SUBSTATION AUTOMATION

AND

LINE&DISTANCE PROTECTION BY IED REL670Substation automation is composed of several tasks.

Data acquisitionData acquisition refers to acquiring, or collecting, data. This data is collected in the form of measured analog current or voltage values or the open or closed status of contact points. Acquired data can be used locally within the device collecting it, sent to another device in

a substation, or sent from the substation to one or several databases for use by operators, engineers, planners, and administration

SupervisionComputer conditions Operators computer device, on processes and personnel supervise, or monitor, the and statuof the power system using this acquired data. and engineers monitor the information remotely on displays and graphical wall displays or locally, at the front-panel displays and laptop computers.

ControlControl refers to sending command messages to a device to operate the I&C and power system devices. Traditional supervisory control and data acquisition (SCADA) systems rely on operators to supervise the system and initiate commands from an operator console on the master computer. Field personnel can also control devices using front-panel push buttons or a laptop computer.

In addition, another task is power system integration, which is the act of communicating data to, from, or among IEDs in the I&C system and remote users. Substation integration refers to combining data from the IEDs local to a substation so that there is a single point of contact in the substation for all of the I&C data.

400kv substation over viewThe over view of a general 400kv substation is shown in the fig.

1.Primary power lines 2.Ground wire 3.Overhead lines 4.Transformer for measurement of electric voltage 5.Disconnect switch 6.Circuit breaker 7.Current transformer 8.Lightning arrester

9.Main transformer 10.Control building 11.Security fence 12.Secondary power lines

wave trap1. Wave trap are used in power system for carrier communication. 2. It trap the higher frequency above 50Hz. 3. It is the effort to utilize the same transmission line between two substation for the purpose of communication

IsolatorAn isolators switch are used to completely de-energized an electrical circuit. High-voltage isolation switches are used in electrical substations to allow isolation of apparatus such as circuit breakers and transformers, andtransmission lines, formaintenance.

INSTRUMENT TRANSFORMERSThe current transformer and voltage transformer are combinly called as instrument transformer.

The main tasks of instrument transformers are:- To transform currents, or voltages, from a high value to a value easy to handle for relays and instruments. - To insulate the metering circuit from the primary high voltage. - To provide possibilities of a standardization, concerning instruments and relays, of rated currents and voltages.

VOLTAGE TRANSFORMER (VT) AND CAPACITIVE VOLTAGE TRANSFORMER (CVT)Voltage transformers can be of two types, magnetic voltage transformers (VT) and capacitive voltage transformers (CVT). The magnetic voltage transformers are most economical for voltages up to about 145 kV and the capacitive voltage transformers there above. A CVT can also be combined with the PLC equipment used for communication over the high voltage transmission lines. Voltage transformers are in most cases connected between phase and earth. The secondary winding of the cvt is always open circuited.

Location The location of the voltage transformers will primary depend on the switchgear arrangement, the protection, the metering and the automatics connected. Normally, voltage transformers connected to the busbars and at the low voltage side of the transformers are satisfactory in a distribution Substation .Directional Protection on outgoing bays are then fed from the busbar VT:s.

CURRENT TRANSFORMERSLocation The location of the current transformers will give the limitation of the protection zones. The most common approach is to locate the current transformer at the outside of the object circuit breaker, so that a Busbar differential protection will cover the circuit breaker. The location should generally be as close as possible to the circuit breaker as the breaker will open when a fault is detected. For lower voltages where busbar protection is not used, a location of the current transformer to between the breaker and the busbar could be advantageous but is usually impossible to do due to the mechanical construction. The secondary side of the current transformer is always short circuited.

Circuit breakerA circuit breaker is an automatically-operated electrical switch designed to protect an electrical circuit from damage caused byoverload or short circuit.

