To eliminate ambiguities in the rules, to revise definitions, and to more clearly define the data needed to assess reliability of distribution of electric power.

 

PUBLIC SERVICE COMMISSION

Departmental

RULE NOS.: RULE TITLES:

25-6.044 Continuity of Service

25-6.0455 Annual Distribution Service Reliability Report

PURPOSE AND EFFECT: To eliminate ambiguities in the rules, to revise definitions, and to more clearly define the data needed to assess reliability of distribution of electric power.
SUBJECT AREA TO BE ADDRESSED: Continuity and reliability of electric service.

SPECIFIC AUTHORITY: 366.05(1) FS.

LAW IMPLEMENTED: 366.03 FS., 366.04(5) FS., 366.05 FS., 366.04(2)(c), (f) FS.

IF REQUESTED IN WRITING AND NOT DEEMED UNNECESSARY BY THE AGENCY HEAD, A RULE DEVELOPMENT WORKSHOP WILL BE HELD AT THE DATE, TIME AND PLACE SHOWN BELOW:

DATE AND TIME: February 22, 2006, 9:30 a.m.

PLACE: Betty Easley Conference Center, Room 148, 4075 Esplanade Way, Tallahassee, Florida

Any person requiring some accommodation at this workshop because of a physical impairment should call the Division of the Commission Clerk and Administrative Services, [phone], at least 48 hours prior to the hearing. Any person who is hearing or speech impaired should contact the Florida Public Service Commission by using the Florida Relay Service, 1(800)955-8771 (TDD).

THE PERSON TO BE CONTACTED REGARDING THE PROPOSED RULE DEVELOPMENT AND A COPY OF THE PRELIMINARY DRAFT IS: Marlene Stern, Office of General Counsel, Florida Public Service Commission, 2540 Shumard Oak Blvd., Tallahassee, FL 32399-0862, [phone]

 

THE PRELIMINARY TEXT OF THE PROPOSED RULE DEVELOPMENT IS:

 

25-6.044 Continuity of Service.

(1) Definitions applicable to this part:

(a) "Area of Service." A geographic area where a utility provides retail electric service. An Area of Service can be the entire system, a district, or a subregion of the utility's system in which centralized distribution service functions are carried out region into which a utility divides its system.

(b) through (p) No change.

(q) Planned Service Interruption." A Service Interruption initiated by the utility to perform necessary scheduled activities for public safety reasons or for scheduled activities, such as maintenance, infrastructure improvements, and new construction due to customer growth. Customers are typically notified in advance of these events.

(2) Each utility shall keep a record of its system reliability and continuity of service data, customers' Service Interruption notifications, and other data necessary for the annual reports filed under these rules. These records and data shall be retained for a minimum of ten years from the filing of each annual report. The utility shall record each Outage Event as planned or unplanned and shall identify the point of origination such as generation facility, transmission line, transmission substation equipment, or distribution equipment. The cause of each Outage event shall be determined and recorded in a standardized manner throughout the utility. The date and time of the Outage Event and the number of Service Interruptions for the Outage Event shall also be recorded.

(3) through (5) No change.

Specific Authority 366.05(1) FS. Law Implemented 366.03, 366.04(2)(c), 366.04(5), 366.05 FS. History–New 7-29-69, Formerly 25-6.44, Amended 2-25-93, 11-7-02, ________.

 

25-6.0455 Annual Distribution Service Reliability Report.

(1) Each utility shall file a Distribution Service Reliability Report with the Director of the Commission's Division of Economic Regulation on or before March 1st of each year, for the preceding calendar year. The report shall contain the following information:

(a) The utility's total number of Outage Events (N), categorized by cause for the highest 10 causes of Outage Events, the Average Duration of Outage Events (L-Bar), and Average Service Restoration Time (CAIDI). The utility shall record these data and analyses on Form PSC/ECR 102-1, entitled "Outage Events" which may be obtained from the Division of Economic Regulation, 2540 Shumard Oak Boulevard, Tallahassee, Florida 32399-0850, [phone];

(b) Identification of the three percent of the utility's Primary Circuits (feeders) with the highest number of feeder breaker interruptions. For each primary circuit so identified the utility shall report the primary circuit identification number or name, substation origin, general location, number of affected customers by service class served, Number of Outage Events (N), Average Duration of Outage Events (L-Bar), Average Service Restoration Time (CAIDI), whether the same circuit is being reported for the second consecutive year, the number of years the primary circuit was reported on the "Three Percent Feeder List" in the past five years, and the corrective action date of completion. The utility shall record these data and analyses on Form PSC/ECR 102-2, entitled "Three Percent Feeder List" which may be obtained from the Division of Economic Regulation, 2540 Shumard Oak Boulevard, Tallahassee, Florida 32399-0850, [phone];

