PURPOSE: This rule prescribes requirements and procedures for the reporting of certain events by electric utilities to the commission to inform the commission of developments that may affect the rendering of safe and adequate service and to enable the commission to thoroughly and fairly investigate certain accidents and events that may have an impact in future electric rate proceedings at the time and in the context in which those events occur. This rule also includes electrical facilities accident and event reporting requirements for rural electric cooperatives.

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.

1. (1) Definitions. The following definitions shall apply to this rule:

   1. (A) Facility is a site at which electric generating units and/ or equipment for converting mechanical, chemical, and/or nuclear energy into electric energy are situated. A facility may contain more than one generating unit or the same or different type.
   2. (B) Generating unit is an individual electric generator and its associated plant and apparatus whose electrical output is capable of being separately identified and metered.

2. (2) Every electric utility shall accumulate at least the following information and submit it monthly in the commission’s electronic filing and information system (EFIS) by the last day of the month following the month to be reported:

   1. (A) Monthly as-burned fuel report for each carbon-based fuel generating unit, including the amount of each type of fuel consumed, the British thermal unit (Btu) value of each fuel consumed, and the blending percentages (if applicable);
   2. (B) Capacity purchases of regardless of duration;
   3. (C) Schedule of planned outages of power production facilities;
   4. (D) Schedule of planned fuel test burns, unit heat-rate tests provided as a heat-rate curve, and accreditation runs with documentation of the results of all tests and runs;
   5. (E) Citations or notices of violation and copies of the electric utility response, or a statement that no such citations or notices were received, related to power production facilities received from any state or federal utility regulatory agency or environmental agency including but not limited to the Federal Energy Regulatory Commission (FERC), the North American Electric Reliability Corporation (NERC), the Nuclear Regulatory Commission (NRC), the Environmental Protection Agency (EPA), the Department of Natural Resources (DNR), and the Department of Energy (DOE);
   6. (F) Penalties incurred under a Regional Transmission Organization or an Independent System Operator Open Access Transmission Tariff, the reason for the penalty, and the expected remediation steps; and
   7. (G) The terms of new contracts or existing contracts which will be booked according to the FERC’s Uniform System of Accounts as adopted by the commission in 20 CSR 4240-20.030 requiring the expenditure by the electric utility of more than two hundred thousand dollars ($200,000) including but not limited to contracts for engineering, consulting, repairs, and modifications or additions to an electric facility.

3. (3) Monthly Reporting of Hourly Data.

   1. (A) Every electric utility shall accumulate the information described below and submit it monthly in EFIS on the last day of the month following the month to be reported:

      1. 1. All generating unit outages and derates for all units re-

gardless of size, dispatchability, fuel type, or ownership share;

1. 2. Net system input for the electric utility;
2. 3. Hourly generation for each generating unit both includ-

ing and excluding hourly station use;

1. 4. Hourly day-ahead cleared generation, hourly real-time

generation, and ancillary services for each generating unit;

1. 5. Hourly day-ahead load and real-time load at each load

node;

1. 6. Total load for each hour by—

   1. A. Wholesale load;
   2. B. Sale for resale load; and

   3. C. Retail load by—

      1. (I) Rate code if customers taking service on a rate code

are metered at a consistent voltage; or

1. (II) Rate schedule for each voltage of service offered

within each rate schedule; and

1. 7. Megawatt amount and delivery prices of hourly pur-

chases and sales of electricity from or to other electrical services providers, independent power producers, or cogenerators and small power producers, including any party to the purchase or sale, and the terms of the purchase or sale.

1. A. If adjustments are made to the price of hourly pur-

chases after the purchase is made, provide the amount of the adjustment and the time period over which the adjustment was made.

1. (B) The information in this section shall be provided in an electronic format from which the data can be easily extracted for analysis in spreadsheet or database software using the templates provided by the commission.

1. (4) Incident Reporting.

   1. (A) Every electric utility shall report through EFIS by the end of the first business day following discovery of an incident the information described below:

      1. 1. Details of any accident or event at a facility involving

serious physical injury or death or property damage in excess of two hundred thousand dollars ($200,000);

1. 2. Forced outages of any nuclear generating unit(s) that

could reasonably be anticipated to last longer than three (3) days;

1. 3. Forced outages of any fossil-fuel fired generating unit(s)

with an accredited capacity of greater than one hundred (100) megawatts that reasonably could be anticipated to last longer than three (3) days, when the unit(s) is forced out due to a common or unforeseen occurrence;

1. 4. Forced outages of wind and solar generating facilities

when there is a loss of at least thirty percent (30%) of total installed capacity that reasonably could be anticipated to last longer than three (3) days, when the cause is due to a common or unforeseen occurrence;

1. 5. Reductions of coal inventory below a thirty- (30-) day

supply and reductions of oil inventory below fifty percent (50%) of the storage capacity of that oil facility; and

1. 6. Loss of transmission capability that could limit the out-

put of a generating facility or the transfer capability into or out of the electric utility’s system.

