RCS-985G X Instruction Manual en Domestic General X R1.01 (En YJBH2041.0086.0002) [PDF]

Citation preview

RCS-985G Generator Protection Instruction Manual



NR Electric Co., Ltd.



RCS-985G Generator Protection



Preface Introduction This guide and the relevant operating or service manual documentation for the equipment provide full information on safe handling, commissioning and testing of this equipment. Documentation for equipment ordered from NR is dispatched separately from manufactured goods and may not be received at the same time. Therefore, this guide is provided to ensure that printed information normally present on equipment is fully understood by the recipient. Before carrying out any work on the equipment, the user should be familiar with the contents of this manual, and read relevant chapter carefully. This chapter describes the safety precautions recommended when using the equipment. Before installing and using the equipment, this chapter must be thoroughly read and understood.



Health and Safety The information in this chapter of the equipment documentation is intended to ensure that equipment is properly installed and handled in order to maintain it in a safe condition. When electrical equipment is in operation, dangerous voltages will be present in certain parts of the equipment. Failure to observe warning notices, incorrect use, or improper use may endanger personnel and equipment and cause personal injury or physical damage. Before working in the terminal strip area, the equipment must be isolated. Proper and safe operation of the equipment depends on appropriate shipping and handling, proper storage, installation and commissioning, and on careful operation, maintenance and servicing. For this reason, only qualified personnel may work on or operate the equipment. Qualified personnel are individuals who: 



Are familiar with the installation, commissioning, and operation of the equipment and of the system to which it is being connected;







Are able to safely perform switching operations in accordance with accepted safety engineering practices and are authorized to energize and de-energize equipment and to isolate, ground, and label it;







Are trained in the care and use of safety apparatus in accordance with safety engineering practices;







Are trained in emergency procedures (first aid).



Instructions and Warnings The following indicators and standard definitions are used:



NR ELECTRIC CO., LTD



i



RCS-985G Generator Protection



DANGER! It means that death, severe personal injury, or considerable equipment damage will occur if safety precautions are disregarded. WARNING! It means that death, severe personal, or considerable equipment damage could occur if safety precautions are disregarded. CAUTION! It means that light personal injury or equipment damage may occur if safety precautions are disregarded. This particularly applies to damage to the device and to resulting damage of the protected equipment. WARNING! The firmware may be upgraded to add new features or enhance/modify existing features, please make sure that the version of this manual is compatible with the product in your hand. WARNING! During operation of electrical equipment, certain parts of these devices are under high voltage. Severe personal injury or significant equipment damage could result from improper behavior. Only qualified personnel should work on this equipment or in the vicinity of this equipment. These personnel must be familiar with all warnings and service procedures described in this manual, as well as safety regulations. In particular, the general facility and safety regulations for work with high-voltage equipment must be observed. Noncompliance may result in death, injury, or significant equipment damage. DANGER! Never allow the current transformer (CT) secondary circuit connected to this equipment to be opened while the primary system is live. Opening the CT circuit will produce a dangerously high voltage. WARNING! 



Exposed terminals



Do not touch the exposed terminals of this equipment while the power is on, as the high voltage generated is dangerous ii



NR ELECTRIC CO., LTD



RCS-985G Generator Protection







Residual voltage



Hazardous voltage can be present in the DC circuit just after switching off the DC power supply. It takes a few seconds for the voltage to discharge. CAUTION! 



Earth



The earthing terminal of the equipment must be securely earthed 



Operating environment



The equipment must only be used within the range of ambient environment detailed in the specification and in an environment free of abnormal vibration. 



Ratings



Before applying AC voltage and current or the DC power supply to the equipment, check that they conform to the equipment ratings. 



Printed circuit board



Do not attach and remove printed circuit boards when DC power to the equipment is on, as this may cause the equipment to malfunction. 



External circuit



When connecting the output contacts of the equipment to an external circuit, carefully check the supply voltage used in order to prevent the connected circuit from overheating. 



Connection cable



Carefully handle the connection cable without applying excessive force.



Copyright Manual: R1.01 P/N: EN_YJBH2041.0086.0002 Copyright © NR 2012. All rights reserved



NR ELECTRIC CO., LTD.



We reserve all rights to this document and to the information contained herein. Improper use in particular reproduction and dissemination to third parties is strictly forbidden except where expressly authorized.



Website: www.nari-relays.com



69 SuYuan. Avenue, Nanjing 211102，China Tel: 86-25-87178185, Fax: 86-25-87178208 Email: [email protected]



The information in this manual is carefully checked periodically, and necessary corrections will be included in future editions. If nevertheless any errors are detected, suggestions for correction or improvement are greatly appreciated. We reserve the rights to make technical improvements without notice.



NR ELECTRIC CO., LTD



iii



RCS-985G Generator Protection



Table of contents Preface .............................................................................................................................................. i Introduction..................................................................................................................................i Health and Safety........................................................................................................................i Instructions and Warnings ..........................................................................................................i Table of contents ............................................................................................................................. i Chapter1 Introduction .................................................................................................................... 1 1.1



Application .................................................................................................................. 1 1.1.1 Typical applications .................................................................................................. 1 1.1.2 Constitution of the scheme ....................................................................................... 2



1.2



Functions .................................................................................................................... 3



1.3



Features...................................................................................................................... 5 1.3.1 High performance hardware ..................................................................................... 5 1.3.2 New philosophy used in RCS-985G ......................................................................... 5 1.3.3 Intellectuality ............................................................................................................. 8



Chapter2 Technical Data ............................................................................................................. 11 2.1



Electrical Specifications ............................................................................................ 11 2.1.1 Power supply .......................................................................................................... 11 2.1.2 Analog current input ratings.................................................................................... 11 2.1.3 Analog voltage input ratings ................................................................................... 11 2.1.4 Binary input ............................................................................................................. 12 2.1.5 Binary output ........................................................................................................... 12 2.1.6 Power supply output for Optical isolators ............................................................... 12



2.2



Mechanical Specifications ........................................................................................ 12



2.3



Atmospheric Environment tests................................................................................ 13



2.4



Communication Interface ......................................................................................... 13



2.5



Type test ................................................................................................................... 14 2.5.1 Environmental tests ................................................................................................ 14



NR ELECTRIC CO., LTD



i



RCS-985G Generator Protection



2.5.2 Mechanical tests ..................................................................................................... 14 2.5.3 Electrical tests ......................................................................................................... 14 2.5.4 Electromagnetic compatibility (EMC) ..................................................................... 14 2.6



