3603.1The electric utility shall implement a plan to improve the performance of the two percent (2%) least performing feeders such that no feeder in the 2% least performing group shall repeat as a member of the 2% least performing feeders following implementation of the plan.
3603.2Individual feeder performance shall be determined using the utility's composite performance index.
3603.3If the utility fails to comply with Section 3603.1, it shall be required to develop a corrective action plan.
3603.4The corrective action plan shall clearly describe the cause(s) of the utility's noncompliance with Section 3603.1 (including an explanation as to why a particular feeder has remained on the list after the implementation of the plan in Section 3603.1), describe the corrective measure(s) to be taken to ensure that the standard is met or exceeded in the future, and provide a target date for completion of the corrective measure(s).
3603.5The utility shall report on the progress of the corrective action plan as described in Section 3603.3 in the Annual Consolidated Report submitted to the Commission.
3603.6The utility shall continue the current reporting of the worst performing (lowest two percent (2%)) feeders (utility methodology) and corresponding corrective action plans, with the action taken in Year 1 and the subsequent performance in Year 2 in the Annual Consolidated Report.
3603.7 The utility shall complete service restoration within twenty-four (24) hours following a non-major service outage.
3603.8The utility shall report on the number and percentage of non-major service outages that extend beyond the twenty-four (24) hour standard and the reasons each such outage extended beyond the twenty-four (24) hour standard.
3603.9The report drafted pursuant to Section 3603.8 shall be included in the Annual Consolidated Report on reliability data.
3603.10 The utility shall not exceed the reliability performance standards established for the following indices, calculated using District of Columbia data: System Average Interruption Frequency Index ("SAIFI") and System Average Interruption Duration Index ("SAIDI") (stated in hours).
3603.11 The reliability performance standards adopted by the Public Service Commission for SAIDI and SAIFI are established as follows:
(a) For 2023, SAIDI shall be one and two hundredths (1.02) and SAIFI shall be fifty-six hundredths (0.56); and(b) For 2024, SAIDI shall be one (1.00) and SAIFI shall be fifty-five hundredths (0.55).3603.12The calculations of these indices shall exclude District of Columbia Major Service Outages ("MSOs") and include only outages on feeders with a majority of customers in the District of Columbia.
3603.13 If the electric utility fails to comply with the reliability performance standards in Section 3603.11, it may be subject to forfeiture in accordance with D.C. Official Code §§ 34-706 and 34-1508 (2019 Repl.) pursuant to the enforcement procedures in Section 3698 of this chapter. The electric utility shall also be required to develop a corrective action plan, which it shall file for the Commission's information within thirty (30) days of filing its Annual Consolidated Report of the following year.
3603.14 The corrective action plan shall clearly describe the cause(s) of the electric utility's failure to comply with Section 3603.11, describe the corrective measure(s) to be taken to ensure that the standard is met or improved upon in the future, and provide a target date for completion of the corrective measure(s).
3603.15 The utility shall report on the progress of any Section 3603.14 corrective action plans in the following year's Annual Consolidated Report submitted to the Commission.
3603.16 The electric utility shall also report in its Annual Consolidated Report of the following year the following reliability performance information:
(a) Its annual reliability indices of SAIFI, SAIDI, and CAIDI, calculated first, using District-only data with and without Major Service Outages ("MSOs"); and second, using District-only data based on the IEEE 13662012 standard with and without Major Event Days; and.(b) The number of its customers experiencing three or more sustained interruptions of power (CEMI3) inclusive of MSOs. When reporting CEMI3, Pepco shall indicate its CEMI3 first, across the District as a whole, second, by Ward and third, within each District neighborhood by Ward.3603.17Major Service Outage Restoration Plan. The utility shall comply with its filed Major Service Outage Restoration Plan when preparing for and responding to a Major Service Outage. The Major Service Outage Restoration Plan shall provide a description of and procedures for the utility's response to Major Service Outage events, including, but not limited to, the following topics and issues:
(a) Major Service Outage restoration preparation, training, and drills;(b) Early storm detection, storm tracking, and internal and external warnings;(c) Activation, mobilization, and deployment of internal and external resources, including both staffing levels and equipment;(d) Materials management and logistics;(e) Major Service Outage restoration priorities, taking into account, among other priorities, the electric power needs of emergency responders and their associated dispatching systems, hospitals, water and sewer pumping stations, natural gas utility and telecommunications service providers, national security and other essential agencies of the federal and District governments, and other essential services. In addition, the utility shall describe:(1) How it prioritizes power restoration between the various priority classifications adopted by the utility;(2) How it prioritizes power restoration among electric customers falling within the same priority classification; and(3) How the utility prioritizes restoration of power for, and communicates with, customers, including residential customers, that have demonstrated to the utility a medical need for electricity;(f) Damage assessment and inspections;(g) Public safety, including wire down response in situations in which downed wires are guarded by fire or police responders and situations in which downed wires are not guarded by fire or police responders;(h) Deployment and supervision of, and communications with, field crews, whether composed of the utility's employees, employees of third-party contractors, or composed of temporary personnel obtained through a mutual assistance agreement, or otherwise;(i) Pruning and trimming of vegetation, removal of downed trees and tree limbs, and removal of storm debris other than vegetation;(j) Replacement of downed poles and wires;(k) External communications, including communications with the: (1) Utility's customers, the public at large, and other interested persons;(2) District's emergency responders, emergency management and communication officials, and transportation officials;(3) Commission's members and designated staff;(4) District's elected officials;(5) District Advisory Neighborhood Commission members;(6) District's Office of the People's Counsel;(7) Telecommunication or cable service providers owning overhead wires or antennae attached to the utility's poles located in the District; and(8) District's Urban Forestry Administration;(l) Internal communications;(m) Communications technology use, including high call volume capability and capacity; use of social media; use of radio, television, and the print media; and use and functionality of the utility's website;(n) Development and communication of estimated times of restoration and assessment of estimated times of restoration accuracy, both during and subsequent to the Major Service Outage;(o) Ramp-down and post-event inspection and reporting; and(p) A Major Service Outage Restoration Plan performance assessment model describing the manner in which the utility shall, within sixty (60) days following the completion of its power restoration following a Major Service Outage, evaluate and report upon its performance under each of the criteria included in its Major Service Outage Restoration Plan.3603.18 The utility shall file with the Commission any material changes to its Major Service Outage Restoration Plan at least sixty (60) days prior to implementation, unless such timing will delay implementation of the change in a manner inconsistent with restoring service in the shortest time practicable, in which case the change shall be filed no later than thirty (30) days after implementing the change. Filings on the Major Service Outage Restoration Plan shall be filed with the Commission's Service Outages ("SO") docket.
D.C. Mun. Regs. r. 15-3603
Final Rulemaking published at 54 DCR 9376 (September 28, 2007); as amended by Final Rulemaking published at 55 DCR 1943 (February 29, 2008); as amended by Notice of Final Rulemaking published at 58 DCR 6026 (July 22, 2011); as amended by Notice of Final Rulemaking published at 59 DCR 1598 (February 24, 2012); as amended by Final Rulemaking published at 59 DCR 8762, 8763 (July 27, 2012); amended by Final Rulemaking published at 69 DCR 3134 (4/8/2022); amended by Final Rulemaking published at 71 DCR 1722 (2/16/2024)Authority: The Public Service Commission of the District of Columbia (Commission) hereby gives notice, pursuant to section 34 -802 of the District of Columbia Official Code.