(c) The reliability indices SAIDI, CAIDI, SAIFI, MAIFIe, and CEMI5 for its system and for each district or region into which its system may be divided. The utility shall report these data and analyses on Form PSC/ECR 102-3, entitled "System Reliability Indices" which may be obtained from the Division of Economic Regulation, 2540 Shumard Oak Boulevard, Tallahassee, Florida 32399-0850, [phone]. Any utility furnishing electric service to fewer than 50,000 retail customers shall not be required to report the reliability indices MAIFIe or CEMI5;

(d) The calculations for each of the required indices and measures of distribution reliability;

(2) The Distribution Service Reliability Report will exclude the impact of all service interruptions associated with generation and transmission disturbances governed by subsections 25-6.018(2) and (3), F.A.C. A utility may exclude from the Annual Distribution Service Reliability Report the Outage Events directly caused by one or more of the following: planned interruptions, a storm named by the National Hurricane Center, a tornado recorded by the National Weather Service, ice on lines, a planned load management event, an electric generation disturbance, an electric transmission system disturbance, or an extreme weather or fire event causing activation of the county emergency operation center.

(3) The report shall contain the following information on an actual and adjusted basis: A utility may submit a request to exclude an Outage Event from the Annual Distribution Service Reliability Report that is not specifically provided for in subsection 25-6.0455(2), F.A.C. Such a request must be filed with the Commission's Division of the Commission Clerk and Administrative Services within 30 days of the Outage Event for which an exclusion is being requested. The Commission will approve the request if the utility is able to demonstrate that the outage was not within the utility's control, and that the utility could not reasonably have prevented the outage.

(a) The utility's total number of Outage Events(N), categorized by cause for the highest 10 causes of Outage Events, the Average Duration of Outage Events (L-Bar), and Average Service Restoration Time (CAIDI). The utility shall record these data and analyses on Form PSC/ECR 102-1(a) (__/06) and Form PSC/ECR 102-1(b) (__/06), entitled "Causes of Outage Events - Actual" and "Causes of Outage Events- Adjusted", respectively, which may be obtained from the Division of Economic Regulation, 2540 Shumard Oak Boulevard, Tallahassee, Florida 32399-0850, [phone], and which are incorporated herein by reference;

(b) Identification of the three percent of the utility's Primary Circuits (feeders) with the highest number of feeder breaker interruptions. For each primary circuit so identified the utility shall report the primary circuit identification number or name, substation origin, general location, number of affected customers by service class served, Number of Outage Events (N), Average Duration of Outage Events (L-Bar), Average Service Restoration Time (CAIDI), whether the same circuit is being reported for the second consecutive year, the number of years the primary circuit was reported on the "Three Percent Feeder List" in the past five years, and the corrective action date of completion. The utility shall record these data and analyses on Form PSC/ECR 102-2(a) (_/06) and Form PSC/ ECR 102-2(b) (_/06), entitled "Three Percent Feeder List - Actual" and "Three Percent Feeder List - Adjusted", respectively, which may be obtained from the Division of Economic Regulation, 2540 Shumard Oak Boulevard, Tallahassee, Florida 32399-0850, [phone], and which are incorporated herein by reference;

(c) The reliability indices SAIDI, CAIDI, SAIFI, MAIFIe, and CEMI5 for its system and for each district or region into which its system may be divided. The utility shall report these data and analyses on Form PSC/ECR 102-3(a) (__/06) and Form PSC/ECR 102-3(b) (__/06), entitled "System Reliability Indices - Actual" and "System Reliability Indices - Adjusted", respectively, which may be obtained from the Division of Economic Regulation, 2540 Shumard Oak Boulevard, Tallahassee, Florida 32399-0850, [phone], and which are incorporated herein by reference. Any utility furnishing electric service to fewer than 50,000 retail customers shall not be required to report the reliability indices MAIFIe or CEMI5; and

(d) The calculations for each of the required indices and measures of distribution reliability.

(4) Adjusted distribution reliability data may reflect Outage Events caused by;

(a) Planned Service Interruptions;

(b) Events resulting in catastrophic damage to utility facilities shown to be beyond the ability of the utility to control and which directly cause more than 10 percent of the utility's retail customers in the utility's Area of Service to experience Service Interruptions within a consecutive 24 hour period.

(5) Each utility shall provide justification for each Outage Event removed from the data in its adjusted reliability indices as reflected in its reported Form PSC/ECR 102-1(b). For each removed Outage Event, the utility will include the following information:

(a) Area of Service affected;

(b) The number of Primary Circuits (feeders) affected;

(c) The physical damages incurred to utility facilities;

(d) The time and resources required to restore service;

(e) The costs incurred to restore service;

(f) The applicable operational or construction standards;

(g) The actions taken to mitigate damages to its facilities; and

(h) The effects of the Outage Event on each of the reported indices.

Specific Authority 366.05(1) FS. Law Implemented 366.03, 366.04(2)(c),(f), 366.04(5), 366.05, 366.05(7) FS. History–New 2-25-93, Amended 11-7-02, ________.