Certifications ............................................................................................................. 15



2.7



Protective functions related parameters................................................................... 15 2.7.1 Accurate Operating scope ...................................................................................... 15 2.7.2 General error of analog input metering .................................................................. 16 2.7.3 Generator differential protection ............................................................................. 16 2.7.4 Phase-splitting transverse differential protection ................................................... 17 2.7.5 High sensitive transverse differential protection..................................................... 17 2.7.6 Longitudinal zero sequence voltage protection for turn-to-turn fault...................... 18 2.7.7 Earth fault protection of stator ................................................................................ 18 2.7.8 Earth fault protection of rotor .................................................................................. 19 2.7.9 Overload protection of stator .................................................................................. 19 2.7.10 Negative sequence overload protection ............................................................... 19 2.7.11 Overload protection of excitation winding (AC quantity) ...................................... 20 2.7.12 Overload protection of excitation winding (DC quantity) ...................................... 20 2.7.13 Loss of excitation protection of generator ............................................................ 20 2.7.14 Out-of-step protection of generator ...................................................................... 21 2.7.15 Voltage protection of generator ............................................................................ 21 2.7.16 Over excitation protection ..................................................................................... 22 2.7.17 Power protection of generator .............................................................................. 22 2.7.18 Frequency protection of generator ....................................................................... 22 2.7.19 Accidental energization protection of generator ................................................... 22 2.7.20 Startup/shutdown protection of generator ............................................................ 23 2.7.21 Low impedance protection.................................................................................... 23 2.7.22 Voltage controlled overcurrent protection............................................................. 23 2.7.23 Measurements and Recording Facilities .............................................................. 24



Chapter3 Description of Operation Theory ............................................................................... 25 3.1 ii



Software Structure .................................................................................................... 25 NR ELECTRIC CO., LTD



RCS-985G Generator Protection



3.2



Fault detectors .......................................................................................................... 25 3.2.1 Using fault detector improves the security of tripping ............................................ 25 3.2.2 Fault detector of differential protection, phase-splitting transverse differential protection of generator..................................................................................................... 26 3.2.3 Interturn fault protection of generator ..................................................................... 27 3.2.4 Earth fault protection of stator of generator ............................................................ 27 3.2.5 Generator rotor earth fault protection ..................................................................... 27 3.2.6 Generator stator overload protection...................................................................... 28 3.2.7 Negative sequence overcurrent protection of generator ........................................ 28 3.2.8 Generator loss-of-excitation protection .................................................................. 28 3.2.9 Generator out-of-step protection ............................................................................ 28 3.2.10 Generator overvoltage protection ......................................................................... 28 3.2.11 Generator over excitation protection .................................................................... 28 3.2.12 Generator reverse power protection..................................................................... 28 3.2.13 Generator frequency protection ............................................................................ 29 3.2.14 Generator accident energization protection ......................................................... 29 3.2.15 Startup and shutdown protection of generator ..................................................... 29 3.2.16 Differential current and overcurrent protection of excitation transformer ............. 29 3.2.17 Overload protection of rotor winding .................................................................... 29 3.2.18 Mechanical protection ........................................................................................... 29



3.3



Theory of protective elements .................................................................................. 30 3.3.1 Differential protection, phase-splitting transverse differential protection of generator ......................................................................................................................................... 30 3.3.2 DPFC Current Differential Element ........................................................................ 34 3.3.3 Interturn fault protection of generator ..................................................................... 36 3.3.4 Backup protection of generator .............................................................................. 40 3.3.5 Earth fault protection of stator ................................................................................ 43 3.3.6 Earth fault protection of rotor .................................................................................. 47 3.3.7 Generator stator overload protection...................................................................... 49 3.3.8 Negative sequence overload protection ................................................................. 51



NR ELECTRIC CO., LTD



iii



RCS-985G Generator Protection



3.3.9 Loss-of-Excitation protection .................................................................................. 53 3.3.10 Out-of-step protection ........................................................................................... 57 3.3.11 Voltage protection ................................................................................................. 59 3.3.12 Over excitation protection ..................................................................................... 60 3.3.13 Power protection ................................................................................................... 61 3.3.14 Frequency protection ............................................................................................ 62 3.3.15 Accidental energization protection ....................................................................... 63 3.3.16 Breaker failure protection ..................................................................................... 65 3.3.17 Generator startup and shutdown protection ......................................................... 66 3.3.18 Excitation winding overload protection ................................................................. 67 3.3.19 Excitation transformer and exciter protection ....................................................... 69 3.3.20 CT circuit failure alarm .......................................................................................... 70 3.3.21 VT circuit failure alarm .......................................................................................... 71 3.3.22 Output contacts driven by overcurrent element ................................................... 72 3.3.23 Mechanical protection ........................................................................................... 72 Chapter4 Self-supervision, metering and records ................................................................... 73 4.1



Self-supervision ........................................................................................................ 73 4.1.1 Start-up self-testing................................................................................................. 73 4.1.2 Continuous self-testing ........................................................................................... 74 4.1.3 List of alarm messages ........................................................................................... 75



4.2



Metering .................................................................................................................... 81 4.2.1 Measured voltages and currents ............................................................................ 81 4.2.2 Sequence voltages and currents ............................................................................ 81 4.2.3 Rms. voltages and currents .................................................................................... 81 4.2.4 Differential current and relevant quantities ............................................................. 81 4.2.5 Phase angles .......................................................................................................... 82 4.2.6 Measurement display quantities ............................................................................. 82 4.2.7 All metering data displayed on LCD ....................................................................... 82



4.3



Signaling ................................................................................................................... 93 4.3.1 Enabling Binary Inputs of generator ....................................................................... 94



iv



NR ELECTRIC CO., LTD



RCS-985G Generator Protection



4.3.2 Enabling Binary Inputs of excitation protection ...................................................... 96 4.3.3 Binary Inputs of mechanical protection .................................................................. 96 4.3.4 Auxiliary Contacts ................................................................................................... 97 4.3.5 Internally generated binary inputs by MON ............................................................ 98 4.3.6 Other Binary Inputs ............................................................................................... 100 4.4