1. (B) The electric utility shall submit, through EFIS within five

1. (5) business days following the discovery, an update of the incident including any details not available at the time of the initial report.

   1. (C) Incidents under paragraph (4)(A)1. require a detailed investigative report, which shall be submitted through EFIS within one hundred twenty (120) days.
2. (5) If a utility provides notice of a generating unit retirement to a regional transmission organization or an independent system operator, notice shall be provided to the commission in the applicable reporting month.

3. (6) Electrical Contact Reporting.

   1. (A) Every electric utility and rural electric cooperative shall notify designated commission personnel by telephone or in writing by the end of the first business day following the discovery of any electrical contact, provided the utility or rural electric cooperative first has received proper notice or has actual knowledge of the electrical contact, as described below:

      1. 1. Electrical contact, arc, or flash with its energized elec-

trical supply facilities or at locations it supplies power that results in admission to a hospital or the fatality of any person even when the source of the electric current is believed to have originated on the customer’s side of the meter; or

1. 2. Courtesy notifications may be provided regarding any

other electrical contact, arc, or flash considered significant by the electric utility or rural electric cooperative.

1. (B) The electric utility or rural electric cooperative shall submit to designated commission personnel within ten (10) business days following the initial notification a written report consisting of any details not available at the time of the initial notification, including information relevant to the circumstances of the incident. Relevant information may include the number of persons injured, type and extent of injuries, cause (if known), extent of any resulting outages, identification of the physical equipment of such electric utility or cooperative, a description of work being performed at the location, weather conditions, and the land use surrounding the scene of the incident.
2. (C) Electrical contact reporting may be made through EFIS or using the Missouri Public Service Commission Electrical Contact Reporting Form, hereby incorporated by reference and made a part of this rule, as published by the commission, September 24, 2024, and provided on the commission website at psc.mo.gov. This rule does not incorporate any subsequent amendments or additions.
3. (D) Contact information for designated commission personnel is included on the Missouri Public Service Commission Electrical Contact Reporting Form, hereby incorporated by reference and made a part of this rule, as published by the commission, September 24, 2024, and provided on the commission website at psc.mo.gov. This rule does not incorporate any subsequent amendments or additions.
4. (E) Neither the initial notification or written report nor the public availability of either shall be deemed to be an admission or waiver of any privilege of the notifying or reporting electric utility or rural electric cooperative.

1. (7) All reports and information submitted by electric utilities and rural electric cooperatives pursuant to this rule shall be subscribed by an authorized representative of the electric utility or rural electric cooperative having knowledge of the subject matter and shall be stated to be accurate and complete, and contain no material misrepresentations or omissions, based upon facts of which the person subscribing the report or information has knowledge, information, or belief.
2. (8) The reporting requirements prescribed by this rule shall be in addition to all other reporting requirements prescribed by law.
3. (9) The information contained in the reports filed pursuant to this rule shall be subject to the provisions of section 386.480, RSMo, and the use of that information in any proceeding before the commission shall be governed by the terms of 20 CSR 4240-2.135 and any protective order issued by the commission in the proceeding, if a protective order has been issued.
4. (10) The receipt by the commission or commission staff of reports prescribed by this rule shall not bind the commission or commission staff to the approval or acceptance of, or agreement with, any matter contained in the reports for the purpose of fixing rates or in determining any other issue that may come before the commission.
5. (11) Upon proper application and after notice and an opportunity for hearing, the commission, in its discretion, may waive any provision of this rule for good cause shown.

AUTHORITY: sections 386.250 and 394.160, RSMo 2016.* This rule originally filed as 4 CSR 240-3.190. Original rule filed Aug. 16, 2002, effective April 30, 2003. Amended: Filed Oct. 14, 2003, effective April 30, 2004. Amended: Filed Dec. 16, 2009, effective Aug. 30, 2010. Moved to 20 CSR 4240-3.190, effective Aug. 28, 2019. Amended: Filed July 31, 2024, effective March 30, 2025. *Original authority: 386.250, RSMo 1939, amended 1963, 1967, 1977, 1980, 1987, 1988, 1991, 1993, 1995, 1996, and 394.160, RSMo 1939, amended 1979.