IEEE 1782:2014 pdf free download – IEEE Guide for Collecting, Categorizing, and Utilizing Information Related to Electric Power Distribution lnterruption Events
4.1 Overview
lt is generally accepted that in today’s operating environment，utilities need to accurately captureinformation regarding the number of service interruptions，their duration,and the number of customersaffected (Robinson ct al. [B2]). Most utilities，including investor-owned，municipal，and co-operativeutilities， have realized the need to capture equipment outages and the resulting customer interruptions;nearly all capture sustained interruptions. The methods and approaches vary widely depending on theexistence and sophistication of installed information systems such as the customer information system(CIS),the geographic information system (GIS),the supervisory control and data acquisition system(SCADA), and the outage management system (OMS). In general, a utility’s interruption reporting systemuses key information from these systems to improve the completeness and accuracy of reliabilityinformation.
Comparing reliability statistics between utilities is a difficult task because of so many factors, not the leastof which is differing data collection processes and procedures.During the benchmarking process,it isimperative that consideration be given to the level of data collection and the state of implementation ofthese systems and their associated processes.Even among utilities that have similar systems, such as anoutage management system from a specific vendor, performance differences are likely to occur, due eitherto customization for an individual utility andor process differences，and those differences may besignificant. Without such consideration, comparison of performance will be inexact.
4.2 Manual collection systems
Typically，a utility with paper maps and little or no connectivity records will utilize a fully manualcollection approach.Field personnel estimate the number of customers affected during a serviceinterruption. Utilities couple these estimates with an estimate of the beginning time of the serviceinterruption to determine the impact of each event on customers.This approach may be the least accurateapproach of the methods that will be discussed in this guide. It is the one that forms the starting point formost utilities in their evolution to a fully connected system, as most utilities began collecting reliabilityperformance information as a consequence of building a system to assist with quicker power restoration.
The data collected with these systems helps that utility identify and track areas on the systems that havereliability concerns. These concerns could include repeated interruptions and potentially poor customersatisfaction.Generally, the manual reporting system tracks only sustained interruptions and does not recordthe momentary interruptions. In utilizing this method, step restoration efforts are very difficult to trackproperly; specifically the customer minutes of interruption are not reduced correctly.
Without a fully connected model that provides the connectivity of each customer to the protective devicesupstream on the feeder,utility staff must manually group individual customer calls (tickets) by area andthen provide this information to field personnel for restoration. Using this approach may result in customerssupplied through different devices being grouped together incorrectly， thereby extending the restorationtime. In this case, the field personnel have to contact each customer to make sure everyone is restored withthe resolution of the outage. If it is assumed everyone in the area has had service restored, then somecustomers may need to call back to report their continued interruption.