Event & fault records .............................................................................................. 100 4.4.1 Introduction ........................................................................................................... 100 4.4.2 Event & Fault records ........................................................................................... 100 4.4.3 Type of event ........................................................................................................ 101 4.4.4 Change of state of opto-isolated inputs ................................................................ 101 4.4.5 Relay alarm signals .............................................................................................. 103 4.4.6 Protection element ................................................................................................ 104 4.4.7 Viewing event records via RCSPC support software ........................................... 106



4.5



Disturbance Record ................................................................................................ 107



4.6



Time Synchronization ............................................................................................. 108



Chapter5 Hardware Description ............................................................................................... 109 5.1



Hardware overview ................................................................................................. 109 5.1.1 Front view ............................................................................................................. 109 5.1.2 Rear view .............................................................................................................. 111 5.1.3 Functional block diagram of RCS-985G ............................................................... 111



5.2



Standard connectors and terminals ....................................................................... 112 5.2.1 General description............................................................................................... 112 5.2.2 Pins definition of ‗1A‘ connectors. ........................................................................ 113 5.2.3 Pins definition of ‗1B‘ connectors ......................................................................... 114 5.2.4 Pins definition of ‗2A‘ connectors ......................................................................... 114 5.2.5 Pins definition of ‗2B‘ connectors ......................................................................... 115 5.2.6 Pins definition of ‗3A‘ connectors ......................................................................... 117 5.2.7 Pins definition of ‗3B‘ connectors ......................................................................... 118 5.2.8 Pins definition of ‗4A‘ connectors ......................................................................... 120 5.2.9 Pins definition of ‗4B‘ connectors ......................................................................... 121



NR ELECTRIC CO., LTD



v



RCS-985G Generator Protection



5.2.10 Pins definition of ‗5B‘ connectors ....................................................................... 122 5.2.11 Pins definition of ‗6B‘, ‗7B‘ connectors ............................................................... 124 5.2.12 Pins definition of ‗8B‘ connectors ....................................................................... 124 5.2.13 Pins definition of ‗8C‘ connectors ....................................................................... 126 5.2.14 Pins definition of ‗9B‘ connectors ....................................................................... 126 5.2.15 Pins definition of ‗9C‘ connectors ....................................................................... 128 5.3



Output ..................................................................................................................... 129 5.3.1 Tripping outputs .................................................................................................... 129 5.3.2 Signaling outputs .................................................................................................. 130 5.3.3 Alarming outputs ................................................................................................... 131 5.3.4 Other outputs ........................................................................................................ 131



Chapter6 Software Overview .................................................................................................... 133 6.1



Software Overview ................................................................................................. 133



6.2



System services software ....................................................................................... 133



6.3



Platform software.................................................................................................... 134 6.3.1 Record logging...................................................................................................... 134 6.3.2 Settings database ................................................................................................. 134 6.3.3 Database interface................................................................................................ 134 6.3.4 Protection and control software ............................................................................ 134



6.4



Software downloading ............................................................................................ 136



Chapter7 Settings ....................................................................................................................... 141 7.1



Equipment parameters ........................................................................................... 141 7.1.1 Setting list ............................................................................................................. 141 7.1.2 Setting instruction of the parameters.................................................................... 141 7.1.3 Setting path ........................................................................................................... 143



7.2



System Settings ...................................................................................................... 143 7.2.1 Logic settings of configuring functions ................................................................. 143 7.2.2 Generator system parameters .............................................................................. 146 7.2.3 System parameters of excitation transformer or exciter ...................................... 149 7.2.4 Implicit configuration settings ............................................................................... 151



vi



NR ELECTRIC CO., LTD



RCS-985G Generator Protection



7.3



Protection Settings ................................................................................................. 154 7.3.1 Differential protection settings .............................................................................. 154 7.3.2 Splitting-phase transverse differential protection settings.................................... 158 7.3.3 Settings of turn-to-turn fault protection of generator ............................................ 159 7.3.4 Settings of backup protection of generator .......................................................... 162 7.3.5 Settings of earth fault protection of stator windings ............................................. 166 7.3.6 Settings of earth fault protection of rotor .............................................................. 170 7.3.7 Settings of thermal overload protection of stator .................................................. 171 7.3.8 Settings of negative sequence overload protection ............................................. 173 7.3.9 Settings of Loss-of-Excitation protection .............................................................. 176 7.3.10 Settings of out-of-step protection ....................................................................... 182 7.3.11 Settings of voltage protection ............................................................................. 185 7.3.12 Settings of overexcitation protection of generator .............................................. 187 7.3.13 Settings of power protection of generator .......................................................... 190 7.3.14 Settings of underfrequency and overfrequency protection ................................ 191 7.3.15 Settings of startup and shutdown protection of generator ................................. 194 7.3.16 Settings of accidental energization protection of generator ............................... 196 7.3.17 Settings of differential protection of excitation transformer or exciter ................ 198 7.3.18 Settings of backup protection of excitation transformer or exciter ..................... 199 7.3.19 Settings of overload protection of excitation ...................................................... 200 7.3.20 Settings of mechanical protection ...................................................................... 202 7.3.21 Settings of breaker failure protection of generator ............................................. 203



7.4



Calculated parameters ........................................................................................... 204 7.4.1 Setting list ............................................................................................................. 204 7.4.2 Explanation of the parameters.............................................................................. 205 7.4.3 Setting path ........................................................................................................... 207



Chapter8 Human Machine Interface ......................................................................................... 209 8.1



User interfaces and menu structure ....................................................................... 209



8.2



Introduction to the relay .......................................................................................... 209 8.2.1 Front panel ............................................................................................................ 209



NR ELECTRIC CO., LTD



vii



RCS-985G Generator Protection



8.2.2 LCD ....................................................................................................................... 210 8.2.3 LED indications ..................................................................................................... 221 8.2.4 Keypad operation.................................................................................................. 223 8.2.5 Menu ..................................................................................................................... 223 8.2.6 Operation instruction of Menu .............................................................................. 226 Chapter9 Communications........................................................................................................ 245 9.1



Introduction ............................................................................................................. 245



9.2



Rear communication port of EIA(RS)485 ............................................................... 245 9.2.1 Rear communication port EIA(RS)485 interface .................................................. 245 9.2.2 EIA(RS)485 bus .................................................................................................... 246 9.2.3 Bus termination ..................................................................................................... 246 9.2.4 Bus connections & topologies .............................................................................. 246



