For local relays configured with all other communication cards i. Page 2, 3, and 4, to the upstream device that monitors a single incomer of the busbar, as shown below. Speed, reliability and cost should be taken into account when selecting the required architecture. The CRC Alarm function is available for monitoring the communication medium noise by tracking the rate of messages failing the CRC check.
The monitoring function counts all incoming messages, including messages that failed the CRC check. In the ring config- uration, all messages originating at a given device should return within a pre-defined period of time. The Unreturned Mes- sages Alarm function is available for monitoring the integrity of the communication ring by tracking the rate of unreturned messages. Page Installation This name will appear on generated reports.
If a protection element is set up to act on SRC 1 cur- rents, then a pickup level of 1 pu will operate on A primary. The same rule applies for current sums from CTs with different secondary taps 5 A and 1 A. For CT inputs, this is the nominal primary and secondary current. For VTs, this is the connection type, ratio and nominal secondary voltage.
Once the inputs have been specified, the configuration for each source is entered, including specifying which CTs will be summed together. Page 0. Loc data item. Page 5. Page Flexcurves 1, i. It is recommended to set the two times to a similar value; otherwise, the linear NOTE approximation may result in undesired behavior for the operating quantity that is close to 1.
Page Some types of operands are present in the relay in multiple instances; e. These types of oper- ands are grouped together for presentation purposes only on the faceplate display. The characteristics of the different types of operands are listed in the table below. Page Setting Group 5. If a pickup delay is not required, set this function to "0". If a dropout delay is not required, set this function to "0".
Page The element can be programmed to respond either to a signal level or to a rate-of-change delta over a pre-defined period of time. The output operand is asserted when the operating signal is higher than a threshold or lower than a threshold as per user's choice. Page The element operates if the positive-sequence voltage is above a settable level and asserts its output signal that can be used to block selected protection elements such as distance or phase overcurrent.
The following figure shows an effect of the Load Encroachment characteristics used to block the Quad distance element. Page If the voltage is below this threshold a blocking signal will not be asserted by the element. When selecting this setting one must remember that the F60 measures the phase-to-ground sequence voltages regardless of the VT connection.
Page 2 phase directional overcurrent elements. This allows for simplified coordination with downstream devices. If there is a requirement to supervise overcurrent elements for flows in opposite directions, such as can happen through a bus-tie breaker, two phase directional elements should be programmed with opposite ECA settings.
Page Therefore, a coordination time of at least 10 ms must be added to all the instantaneous protec- tion elements under the supervision of the Phase Directional element. If current reversal is of a concern, a longer delay — in the order of 20 ms — may be needed.
Page The reverse-looking function is designed to be faster as compared to the forward- looking function and should be used for the blocking direction. This allows for better protection coordination. The polarizing voltage can be programmed to be either the zero-sequence voltage calculated from the phase voltages "Calculated V0" or supplied externally as an auxiliary voltage "Measured VX". Page The conversion range of a standard channel is from 0. The conversion range of a sensitive channel is from 0.
Page This allows for better protection coordination. Page Range: 0. Page This can also occur in breaker-and-a-half or ring bus configurations where the first breaker closes into a fault; the protection trips and attempts to initiate breaker failure for the second breaker, which is in the process of closing, but does not yet have current flowing through it. Page In microprocessor relays this time is not significant. In F60 relays, which use a Fourier transform, the calculated current magnitude will ramp-down to zero one power frequency cycle after the current is interrupted, and this lag should be included in the overall margin duration, as it occurs after current interruption.
Page 1-pole breaker failure schemes. CDR A5. The element has two independent as to the pickup and delay settings stages for alarm and trip, respectively. Page Selector Switch 1 A user-programmable pushbutton is typically configured as the acknowledging input. Page The selector position pre-selected via the stepping up control input has not been confirmed before the time out.
The supervising function responds to the positive-sequence current. Typical application includes load shedding. Set the pickup threshold to zero if no overcurrent supervision is required. This time can be calculated by: - EQ 5. Page The relay will use the phase channel of a three-phase set of voltages if pro- grammed as part of that source. The relay will use the auxiliary voltage channel only if that channel is programmed as part of the Source and a three-phase set is not.
Page Autoreclose 1 4. This timer must be set to a delay less than the reset timer. Page Some versions of the digital input modules include an active voltage monitor circuit connected across Form-A contacts. The voltage monitor circuit limits the trickle current through the output circuit see technical specifications for Form-A.
All counter operands are blocked. The relay maintains four captures of records each. The capture frequency is 1 Hz and the data collected is defined in the following two tables.
The rate-of-change is calculated as the difference between two consecutive two-cycle RMS readings. The recommended setting is A per two-cycle interval. The setting is given in primary amperes. Page For the first three to five days after installation or after being out-of-service for a sig- NOTE nificant period , the F60 may identify some of this noise as arcing.
This should be taken into account when responding to alarms during these type of operating periods. Page Voltage drop measured from either side of the breaker during the flashover period, Voltage difference drop, and Measured flashover current through the breaker.
Furthermore, the scheme is applicable for cases where either one or two sets of three-phase voltages are available across the breaker. Page This application do not require detection of breaker status via a 52a contact, as it uses a voltage difference larger than the setting. However, monitoring the breaker contact will ensure scheme stability.