Lightning arresterThe overvoltage protection is obtained by the use of lightning / surge arresters. Lightning Arresters or Surge Arresters are always connected in Shunt to the equipment to be protected. They provide a low impedance path for the surge current to the ground. Mostly in present days zinc oxide (ZnO) gapless arresters are in useT

CVT INTRODUCTION TO IEDS Intelligent Electronic Device = IED

ALL MAJOR APPLICATIONS OF IED 670Overhead lines Underground cables Multi terminal Circuits Transformers & Reactors

Generators & Large Machines Busbar & Breaker Composite Objects High Voltage Switchgear s

A generic name for all protection and control devices with IEC61850. All products are named according the application .RED 670 Multi-terminal Line differential protection IED REL 670 Line Distance protection IED RET 670 Transformer protection IED REC 670 Bay control IED REB 670 Busbar protection REG 670 Generator protection IED

IED 670 Local Human Machine Interface

IED REL670 REL 670 line distance protection IED(Intelligent electronic device) offer extensive protection application opportunities for overhead lines and cables,or combinations of overhead lines and cables. They feature full scheme distance protection with selective single-phase and three-phase tripping and autoreclosing with synchronizing and synchrocheck, power swing detection and a wide range of scheme communication logics. The IEDs with five zone distance protection for phase-to-phase and phase-to-earth faults enable youto protect transmission and sub-transmission lines and cables in impedance or solidly earthed networks. The IEDs are also equipped with residual overcurrent protection

functions and a wide range of scheme communication logics that enable detection and fault clearance of high resistive earth faults.

SpecificationsThe REL 670 IED (Intelligent Electronic Device) is designed for protection, monitoring and control of overhead lines and cables. It provides an extensive functionality with configuration opportunities and expandable hardware to meet your specific requirements. This powerful IED provides distance protection for a complete double circuit, parallel operating line. REL 670 features full scheme distance protection with independent phase selection,power swing detection and a wide range of scheme communication logics. Furthermore, REL 670 allows you to protect

and control several objects, for instance line and a transformer with one single IED. The REL 670 IEDs are delivered pre-configured, type tested and set with default parameters for fast and efficient commissioning. These IEDs are equipped with complete functionality adapted for four different configuration alternatives: single pole breaker or multibreaker arrangement with single or three phase tripping. If needed, they can also be easily adapted to meet the specific requirements of your power system. Furthermore you can increase the functionality of your REL 670 IEDs with optional protection and control functions. The wide application flexibility makes these IEDs an excellent choice for both new and retrofit installations. REL 670 provides protection of power lines with high sensitivity and low requirement on remote end communication. Measurements and setting of all five zones with six setting groups are made completely independently, which ensures high reliability for all types of lines. The distance and earth-fault protection functions can communicate with remote end in any communication scheme. It offers full control and interlocking functionality required for control of apparatuses in a substation. The integrated HMI allows secure and quick local control for stand-alone applications and provides back-up control for substation automation systems. REL 670 features extensive functionality and expandable I/O, which enables applications with multiple algorithms, multiple objects, integrated and distributed architectures. Thus, REL 670 provides efficient substation automation solutions in terms of performance, redundancy and cost for any high voltage application. REL 670 provides solutions for your protection, control and monitoring. REL 670 provides improved availability through outstanding performance and efficient information management REL 670 enables significant savings in configuration, setting, erection, commissioning and maintenance cost ce requirements

Extensive Application OpportunitiesEHV & HV lines and cables Long lines Short lines Series compensated High resistive faults 1 12 and 2 breaker arrangement Multi object capability in single IED Line and transformer Dual distance protection for back-up of additional line.

IED REL670 Local Human Machine InterfaceHMI(Human machine interface)The local human machine interface is available in a small, and a medium sized model. The principle difference between the two is the size of the LCD. The small size LCD can display seven line of text and the medium size LCD can display the single line diagram with up to 15 objects on each page. Six SLD pages can be defined. The local human machine interface is equipped with an LCD that can display the single line diagram with up to 15 objects. The local human-machine interface is simple and easy to understand the whole front plate is divided into zones, each of them with a well-defined functionality

Large size HMI Easy navigation with easy to understand push-buttons 15 LEDs freely programmable Flashing or permanent light Signal following Latched mode Single line diagram for control and supervision

Settings Disturbance information Self supervision Standard RJ45 connector to PC with toolbox (with indication communication).

Front panel of IED REL 670

1 Status indication LEDs 2 LCD 3 Indication LEDs 4 Label 5 Local/Remote LEDs 6 RJ45 port 7 Communication indication LED 8 Keypad

IED REL 670status indication LEDsGreenSteady: Flashing: Dark : In service Internal failure No power supply

YellowSteady: Flashing: Disturbance recorder triggered IED in test mode

Red

Steady: Flashing:

Trip command issued IED blocked

** KEYPADThe keypad is used to monitor and operate the IED. The keypad has the same look and feel in all IEDs in the IED 670 series. LCD screens and other details may differ but the way the keys function is identica

Thiskeycloses(energizes)abreakerordisconnector.