9.3



IEC60870-5-103 communication ............................................................................ 247 9.3.1 Overview of IEC60870-5-103 ............................................................................... 247 9.3.2 Messages description in IEC60870-5-103 protocol type ..................................... 247



9.4



MODBUS protocol .................................................................................................. 252 9.4.1 Overview ............................................................................................................... 252 9.4.2 Fetch real time status (Binary).............................................................................. 252 9.4.3 Fetch metering values of equipment .................................................................... 259 9.4.4 Fetch settings value of equipment ........................................................................ 262 9.4.5 Diagnostics (Function Code: 08H) ....................................................................... 272 9.4.6 Exception Responses ........................................................................................... 273



9.5



EIA(RS)232 Interface ............................................................................................. 273



9.6



Communication with printer .................................................................................... 274



9.7



Communication with External GPS pulse Source .................................................. 274



Chapter10 Installation ................................................................................................................ 277



viii



10.1



Receipt of Relays ................................................................................................... 277



10.2



Handling of Electronic Equipment .......................................................................... 277



10.3



Storage ................................................................................................................... 278



10.4



Unpacking ............................................................................................................... 278 NR ELECTRIC CO., LTD



RCS-985G Generator Protection



10.5



Relay Mounting ....................................................................................................... 278 10.5.1 Rack Mounting .................................................................................................... 278 10.5.2 Panel mounting ................................................................................................... 280



10.6



RELAY WIRING ..................................................................................................... 280 10.6.1 Medium and heavy duty terminal block connections ......................................... 280 10.6.2 EIA(RS)485 port ................................................................................................. 281 10.6.3 IRIG-B connections (if applicable) ...................................................................... 281 10.6.4 EIA(RS)232 front port of downloading/monitoring.............................................. 281 10.6.5 Ethernet port (if applicable) ................................................................................ 281 10.6.6 Test port .............................................................................................................. 282 10.6.7 Earth connection ................................................................................................. 282



Chapter11 Commission ............................................................................................................. 283 11.1



Introduction ............................................................................................................. 283



11.2



Precautions ............................................................................................................. 283



11.3



Relay commission tools .......................................................................................... 284



11.4



Setting Familiarization ............................................................................................ 285



11.5



Product checks ....................................................................................................... 285 11.5.1 With the relay de-energized................................................................................ 285 11.5.2 With the relay energized ..................................................................................... 288 11.5.3 Setting Testing .................................................................................................... 296 11.5.4 Rear communications port EIA (RS) 485 ........................................................... 296 11.5.5 On-load checks ................................................................................................... 296 11.5.6 Final check .......................................................................................................... 297



11.6



Use of assistant test software RCSPC................................................................... 297 11.6.1 Function summary of RCSPC communication software .................................... 297 11.6.2 Connection way of protection equipment and personal computer ..................... 298 11.6.3 Configuration of PC and the software before use .............................................. 298 11.6.4 Operation instruction of the software.................................................................. 299



Chapter12 Maintenance ............................................................................................................. 301 12.1



Maintenance period ................................................................................................ 301



NR ELECTRIC CO., LTD



ix



RCS-985G Generator Protection



12.2



Maintenance checks ............................................................................................... 301 12.2.1 Alarms ................................................................................................................. 301 12.2.2 Binary Inputs ....................................................................................................... 301 12.2.3 Binary output ....................................................................................................... 301 12.2.4 Analog inputs ...................................................................................................... 301



12.3



Method of Repair .................................................................................................... 302 12.3.1 Replacing the complete relay ............................................................................. 302 12.3.2 Replacing a PCB ................................................................................................ 303



12.4



Changing the relay battery ..................................................................................... 303 12.4.1 Instructions for replacing the battery .................................................................. 304 12.4.2 Battery disposal .................................................................................................. 304



12.5



Cleaning.................................................................................................................. 304



Chapter13 Decommissioning and Disposal ............................................................................ 305 13.1



Decommissioning ................................................................................................... 305 13.1.1 Switching Off ....................................................................................................... 305 13.1.2 Disconnecting Cables ......................................................................................... 305 13.1.3 Dismantling ......................................................................................................... 305



13.2



Disposal .................................................................................................................. 305



Chapter14 Ordering Form.......................................................................................................... 307 14.1



Loose equipment .................................................................................................... 307



14.2



Panel installed ........................................................................................................ 308



Chapter15 Manual version history ........................................................................................... 309 Chapter16 ANNEX ...................................................................................................................... 311 16.1



Appendix A: RCSPC for RCS-985 (User Version) ................................................. 311 16.1.1 General ............................................................................................................... 311 16.1.2 Menu bar ............................................................................................................. 312 16.1.3 Tool bar ............................................................................................................... 314 16.1.4 Report ................................................................................................................. 320 16.1.5 Trip Tests ............................................................................................................ 321



x



NR ELECTRIC CO., LTD



Chapter1 Introduction



Chapter1 Introduction 1.1



Application



RCS-985G is a microprocessor based generator protection relay integrated with main and backup protection. It provides complete electrical protection for large-sized generators, including turbo-generator, hydro-generator, gas turbine generator and pumped-storage generator. The RCS-985G relay is suited for wall surface mounted or flush mounted into a control panel. Figure 1.1-1 shows a typical application of RCS-985G.



1.1.1 Typical applications Figure 1.1-1 typical protection configuration scheme consists of three protection panels. In which panels A and B comprises of one set of electric quantity protection of generator respectively. Different groups of CT are used for them respectively. Panel C comprises of mechanical protection as well as pole disagreement protection, circuit breaker failure initiation and circuit breaker operation relay set if needed.