Page Supervision can be provided by operation of other protection elements, breaker failure, and close and trip commands. Page An additional condition is introduced to inhibit a fuse failure declaration when the monitored circuit is de-energized; positive sequence voltage and current are both below threshold levels. Page Cold Load Pickup 1 During the cold load condition, the current level can be above the pickup setting of some protection elements, so this feature can be used to prevent the tripping that would otherwise be caused by the normal settings.
Page The DC input voltage is compared to a user-settable threshold. A new contact input state must be maintained for a user- settable debounce time in order for the F60 to validate the new contact state. In the figure below, the debounce time is set at 2.
As such they retain their position even if the relay is not powered up. The relay recognizes all latching output contact cards and pop- ulates the setting menu accordingly. Page Remote Inputs Logic 0. When communication resumes, the input becomes fully operational. The scheme output operand is used to key the permission. Page In three-terminal applications, both the remote terminals must grant permission to trip.
Page On 3-terminal system or 2-terminal same for Intermediate values between the min and max values are scaled linearly. Each channel is assigned a slot letter followed by the row number, 1 through 8 inclusive, which is used as the channel number. Both the output range and a signal driving a given output are user-programmable via the following settings menu an exam- ple for channel M5 is shown.
The nominal current is A primary and the nominal power factor is 0. Page 0 to 1 mA. The VT secondary setting is Page Page See page This number will rollover to zero when a count of 4,,, is incremented. This, however, is a relative matter.
Page The effective operating quantities of the sensitive directional power elements are displayed here. The currents from the local and remote systems can be parted between their fault F and pre-fault load pre components: EQ 6. Page Event Records It counts up at the defined sampling rate. If Data Logger channels are defined, then both values are static. Refer to the menu for clearing data logger records.
A modification file number of 0 indicates that, currently, no modifications have been installed. Page If an update occurs, the following message is shown. Refer to the settings in the User-Programmable Self-Tests section in Chapter 5 for additional details. Contact the factory. Event driven. Page Theory Of Operation 50 Hz system, it consists of a sum of the 25, 75, , If the Energy Algorithm detects a sudden, sustained increase in one of these component energies, it reports this to the Expert Arc Detector algorithm, resets itself, and continues to monitor for another sudden increase.
Page Load Analysis Algorithm The duration over which the algorithm inhibits the setting of the overcurrent flag s is from the time the even-harmonic level as a percentage of RMS increases above the threshold until one second after it falls back below the threshold. Also the High Impedance Oscillography will record that a voltage dip was experienced. The Oscillography record is phase specific. Page Introduction Broadcast mode is only recognized when associated with Function Code 05h.
For any other function code, a packet with broadcast mode slave address 0 will be ignored. Page File Transfers Cleared Date to the present date and time. The file name is faultReport.
The refers to the fault report record number. The fault report number is a counter that indicates how many fault reports have ever occurred. Repeated for Digital Counter 7 Repeated for Source 2 1C Repeated for Source 3 1C Repeated for Source 4 1C Repeated for Source 2 1EC Repeated for Source 3 1EE Secondary Winding.
Nov 17, The content of this manual is for informational use only and is subject to change without notice. Part numbers contained in this manual are Interruptions to alternating components ripple in DC auxiliary energizing quantity of measuring relays. No part of this manual shall be copied, reproduced, or transmitted in any way without the prior, written consent of.
The version 4. B30 Bus Differential Relay. C30 Controller. C60 Breaker Management Relay. Parameter group for configuring timing and output functions for relays. No Operation. Default for all digital and relay outputs. In this part of the manual the operating instructions and maintenance is supplied. Single Wire Earth Return S. R Distribution networks were installed by Electrical. Distribution entities to distribute power to customers who are remote from Zone.
Substations and have a low energy demand. As is common with typical distribution systems, S. Page Feeder Protection with Hi-Z Fault. Comprehensive feeder protection, control, advance communications, monitoring and Multilin Universal Relay to provide Ethernet connectivity to the relay as well as other Ethernet-enabled devices. Team is one component of the acSELerator Software family, which helps you work more efficiently and manage processes by providing a common set of tools that improve commissioning and collaboration.
Using Team, engineers and technicians can continuously monitor an entire system and quickly gather event or Sep 1, Fig 3 shows a single line diagram of a Parallel to Utility system with two generators Cogen application. The F60, a member of the UR Family of protection relays, provides high performance feeder protection, control, monitoring and metering in an integrated, economical, and compact package.
The F60 feeder protection system provides feeder protection, control, monitoring and metering in an integrated, economical, and compact package. The F60 incorporates a unique and matured algorithm to detect high-impedance faults such as downed conductor detection. It also provides fast and deterministic execution of programmable logic necessary for substation automation applications. Graphical programming tools Viewpoint Engineer , supported by a library of logic components, make the F60 simple to use and configure.
The F60 has a wide range of protection elements that have many years of proven field experience. The D30 is the single point for protection, control, metering, and monitoring in one integrated device that can be easily connected directly to HMI or SCADA monitoring and control systems.
The D30 integrates seamlessly with other UR relays for complete system protection. The F60 provides advanced communications technologies for remote data and engineering access, making it easy and flexible to use and integrate into new and existing infrastructures.
Direct support for fiber optic Ethernet provides high-bandwidth communications allowing for low-latency controls and high-speed file transfers of relay fault and event record information.
The available three independent and redundant Ethernet options provide the means to create fault tolerant communication architectures in an easy, cost-effective manner. The F60 supports the most popular industry standard protocols enabling easy, direct integration into monitoring and SCADA systems.
Use the F60 with integrated IEC to lower costs associated with feeder protection, control and automation.
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