Thiskeyopensabreakerordisconnector.

Thehelpkeybringsuptwosubmenus.KeyoperationandIED information. Thiskeyisusedtoclearentries,Itcancelscommandsandedits.

Opensthemainmenu,andusedtomovetothedefaultscreen.

TheLocal/RemotekeyisusedtosettheIEDinlocalorremote controlmode. Thiskeyopenstheresetscreen.

TheEkeystartseditingmodeandconfirmssettingchangeswhenin editingmode. Therightarrowkeynavigatesforwardbetweenscreensandmoves rightineditingmode. Theleftarrowkeynavigatesbackwardsbetweenscreensandmoves leftineditingmode. Theuparrowkeyisusedtomoveupinthesinglelinediagramand inmenutree.

Thedownarrowkeyisusedtomovedowninthesingleline diagramandinmenutree.

features

Typical operate time: One cycle

Fully IEC 61850 compliant Protection, monitoring and control integrated in one IED Extensive self-supervision including analog channels Six independent parameter setting groups Large HMI for visualization of single line diagrams Ethernet interface for fast and easy communication with PC Signal matrix for easy configuration of binary and analog signalsUser management and authority handling . Auto-reclosing function for single two-and/or three-phase reclosing. Powerful software pc tool for setting,distrubence evaluation and configuration. Full scheme phase-to-phase andphase-to-earth distance protection with up to five zones. Six independent groups of complete setting parameters with password protection.

Load enchroachment feature. Advanced phase selection. Complete software library for all applications. Low requirement of CT.

Monitoring Disturbance recorder - 100 disturbances - 40 analog channels (30 physical and 10 derived) - 96 binary channels Event list for 1000 events Disturbance report Event and trip value recorders Fault locator Event counters Supervision of AC and mA input quantities Small and large HMI in local language LED indications with 6 red and 9 yellow LEDs

Metering U, I, P, Q, S, f, and cos Differential voltage per zone AC input quantities with accuracy better than 0.5% Inputs for mA measuring Energy metering function for energy statistics Pulse counting support for energy metering

Available functions.The functions which are available in IED REL 670 are listed below

1.Differential protectionHigh impedance differential protection (PDIF, 87) (87 ANSI,PDIF functionality discription)

The high impedance differential protection can be used when the involved CT cores have same turn ratio and similar magnetizing characteristic. It utilizes an

external summation of the phases and neutral current and a series resistor and a voltage dependent resistor externally to the relay.

2.Distance protection Distance protection zones (PDIS, 21)The line distance protection is a five zone full scheme protection with three fault loops for phase to phase faults and three fault loops for phase to earth fault for each of the independent zones. Individual settings for each zone resistive and reactive reach gives flexibility for use on overhead lines and cables of different types and lengths.The function has a functionality for load

encroachment which increases the possibility to detect high resistive faults on heavily loaded linesThe distance protection zones can operate, independent of each other, in directional (forward or reverse) or non-directional mode. This makes them suitable, together with different communication schemes, for the protection of power lines and cables in complex network configurations, such as parallel lines, multi-terminal lines etc.

3.Power swing detection (RPSB, 78)Power swings may occur after disconnection of heavy loads or trip of big generation plants.Power swing detection function is used to detect power swings and initiate block of selected distance protection zones. Occurrence of earth fault currents during a power swing can block the power swing detection function to allow fault clearance.

Power Swing detection is based on the measurement of the time for the transient impedance to pass between the outer and inner impedance characteristic Power Swing Detection function block. This signal will block impedance

4.Automatic switch onto fault logic (PSOF)Automatic switch onto fault logic is a function that gives an instantaneous trip at closing of breaker onto a fault. A dead line detection check is provided to activate the function when the line is dead.

SOTF is a basic protection function which enables instantaneous trip at closing of breaker. Non directional to cover zero voltage due to forgotten earthing switch.

Two versions of protection functions are available in SOTF. 1.A binary input (bc) which releases the SOTF overreaching zone at breaker closing command . 2.Internal measurement detects that no voltage and no current is available for a certain time(DLD). The instantaneous, non directional measurement is then activated internally.