B



Panel A



Panel B



Panel C



RCS-985G



RCS-985G



RCS-974AG



B



Exciting Transformer Generator



B



B



Figure 1.1-1 Typical application of RCS-985G



NR ELECTRIC CO., LTD



1



Chapter1 Introduction



1.1.2 Constitution of the scheme 1.1.2.1 Differential protection For a large-sized generator, panel A and B are both equipped with generator differential protection and exciting transformer (exciter) differential protection. RCS-985G is equipped with two kinds of percentage differential protection (variable slope percentage differential protection and DPFC percentage differential protection) in order to meet high performance not only in speed but also in security. 1.1.2.2 Backup protection Panel A and B are equipped with a complete set of backup protection for generator and use two groups of independent CTs. For earth fault protection of rotor, two sets of such protection cannot work simultaneously as influence between them will appear. Therefore only one set of earth fault protection of rotor can be enabled during operation. If the other set will be switched on at anytimes, this current set shall first quit before letting the other set operates. 1.1.2.3 Current transformer Panels A and B adopt different independent CTs. Main protection and backup protection adopt one common group of CTs. 1.1.2.4 Voltage transformer Panel A and B shall adopt different potential transformer VTs or its different windings so far as possible. For turn-to-turn fault protection of generator, in order to prevent unwanted operation due to VT circuit failure at HV side which is used dedicatedly for this protection, one set of protection shall adopt two groups of VT. However, if we consider adopting only independent VT windings, then too many VTs will be installed at generator terminal which is not reasonable. Therefore it is recommended to equip three VTs at generator terminal, named VT1, VT2 and VT3. Panel A adopts voltage from VT1 and VT3 while panel B from VT2 and VT3. During normal operation, panel A adopts VT1 and panel B adopts VT2 while VT3 is as a backup VT to both of them. If circuit of VT1 or VT2 fails, VT3 will be switched over to automatically by the software. For zero sequence voltage, there are no two independent windings adopted by two sets of protection equipments simultaneously in general. 1.1.2.5 Circuit Breaker Failure Initiation Circuit breaker failure initiation is very important to a power plant. In general, generator protection tripping contact is an essential condition to circuit breaker failure initiation. Considering importance of such protection, it is recommended to realize it as follows: Only one set of circuit breaker failure initiation shall be equipped. In order to make it more reliable, circuit breaker failure initiation function can‘t be integrated into 2



NR ELECTRIC CO., LTD



Chapter1 Introduction



any equipment with electric quantity protection relays.



1.2



Functions Table 1.2-1 Protective functions for generator



No.



Protection function overview for generator



IEEE



1.



Current differential protection



87G



2.



Unrestrained instantaneous differential protection



87UG



3.



DPFC current differential protection



7/87G



4.



High sensitive transverse differential protection



87G



5.



Longitudinal zero sequence overvoltage protection for turn-to-turn fault



59N/60



6.



DPFC directional protection for turn-to-turn fault



7/67



7.



Two stages phase-to-phase distance protection



21G



8.



Voltage controlled overcurrent protection



51V



9.



Current blocking element at generator‘s terminal



10.



Fundamental zero sequence overvoltage protection for stator earth fault



64G1



11.



Third harmonic protection for stator earth fault



27/59TN, 64G2



12.



Two stages of one-point-earth fault protection of rotor



64R



13.



Two-point earth fault protection of rotor



64R



14.



Definite and inverse time stator thermal overload protection



49S



15.



Definite and inverse time negative sequence overload protection of rotor



46/50, 46/51, 49R



16.



Loss-of-excitation protection



40



17.



Out-of-step protection



68/78



18.



Two stages phase-to-phase overvoltage protection



59G



19.



Phase-to-phase undervoltage protection



27G



20.



Two stages definite time over-excitation protection



24



21.



Inverse time over-excitation protection



24



22.



Reverse power protection



32G



23.



Reverse power protection during generator shutting down



32G



24.



Three stage underfrequency protection



81G



25.



Two-stage overfrequency protection



81O



26.



Startup/shutdown protection of generator



27.



Accidental energization protection



50/27



28.



Voltage balance function



60



29.



Under-frequency overcurrent protection



30.



Voltage transformer supervision



47,60G



31.



Current transformer supervision



50/74



Table 1.2-2 Protective functions for excitation



NR ELECTRIC CO., LTD



3



Chapter1 Introduction



No.



Protection function overview for excitation



IEEE



1.



Current differential protection for exciting-transformer



87T



2.



Current differential protection of AC exciter



87G



3.



Overcurrent protection



50P/51P



4.



Definite and inverse time thermal overload protection for exciting windings



87G



5.



Current transformer supervision of excitation set



50/74



Table 1.2-3 Mechanical protection of generator No.



Mechanical protection function overview for generator



1.



Mechanical protection 1



2.



Mechanical protection 2



3.



Mechanical protection 3



4.



Mechanical protection 4



IEEE



Table 1.2-4 Other functions of RCS-985G Other functions overview Automatic self-supervision



relay hardware supervision and secondary circuit supervision



Metering



24 samples per cycle



Fault recording



Event recording



CPU module



32 latest fault reports, 8 latest fault waveforms



MON module



4 or 8 seconds continuous oscillogram function for latest fault



self-supervision report



32 latest abnormality reports



binary input chang report



32 latest binary status input change reports



Present recording



One normal operating waveform triggered manually



Loacal HMI



LCD and keypad



Remote HMI



RCSPC software or substation automation system software



Front communication port (RS232)



for software RCSPC with local protocol



Rear communication ports to host



Ports type



four RS-485 ports (two can be configured as fiber port)



Protocol type



IEC 60870-5-103/MODBUS



Rear communication port to printer



one RS-485 or RS-232



Time synchronisation port



IRIG-B (optional)



Voltage and current drift auto-adjustment.



4



NR ELECTRIC CO., LTD



Chapter1 Introduction



1.3



Features



1.3.1 High performance hardware 1.3.1.1 Parallel calculation of double CPU system The hardware of any one CPU system comprises a 32 bit microprocessor and two digital signal processors (DSP). The two CPU systems can operate in parallel acompanied by a fast A/D converter. The 32-bit microprocessor performs logic calculations and the DSPs perform the protection calculation. A high performance hardware ensures real time calculation of all protection relays within a sampling interval. On the premise of 24 samples per cycle, all data measurement, calculation and logic discrimination could be done within one sampling period. The event recording and protection logic calculation are completed simultaneously. 1.3.1.2 Independent Fault Detectors There is a set of independent fault detectors in the CPU processor in the RCS-985G relay. Its operation supervises the tripping outputs. They will connect power supply to output relays when in operation. There are different fault detectors in the CPU module used for various protective functions. The relay can drive a tripping output only when the fault detectors in the CPU module and the fault detectors in the MON module operate simultaneously. This kind of independent supervision of tripping outputs using fault detectors can avoid any maloperation possibly caused by any hardware component failures. This highly increases the security to a very high level. 1.3.1.3 Integration Of Main And Backup Protection Main and backup protection are integrated in one set of protection equipment. Protection information such as sampled data and binary inputs are shared by all protective elements and no more than one CT or VT at the same side of the transformer needs to be input into the equipment for different protective elements. Shunt connection of VT and serial connection of CT that is usually seen in secondary circuits before can be avoided. This greatly reduces the possibility of circuit failure. The equipment can gather all information of any fault and record all relevant waveforms of it for offline analysis. 1.3.1.4 Flexible configuration of output Elaborately designed tripping matrix makes it possible for the operation circuit to be suitable for various circuit breakers.



