TRANSMISSION & DISTRIBUTION TECHNOLOGY
NovaTech Bitronics DGM
DME WITH A DIFFERENCE The latest in disturbance monitoring equipment (DME) is a
novel concept that provides utilities with an economical retrofit solution to comply with upcoming requirements
U
tilities in the USA are facing an upcoming 2022 deadline from the North American Electric Reliability Corporation (NERC) to fully comply with an updated protection and control standard (PRC-002-2) for disturbance monitoring and reporting requirements for transmission and generation systems. Te first milestone is 50% compliance by January 1, 2021, followed by 100% compliance by July 1, 2022.
Te objective is to be able to standardise
regional reliability requirements and requires utilities to install disturbance monitoring equipment (DME). Te data collected by this equipment enables NERC to conduct forensic analyses of power failures to detect the causes in order to improve the safety and reliability of power delivery management.
10
www.engineerlive.com
“Te NERC standard requires a continuous, high-resolution 10 day recording of up to nine measurements per line of per-phase volts and amps, total MW and MVARs, and frequency,” says Bryan Gehringer, senior application engineer at NovaTech, provider of the Bitronics meters and IED solutions deployed in over 1,200 US utilities. “In addition, disturbances of interest must be archived for three years.” DME, as defined in the PRC002- 02, must monitor sequence of events recording (SER), fault recording (FR) and dynamic disturbance recording (DDR) data. SER and FR functions are already well understood and widely deployed throughout the industry, but the DDR function is relatively new and generally available in more expensive digital fault recorders (DFRs).
Although the majority of 230kV and higher voltage substations are likely already constructed with DFRs, the requirement for DME placement is based on the MVA short-circuit capacity of the bus, and so includes some lines down to 100kV. Tat is a voltage level where DFRs are not typically part of the original design. In those locations, it may be necessary to add recording capability to an operational substation where there may not be room to retrofit a traditional DFR, and where pulling new CT, PT and I/O cables to one location would be a major undertaking. Traditional microprocessor-based
protective relays are also able to perform fault recording, but typically do not have the memory to monitor and store continuous flows of information for 10 days as required by the PRC standard.
Page 1 |
Page 2 |
Page 3 |
Page 4 |
Page 5 |
Page 6 |
Page 7 |
Page 8 |
Page 9 |
Page 10 |
Page 11 |
Page 12 |
Page 13 |
Page 14 |
Page 15 |
Page 16 |
Page 17 |
Page 18 |
Page 19 |
Page 20 |
Page 21 |
Page 22 |
Page 23 |
Page 24 |
Page 25 |
Page 26 |
Page 27 |
Page 28 |
Page 29 |
Page 30 |
Page 31 |
Page 32 |
Page 33 |
Page 34 |
Page 35 |
Page 36 |
Page 37 |
Page 38 |
Page 39 |
Page 40 |
Page 41 |
Page 42 |
Page 43 |
Page 44 |
Page 45 |
Page 46 |
Page 47 |
Page 48 |
Page 49 |
Page 50 |
Page 51 |
Page 52
