-directional flow; or

1. 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).

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 oper-

ator;

1. C. A change in the entity (e.g., com-

pany, municipality) responsible for an existing pipeline, pipeline segment, pipeline facility, underground natural gas storage facility, 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;

1. E. The acquisition or divestiture of an

existing LNG plant or LNG facility subject to 49 CFR Part 193; or

1. F. The acquisition or divestiture of an

existing underground natural gas storage facility subject to 49 CFR part 192.

1. (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.

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) (191.25) 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 an underground natural

gas storage facility, including injection, withdrawal, monitoring, or observation well, general corrosion that has reduced the wall thickness to less than that required for the maximum well operating pressure, and localized corrosion pitting to a degree where leakage 20 CSR 4240-40

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 an underground natural gas storage facility, including injection, withdrawal, monitoring, or observation well for an underground natural gas storage facility, or 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 an underground natural gas storage facility or LNG facility that contains, controls, or processes gas or LNG;

1. 5. Any material defect or physical dam-

age 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 underground natural gas storage facility, including injection, withdrawal, monitoring, or observations well for an underground natural gas storage facility;

1. 6. Any malfunction or operating error

that causes the pressure of:

1. A. A pipeline to rise above its maxi-

mum allowable operating pressure plus the buildup allowed for operation of pressure limiting or control devices;

1. B. An underground natural gas stor-

age facility to rise above its maximum well operating pressure plus the margin (build-up) allowed for operation of pressure limiting or control devices; or

1. C. An LNG facility that contains or

processes gas or LNG to rise above its working pressure plus the margin (build-up) allowed for operation of pressure limiting or control devices.

1. 7. A leak in a pipeline or an under-

ground natural gas storage facility, including injection, withdrawal, monitoring, or observation well for an underground natural gas storage facility, or LNG facility that contains or processes gas or LNG that constitutes an emergency;

1. 8. Inner tank leakage, ineffective insula-

tion, or frost heave that impairs the structural integrity of an LNG storage tank; and

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 or an underground natural gas storage facility, including injection, withdrawal, monitoring, or observation well for an underground natural gas storage facility, or an LNG facility AND INSURANCE

that contains or processes gas or LNG.

1. (B) A report is not required for any safetyrelated condition that—

   1. 1. Exists on a master meter system 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 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; or

1. 4. Is corrected by repair or replacement

in accordance with applicable safety standards before the deadline for filing the safety-related condition report, except that reports are required for conditions under paragraph (12)(A)1. other than localized corrosion pitting on an effectively coated and cathodically protected pipeline.

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

   1. (A) Each report of a safety-related condition under subsection (12)(A) must be filed (received by the Office of Pipeline Safety at PHMSA and designated commission personnel) 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. See the report submission requirements in subsection (5)(C). Reports may be transmitted by electronic mail to InformationResourcesManager@dot.gov and PipelineSafetyProgramManager@psc.mo.gov. To file a report by telefacsimile (fax), dial

2. (202) 366-7128 for the Office of Pipeline Safety and (573) 522-1946 for designated commission personnel.

   1. (B) The report must be titled Safety- Related Condition Report and provide the following information:

      1. 1. Name and principal address of the

operator;

1. 2. Date of report;
2. 3. Name, job title, and business tele-

phone number of the person submitting the report;

1. 4. Name, job title, and business tele-

phone 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 refer-

ence 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, includ-

ing 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 oper-

ator; and

1. 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.

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.

*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.