1.3.2 New philosophy used in RCS-985G 1.3.2.1 Variable slope percentage differential protection The percentage differential protection adopts variable slope restraint characteristics and the actual unbalanced differential current effect can be simulated. In order to prevent unwanted operation of differential protection due to CT saturation, countermeasures to discriminate CT saturation are provided by means of waveform identification of phase current at each side. NR ELECTRIC CO., LTD



5



Chapter1 Introduction



1.3.2.2 DPFC percentage differential protection DPFC percentage differential protection reflects only deviation components of differential current and restraint current and is not affected by load current. It can detect slight fault within generator. Besides this, it is insensitive to CT saturation since its restraint coefficient is set comparatively higher than that of conventional differential protection. 1.3.2.3 Ratio corrected by software for differential protection Current from CTs of each side under different ratios are corrected to a single standard before calculation. 1.3.2.4 Provide two inrush current distinguishing methods Two discrimination principles for inrush current are provided: harmonics restraint and waveform distortion restraint. 1.3.2.5 CT saturation detection Based on the operation sequence of DPFC restraint current element and the DPFC differential current element of differential protection, external fault with CT saturation and internal fault can be distinguished correctly. In case of internal fault, the relay will operate immediately, while in case of external fault with CT saturation, the criterion of current waveform is adopted. The relay will not operate in case of a persisting external fault with CT saturation which occur no less than 5ms after the fault detectors pickup. The relay will operate quickly though when an evolving external to internal fault occurs. 1.3.2.6 High sensitive transverse differential protection Transverse differential protection adopts a percentage phase current restraint and floating threshold to get high sensitivity in internal fault and high security in external fault. In addition, by adopting a frequency tracking technique, digital filter technique and Fourier transformation technique, the filtration ratio of third component can reach more than 100. These countermeasure guarantees the reliability of the protection in all occasions as mentioned below: Advantages of percentage restraint by phase current: （1）The transverse differential protection can get reliable restraint effect as the faulty phase current increases greatly while transverse differential current increases less in external fault situation. （2）The protection has very high operation sensitivity because the transverse differential current increases exponentially in comparison to phase current change whose increase is minimal in slight interturn fault situation. （3）The insensitive stage of transverse differential current protection will operate quickly and reliably when severe interturn fault occurs in stator winding. （4）In case of phase-to-phase fault of stator winding, not only does the transverse differential current increase greatly, but so also the phase current. Therefore just low percentage restraint by



6



NR ELECTRIC CO., LTD



Chapter1 Introduction



phase current guarantees the reliable operation of transverse differential protection against the fault. （5）As for other increment of transverse differential unbalanced current in normal operation condition, transverse differential current protection uses float threshold technique to avoid unwanted operation. 1.3.2.7 Performance of percentage restraint interturn protection By adopting frequency tracking technique, digital filter technique and Fourier transformation technique, the filtration ratio of the third harmonic component can reach more than 100. New criteria of generator current percentage restraint: （1）Fault current increases greatly while longitudinal residual voltage increase less in external three-phase fault, therefore the protection tends to be reliably restrained thanks to current increment as restraint quantity. （2）If external asymmetric fault occurs, phase current increases greatly with negative sequence current, but the longitudinal residual voltage has very little increment, therefore the protection tends to be reliably restrained by the mixing the quantity of current increment and the negative-sequence component. （3）The protection has very high operation sensitivity as the longitudinal residual voltage increase is comparatively large whereas the phase current hardly changes in the situation of slight interturn fault. （4）The high-setting stage of transverse differential current protection will operate quickly and reliably when severe interturn fault occurs in stator winding. （5）As for the other increment of unbalanced longitudinal residual voltage in normal operation condition, the protection uses floating-threshold technique to avoid unwanted operation. 1.3.2.8 Performance of stator earth fault protection （1）By adopting frequency tracking techniques, digital filter techniques and Fourier transformation techniques, the filtration ratio of third component can reach more than 100. （2）The sensitive stage of foundational residual voltage protection operates and issues trip command only if the dual criteria of residual voltages of generator terminal and neutral point are satisfied at the same time. （3）The ratio settings of third harmonic of generator terminal to that of neutral point used in third harmonic ratio criteria, which will automatically suit to the change of ratio of third harmonic voltage of the plant unit fore-and-aft incorporated in the power network. This automation adjustment function ensures the correctness of signals generated and issued by the third harmonic voltage criteria even during incorporation or during isolation course of generator. (4) The ratio and phase-angle difference of third harmonic voltage of generator terminal to that of neutral point which is kept almost stable when the generator is in normal operation condition; also it is a slow developing course. Through real time adjustment of coefficient of amplitude value and



NR ELECTRIC CO., LTD



7



Chapter1 Introduction



phase, RCS-985 makes differential voltage between generator terminal and neutral point as 0 in normal operation condition. When stator earth fault occurs, the criteria tend to operate reliably and sensitively. 1.3.2.9 Performance of rotor earth fault protection Rotor earth fault protection adopts a sampling-switch（ping-pong type）principle. Direct current is input by a high-performance isolated amplifier. By switching two different electronic switches，the RCS-985 solves four different ground-loop equations to compute rotor winding voltage, rotor ground resistance and earthing position on real time and display these information on LCD of the protection. If one point earth fault protection only issues alarm signals instead of tripping after operation, then the two-points earth fault protection will be automatically put into service with a certain fixed delay and will operate to trip when two-point earth fault of rotor occurs. 1.3.2.10 Performance of loss-of-excitation protection Loss-of-excitation protection adopts optimizing protection scheme in which the stator impedance criteria, reactive power criteria, rotor voltage criteria, busbar voltage criteria and criteria of stator active power decrement，could be optionally combined to meet various demands of operation of the unit for different generators. 1.3.2.11 Performance of out-of-step protection Out-of-step protection adopts three-impedance element (which is got from positive-sequence current and positive sequence voltage of generator) to distinguish out-of-step from steady swing. The protection more than that can also accurately locate the position of swing center and record the slid numbers of external and internal swing respectively in real time. 1.3.2.12 VT circuit failure supervision Two groups of VT inputs are equipped at generator terminal. If one group fails, the equipment will issue an alarm and switch over to the healthy one automatically. It does not need to block any protective elements relevant to voltage. 1.3.2.13 CT circuit failure alarm and blocking This function adopts percentage differential principle. Detection ability of CT circuit failure can be enhanced significantly and unwanted operations can be avoided.