5.Current protectionInstantaneous phase overcurrent protection (PIOC, 50)The instantaneous three phase overcurrent function has a low transient overreach and short tripping time to allow use as a high set short-circuit protection function, with the reach limited to less than typical eighty percent of the power line at minimum source impedance.

Four step phase overcurrentThe four step phase overcurrent function has an inverse or definite time delay independent for each step separately. All IEC and ANSI time delayed characteristics are available together with an optional user defined time characteristic. The function can be set to be directional or non-directional independently for each of the steps.

Instantaneous residual overcurrent protection (PIOC, 50N)

The single input overcurrent function has a low transient overreach and short tripping times to allow use as a high set short circuit protection function, with the reach limited to less than typical eighty percent of the power line at minimum source impedance. The function can be configured to measure the residual current from the three phase current inputs or the current from a separate current input.

Four step residual overcurrent protection (PEFM, 51N/67N)The four step single input overcurrent function has an inverse or definite time delay independent for each step separately. All IEC and ANSI time delayed characteristics are available together with an optional user defined characteristic. The function can be set to be directional, forward, reverse or non-directional independently for each of the steps. A second harmonic blocking can be set individually for each step. The function can be used as main protection for phase to earth faults. The function can be used to provide a system back-up e.g. in the case of the primary protection being out of service due to communication or voltage transformer circuit failure. Directional operation can be combined together with corresponding communication blocks into permissive or blocking teleprotection scheme. Current reversal and weak-end infeed functionality are available as well. The function can be configured to measure the residual current from the three phase current inputs or the current from a separate current input.

6.Voltage protection Two step under voltage protection (PUVM, 27)Under voltages can occur in the power system during faults or abnormal conditions. The function can be used to open circuit breakers to prepare for system restoration at power outages or as long-time delayed back-up to primary protection. The function has two voltage steps, each with inverse or definite time delay.

Two step overvoltage protection (POVM, 59)Over voltages will occur in the power system during abnormal conditions such as sudden power loss, tap changer regulating failures, open line ends on long lines. The function can be used as open line end detector, normally then combined with directional reactive over-power function or as system voltage supervision, normally then giving alarm only or switching in reactors or switch out capacitor banks to control the voltage. The function has two voltage steps, each of them with inverse or definite time delayed. The overvoltage function has an extremely high reset ratio to allow setting close to system service voltage.

Two step residual overvoltage protection (POVM, 59N)Residual voltages will occur in the power system during earth faults. The function can be configured to calculate the residual voltage from the three phase voltage input transformers or from a single phase voltage input transformer fed from an open delta or neutral point voltage transformer. The function has two voltage steps, each with inverse or definite time delayed.

7.Thermal overload protection, one time constant (PTTR, 26)The increasing utilizing of the power system closer to the thermal limits have generated a need of a thermal overload function also for power lines. A thermal overload will often not be detected by other protection functions and the introduction of the thermal overload function can allow the protected circuit to operate closer to the thermal limits. The three phase current measuring function has an I2t characteristic with settable time constant and a thermal memory. An alarm level gives early warning to allow operators to take action well before the line will be tripped

8.Breaker failure protection (RBRF, 50BF)The circuit breaker failure function ensures fast back-up tripping of surrounding breakers. The breaker failure protection operation can be current based, contact based or adaptive combination between these two principles. A current check with extremely short reset time is used as a check criteria to achieve a high security against unnecessary operation. The breaker failure protection can be single- or three-phase started to allow use with single phase tripping applications. For the three-phase version of the breaker failure protection the current criteria can be set to operate only if two out of four e.g. two phases or one phase plus the residual current starts. This gives a higher security to the back-up trip command .The function can be programmed to give a single or three phase re-trip of the own breaker to avoid unnecessary tripping of surrounding breakers at an incorrect starting due to mistakes during testing.

9.Frequency protectionUnder frequency protection (PTUF, 81)Under frequency occurs as a result of lack of generation in the network .The function can be used for load shedding systems, remedial action schemes, gas turbine start-up etc. The function is provided with an under voltage blocking. The operation may be based on single phase, phase-to-phase or positive

sequence voltage measurement. Up to two independent under frequency function instances are available.