1.3.3 Intellectuality 1.3.3.1 Friendly HMI interface The HMI interface with a LCD and a 9-button keypad on the front panel is very user friendly. Real time data, connection diagram, phase current, differential current and voltage can be displayed on LCD during normal condition. 1.3.3.2 Transparency More than 500 sampled data including differential current and phase angle etc. can be displayed 8



NR ELECTRIC CO., LTD



Chapter1 Introduction



on LCD and more than 1500 internal data of the equipment can be supervised through dedicated auxiliary software RCSPC that provides the user with a greater convenience to know about the operational situation of RCS-985. 1.3.3.3 Perfect fault recording function CPU module: the latest 32 groups of fault data and event sequence, 8 groups of fault oscillograms, 32 status changes of binary inputs and 32 self-supervision reports can be recorded. MON module: when the equipment picks up, oscillograms of all analog sampling quantity, differential current and operation of the protection equipment can be recorded with duration of up to 4 seconds or 8 seconds (depending on the sample rate configured). The format of event or fault report is compatible with the international COMTRADE format. 1.3.3.4 Communication ports One front RS232 port ( For RCSPC software) Two rear RS-485 ports with IEC 60870-5-103 protocol or MODBUS protocol which can be re-configured as optical fiber ports. One rear RS-485 with clock synchronization, One rear RS-232 or RS-485 with printer. 1.3.3.5 Various clock synchronizations Various GPS clock synchronizations: second/minute pulse via binary input or RS-485, message via communication ports and IRIG-B synchronization.



NR ELECTRIC CO., LTD



9



Chapter1 Introduction



10



NR ELECTRIC CO., LTD



Chapter2 Technical Data



Chapter2 Technical Data 2.1



Electrical Specifications



2.1.1 Power supply Rated Voltage (Un)



24Vdc, 110Vdc, 125Vdc, 220Vdc, 250Vdc



Variation



(80% ~ 120%)Un



Ripple in the DC auxiliary voltage



Max 15% of the DC value. Per IEC 60255-11



Voltage dips voltage short interruptions Burden



and



Per IEC 61000-4-11，IEC 60255-11:1979 20ms for interruption without de-energizing，dips 60% of Un without reset up to 100ms



Quiescent condition



[I_OvLd_Sta]



&



[En_OvLd_Sta] [TrpLog_OvLd_Sta].bit0



&



&



[EBI_Ovld_Sta] [FD_Ovld_Sta]



Figure 3.3-16 Logic diagram of stator definite time overload protection



50



NR ELECTRIC CO., LTD



Chapter3 Description of Operation Theory I > [I_InvOvLd_Sta]



&



&



tmin



[TrpLog_InvOvLd_Sta].bit0



&



Op_InvOvLd_Sta



[TrpLog_InvOvLd_Sta].bit0 &



[EBI_EF_Sta] [FD_OvLd_Sta]



Figure 3.3-17 Logic diagram of inverse time stator overload protection



3.3.8 Negative sequence overload protection Negative sequence overload reflects overheating on surface of the rotor and other abnormality due to negative sequence current. This protection takes negative sequence current in generator end and neutral point as its criterion. 3.3.8.1 Definite time negative sequence overload protection There are two stages equipped with definite time negative sequence overload protection: one for alarm and the other for tripping. Figure 3.3-19 shows its logic diagram. 3.3.8.2 Inverse time negative sequence overload protection Inverse time negative sequence protection consists of three parts: low setting initiator, inverse time part and upper limit definite time part. Inverse time part can simulate generator-heating process including heat accumulation and dissipation. When negative sequence current reaches its low setting [I_InvNegOC_Gen], inverse time part initiates and the heat is accumulated. When the stator current is lower than permissive continuous negative sequence current [I_Neg_Perm_Gen], the heat accumulation will decrease accordingly. Operation criterion of inverse time part:



[(I 2 / I ezd ) 2  (I 2 l ) 2 ]  t  A (Equation 3.3-15) Where:



I 2 is generator negative sequence current, I eZD is generator rated current,



I 21 is permissive continuous negative sequence current (per unit value), and A is negative sequence heating constant of rotor. Figure 3.3-18 shows the inverse time curve. In the figure, t min ([tmin_InvNegOC_Gen]) is delay of NR ELECTRIC CO., LTD



51



Chapter3 Description of Operation Theory



upper limit of inverse time curve and I 2 SZD ([I_InvNegOC_Gen]) is setting of the inverse time negative sequence overload protection. I



I2zd



t min



t max



Figure 3.3-18 Operation curve of inverse time negative sequence overload protection of stator 3.3.8.3 Logic diagram of negative sequence overload protection of stator [En_NegOC_Gen]



& I2>[I_Alm_NegOC_Gen]



t



Alm_NegOC_Gen



[t_Alm_NegOC_Gen]



I2>[I_NegOCn_Gen]



& [En_NegOC_Gen]



&



t



Op_NegOCn_Gen



[t_NegOCn_Gen ]



[TrpLog_NegOCn_Gen].bit0



& [EBI_NegOC_Gen] [FD_PPF_Gen]



Figure 3.3-19 Logic diagram of definite time negative sequence overload protection



52



NR ELECTRIC CO., LTD



Chapter3 Description of Operation Theory I >[I_InvNegOC_Gen]



&



[En_NegOC_Gen]



&



t min &



Op_InvNegOC_Gen



[TrpLog_InvNegOC_Gen].bit0 &



[EBI_NegOC_Sta] [FD_PPF_Gen]



Figure 3.3-20 Logic diagram of inverse time negative sequence overload protection



3.3.9 Loss-of-Excitation protection 3.3.9.1 Theory of loss-of-excitation protection Loss of excitation represents abnormal operation of generator due to excitation failure. There are four criterions used for loss-of-excitation protection: under voltage, stator side impedance, rotor side undervoltage/excitation voltage and power output reduction. 3.3.9.2 Under voltage criterion Three phase voltages on bus generally and those at generator terminal sometimes are taken as this criterion. Criterion of simultaneous three phases under voltage is