Over frequency protection (PTOF, 81)Overfrequency will occur at sudden load drops or shunt faults in the power network. In some cases close to generating part governor problems can also cause overfrequency. The function can be used for generation shedding, remedial action schemes etc. It can also be used as a sub-nominal frequency stage initiating load restoring. The function is provided with an undervoltage blocking. The operation may be based on single phase, phase-to-phase or positive sequence voltage measurement. Up to two independent over frequency function instances are available.

Rate-of-change frequency protection (PFRC, 81)Rate of change of frequency function gives an early indication of a main disturbance in the system. The function can be used for generation shedding, load shedding, remedial action schemes etc. The function is provided with an undervoltage blocking. The operation may be based on single phase, phase-to-phase or positive sequence voltage measurement. Each step can discriminate between positive or negative change of frequency. Up to two independent rate-of-change frequency function instances are available.

Control10.Synchrocheck and energizing check (RSYN, 25)The synchro check function checks that the voltages on both sides of the circuit breaker are in synchronism, or with at least one side dead to ensure that closing can be done safely.The function includes a built-in voltage selection scheme for double bus and one- and a half or ring busbar arrangements. Manual closing as well as automatic reclosing can be checked by the function and can have different settings, e.g. the allowed frequency difference can be set to allow wider limits for the auto-reclose attempt than for the manual closing.

11.Auto recloser (RREC, 79)The auto reclosing function provides high-speed and/or delayed auto-reclosing for single or multi-breaker applications. Up to five reclosing attempts can be programmed. The first attempt can be single-, two and/or three phase for single phase or multi-phase faults respectively. Multiple auto reclosing functions are provided for multi-breaker arrangements. A priority circuit allows one circuit

breaker to close first and the second will only close if the fault proved to be transient. Each auto reclosing function can be configured to co-operate with a synchro check function.

12.Disturbance report (RDRE)Complete and reliable information about disturbances in the primary and/or in the secondary system together with continuous event-logging is accomplished by the disturbance report functionality. The disturbance report, always included in the IED, acquires sampled data of all selected analogue input and binary signals connected to the function block i.e. maximum 40 analogue and 96 binary signals. The disturbance report functionality is a common name for several functions: Event List (EL) Indications (IND) Event recorder (ER) Trip Value recorder (TVR) Disturbance recorder (DR) Fault Locator (FL) The function is characterized by great flexibility regarding configuration, starting conditions, recording times and large storage capacity. A disturbance is defined as an activation of an input in the DRAx or DRBy function blocks which is set to trigger the disturbance recorder. All signals from start of pre-fault time to the end of post-fault time, will be included in the recording. Every disturbance report recording is saved in the IED in the standard Comtrade format. The same applies to all events, which are continuously saved in a ring-buffer. The Local Human Machine Interface (LHMI) is used to get information about the recordings, but the disturbance report files may be uploaded to the PCM 600 (Protection and Control IED Manager) and further analysis using the disturbance handling tool.

Event list (RDRE)The event list logs all binary input signals connected to the Disturbance report function. The list may contain of up to 1000 time-tagged events stored in a ring-buffer.

Indications (RDRE)To get fast, condensed and reliable information about disturbances in the primary and/or in the secondary system it is important to know e.g. binary signals that have changed status during a disturbance. This information is used in the short perspective to get information via the LHMI in a straightforward way. There are three LEDs on the LHMI (green, yellow and red), which will display status information about the IED and the Disturbance Report function (trigged). The Indication list function shows all selected binary input signals connected to the Disturbance Report function that have changed status during a disturbance.

Event recorder (RDRE)Quick, complete and reliable information about disturbances in the primary and/or in the secondary system is vital e.g. time tagged events logged during disturbances. This information is used for different purposes in the short term (e.g. corrective actions) and in the long term (e.g. Functional Analysis). The event recorder logs all selected binary input signals connected to the Disturbance Report function. Each recording can contain up to 150 time-tagged events.The event recorder information is available for the disturbances locally in the IED. The event recording information is an integrated part of the disturbance record (Comtrade file)

Trip value recorder (RDRE)Information about the pre-fault and fault values for currents and voltages are vital for the disturbance evaluation. The Trip value recorder calculates the values of all selected analogue input signals connected to the Disturbance report function. The result is magnitude and phase angle before and during the fault for each analogue input signal. The trip value recorder information is available for the disturbances locally in the IED. The trip value recorder information is an integrated part of the disturbance record

Disturbance recorder (RDRE)The Disturbance Recorder function supplies fast, complete and reliable information about disturbances in the power system. It facilitates understanding system behavior and related primary and secondary equipment during and after a disturbance. Recorded information is used for different purposes in the short perspective (e.g. corrective actions) and long perspective (e.g. Functional Analysis). The Disturbance Recorder acquires sampled data from all selected analogue input and binary signals connected to the Disturbance Report function (maximum 40 analog and 96 binary signals). The binary signals are the same signals as available under the event recorder function. The function is characterized by great flexibility and is not dependent on the operation of protection functions. It can record disturbances not detected by protection functions. The disturbance recorder information for the last 100 disturbances are saved in the IED and the Local Human Machine Interface (LHMI) is used to view the list of recordings.

Event function (EV)When using a Substation Automation system with LON or SPA communication, time-tagged events can be sent at change or cyclically from the IED to the station level. These events are created from any available signal in the IED that is connected to the Event function block. The event function block is used for LON and SPA communication. Analog and double indication values are also transferred through the event block.

Fault locator (RFLO)

The accurate fault locator is an essential component to minimize the outages after a persistent fault and/or to pin-point a weak spot on the line. The built-in fault locator is an impedance measuring function giving the distance to the fault in percent, km or miles. The main advantage is the high accuracy achieved by compensating for load current and for the mutual zero sequence effect on double circuit lines. The compensation includes setting of the remote and local sources and calculation of the distribution of fault currents from each side. This distribution of fault current, together with recorded load (pre-fault) currents, is used to exactly calculate the fault position. The fault can be recalculated with new source data at the actual fault to further increase the accuracy. Specially on heavily loaded long lines (where the fault locator is most important) where the source voltage angles can be up to 35-40 degrees apart the accuracy can be still maintained with the advanced compensation included in fault locator.

IEC 61850 COMMUNICATIONInternational electromecanical comisson(IEC)is getting popularity all over the world for flexible data communication across the IEDs in an electric power substation..Substation automation is done by the IEC 61850 standerd to interoperability among various IEDs.This standard ensures the interoperability among various substation automation components supplied by different vendors. The IEC 61850 standard ensures that all devices within power and energy system architectures can communicate with all the electronic devices (IEDs) in the process layer. In this application, the computing platforms, control platform and protocol gateways are the most critical devices to fulfill this interoperability. Redundant Managed Ethernet switches provide this interconnection between the substation and power system which is critical to improve reliability,

efficiency, and productivity. The IEC 61850-3 standard for power and energy communication networks and systems guarantees reliable performance in the critical environments these applications are based,guaranteeing certain levels of EMI immunity and interference resistance. Advantech's UNO-4672 computing platform is an advanced and flexible device to simplify substation system configuration, due to its ability to integrate gateways, controllers and servers into one station computer. They are expandable, support LAN redundancy and teaming functionality, feature a robust design and meet the IEC 61850-3 and IEEE 1613 requirements for substation-grade equipment. The result is a reduction in hardware which in turn reduces the overall failure rate of the system. Advantech's Managed Ethernet Switch, EKI-4654R, provides a reliable Ethernet backbone to realize redundant ring capabilities. Aside from its wide input power range (AC/DC), EKI-4654R provides dual redundant power modules to fulfill the high reliability and dependability requirements of substation network configuration.

IEC 61850 is the international standard that defines the hardware and communication requirements for all products within substation automation. IEC 61850 is being applied increasingly within substation automation, T&D automation, and grid integration applications. This standard ensures interoperability for the myriad of devices which comprise power and energy, especially between all of the intelligent electronic devices (IEDs) from different manufacturers.IEC 61850-3 is the hardware standard of general requirements ensures environmental and EMI immunity of network devices used in substations. Another standard for electronic power substations is IEEE 1613, detailing environmental and higher standard testing requirements for communications networking devices. Based on the IEC 61850-3 and IEEE 1613 certifications, Advantechs power and energy products ensure reliable communication and interconnectivity between the intelligent electronic devices (IEDs), the network components and the control platform.

Benefits* Fully interoperable system with IED 670 for protection and control Cost-efficient solution through full exploitation of IEDs functional capability including GOOSEbased functionality * High system availability with fully redundant operator workstations and independent gateways * Guaranteed system openness for future hardware and functional extensions through high-quality engineering .

AdvDistance2: . Test Object - Device Settings.Substation/Bay:

.. .

Substation: Bay:.Device:

Malkaram ghanapur 1

Substation address: Bay address:. .

Name/descripti REL670 on: Device type: REL670 Version 2

Manufacturer: Device address:

ABB

Serial/model number:

10914020

Additional info 1: Additional info 2:.Nominal Values:f nom: V nom (secondary): I nom (secondary): 50.00 Hz 110.0 V 1.000 A Number of phases: V primary: I primary: 3 220.0 kV 800.0 A

.

.

.Residual Voltage/Current Factors:VLN / VN: 1.732

.IN / I nom:

.1.000

.Limits:V max: 165.0 V

.I max:

.2.500 A

.Debounce/Deglitch Filters:Debounce time: 3.000 ms

.Deglitch time:

.0.000 s

.Overload Detection:Suppression time: 50.00 ms

.

.

Test Object - Other RIO Functions .CB ConfigurationDescription CB trip time CB close time 52a/b % Name CB trip time CB close time 52a/b % Value 50.00 ms 100.00 ms 20.00 %

Test Object - Distance Settings . .System parameters:Line length: PT connection: 0.000 at line

.Line angle: CT starpoint:

.79.06 Dir. line

Impedance correction 1A/I nom: No Impedances in primary values: No

. Tolerances:Tol. T rel.: Tol. T abs. +:

.

.

.

5.000 % 20.00 ms

Tol. T abs. -:

20.00 ms

Tol. Z rel.:

5.000 %

Tol. Z abs.:

50.00 m

Groundingfacto:Z0/Z1 mag.: Separate arc resistance: 1.000000 No Z0/Z1 angle: 0.000000

Zone Settings:Label Z1 L-L Z1 L-N Z2 L-L Z2 L-N Z3 L-L Z3 L-N Z4 L-L Z4 L-N Z5 L-L Z5 L-NVVVVV

Type Tripping Tripping Tripping Tripping Tripping Tripping Tripping Tripping Tripping Tripping

Fault loop Trip time L-L 35.00 ms L-E 35.00 ms L-L L-E L-L L-E L-L L-E L-L L-E 335.0 ms 335.0 ms 635.0 ms 635.0 ms 1.235 s 1.235 s 1.035 s 1.035 s

Tol.T rel 5.000 % 5.000 % 5.000 % 5.000 % 5.000 % 5.000 % 5.000 % 5.000 % 5.000 % 5.000 %

Tol.T abs+ Tol.T abs20.00 ms 20.00 ms 20.00 ms 20.00 ms 20.00 ms 20.00 ms 20.00 ms 20.00 ms 20.00 ms 20.00 ms 20.00 ms 20.00 ms 20.00 ms 20.00 ms 20.00 ms 20.00 ms 20.00 ms 20.00 ms 20.00 ms 20.00 ms

Tol.Z rel. 5.000 % 5.000 % 5.000 % 5.000 % 5.000 % 5.000 % 5.000 % 5.000 % 5.000 % 5.000 %

Tol.Z abs 50.00 m 50.00 m 50.00 m 50.00 m 50.00 m 50.00 m 50.00 m 50.00 m 50.00 m 50.00 m

Linked XRIO ReferencesReference Name RIO.DEVICE.NOMINALVALUE S.INOM Unit In Valu e 1.00 A XRIO Path RIO/Devic e/Nominal Values/In

Comment

.

Test ModuleName: Test Start: User Name: Company: OMICRON Advanced Distance 20-Oct-2010 16:10:56 SATYA APTRANSCO Version: Test End: Manager:

Test Settings.Test model:Test model: Allow reduction of ITest/VTest: ZS mag.: kS mag.: constant test current No 0.000 1.000 ITest kS = kL: ZS angle: kS angle:

.Fault Inception:Mode: DC-offset: Random No

.Times:Prefault: Postfault: 1.000 s 500.0 ms Max. fault: Time reference:

.Other:Extended zones: Load current enabled: not active No Switch off at zero crossing: Load current::

.Search Settings:Search res. Rel.: 1.000 % Search res. abs.: 50.00 m

Ignore nominal characteristics: No

Search interval: 200.0 M