U pp  U lezd



(Equation 3.3-16)



Where: Upp is phase-to-phase voltage of busbar or of generator terminal. Ulezd is undervoltage setting [V_BusUV_LossExc_Gen]. The protection will be blocked, when bus voltage is taken as the criterion and the bus VT circuit fails. When the generator terminal voltage is taken as the criterion, if one group of VT circuit fails, the other group of VT will be switched over to automatically. 3.3.9.3 Stator side impedance criterion This criterion is impedance circle including asynchronous impedance circle and steady state stabilization limit circle. The operation criterion is



270   Arg



Z  jX B  90  Z  jX A



(Equation 3.3-17)



Where:



X A can be set as the system impedance Xs for steady state stabilization limit circle and X A  1/2X d' for asynchronous impedance circle;



NR ELECTRIC CO., LTD



53



Chapter3 Description of Operation Theory



X B is taken as Xd  1/2X ' for round rotor generator and (X  X )/2  X ' /2 for salient pole d d q d generator. The impedance criterion can be combined with reverse reactive power criterion, i.e.,



Q  [Q_RevQ_LossExc_Gen]. Figure 3.3-21 (a) and (b) show operation characteristics of steady state stabilization impedance relay and asynchronous impedance relay, where the hatched area is operating area, and the dotted line is operation limit of reverse reactive power. jx



jx Z1



R



-Qzd



-Qzd



Z2



a)



R



Z1



Z2



(a)



b)



(b)



Figure 3.3-21 Operation characteristic of stator side impedance relay Besides operation criterion mentioned above, there are also auxiliary operation criterions, namely: Positive sequence voltage is greater than or equal to 6 V; Negative sequence voltage U2 is lower than 0.1 Un (rated voltage of generator); and Current of generator is no less than 0.1 Ie (rated current of generator). 3.3.9.4 Rotor side criterion Rotor side criterion comprises: Rotor undervoltage criterion: U r  U rlzd ;



Variable exciter voltage criterion:



U r  K r  X dz  S  U f0



Where:



Ur is exciting voltage.



U rlZD is the setting [V_RotUV_LossExc_Gen].



X dz  X d  X s , X d is synchronous reactance of generator (per unit value); 54



NR ELECTRIC CO., LTD



Chapter3 Description of Operation Theory



Xs is equivalent reactance on system side connected with the generator (per unit value); S is rated apparent power of generator (per unit value);



U f0



is rated voltage of exciter during generator without load;



K r is reliability coefficient. If Ur drops to zero or goes to minus value suddenly during loss of excitation, the rotor under voltage criterion will be met quickly before steady state stability limit of the generator is reached. If Ur drops to zero or reduces to a value gradually during loss of excitation, the variable excitation voltage criterion will be reached. Excitation under voltage or loss of excitation will cause out-of-step, and then excitation voltage and output power of the generator will swing seriously. In this case, the rotor under voltage criterion and the variable excitation voltage criterion will be met and withdrawn periodically in general. So the excitation voltage element will revert with delay during out-of-step condition while the impedance entering the steady state stability limit circle. 3.3.9.5 Reduced power output Active power criterion for power output reduction is P > Pzd. When out-of-step occurs during loss of excitation, power output of generator will swing within a certain range. P represents average power output within an oscillation period. Pzd is the setting [P_LossExc_Gen]. 3.3.9.6 Logic diagram of loss-of-excitation protection Three stages are equipped with loss-of-excitation protection: stage 1 is used for reduction of power output and alarm, stage 2 (with bus undervoltage criterion) is used for tripping, stage 3 is used for tripping with long delay. Figure 3.3-22 shows logic diagram of stage 1 of loss-of-excitation protection. If excitation is lost, this stage will be used to reduce power output to a pre-set level and issue alarm.



NR ELECTRIC CO., LTD



55



Chapter3 Description of Operation Theory [En_Alm_LossExc1_Gen] &



t



Alm_LossExc_Gen



P > [P_OvPwrLossExc_Gen] &



≥1



[En_P_LossExc1_Gen]



t



Ur[Q_RevQ_LossExc_Gen]



&



[En_RevQ_LossExc_Gen]



[En_LossExc_Gen] [EBI_LossExc_Gen] [TrpLog_LossExc1_Gen].bit 0 [FD_LossExc&OOS_Gen]



Figure 3.3-22 Logic diagram of loss-of-excitation protection stage 1 Figure 3.3-23 shows logic diagram of stage 2 of loss of excitation protection. If excitation is lost and voltage on HV side bus of main transformer is lower than its setting, this stage will trip with delay. In configuring this stage with consideration to security, it is strongly recommended that impedance criterion should be used as well as busbar criterion rather than the model where only busbar undervoltage criterion and rotor undervoltage criterion are used.



56



NR ELECTRIC CO., LTD



Chapter3 Description of Operation Theory Upp[V_OVn_Gen] [En_VoltProt_Gen]



&



&



t



&



[TrpLog_OVn_Gen].bit0



Op_OVn_Gen



t_OVn_Gen



[EBI_VoltProt_Gen]



tripping.



[FD_Volt&OvExc_Gen]



Figure 3.3-27 shows logic diagram of overvoltage protection. 3.3.11.2 Undervoltage protection Undervoltage protection responses to reduction of phase-to-phase voltage at the terminal of generator and will trip terminal breaker of the generator with configurable delay. The protection is controlled by external equipment such as control equipment of synchronous condenser. Only one stage of undervoltage protection is equipped with RCS-985G. Figure 3.3-28 shows logic diagram of undervoltage protection. 3.3.11.3 Logic diagram of overvoltage protection and undervoltage protection Upp>[V_OVn_Gen] [En_VoltProt_Gen]



&



&



t



&



[TrpLog_OVn_Gen].bit0



Op_OVn_Gen



t_OVn_Gen



[EBI_VoltProt_Gen] [FD_Volt&OvExc_Gen]



Figure 3.3-27 Logic diagram of overvoltage protection [BI_SyncCondenser] Upp.max [k_Alm_OvExc_Gen]



t



Alm_OvExc_Gen



[t_Alm_OvExc_Gen]



U/F > [k_OvExc n_Gen]



&



&



[En_OvExc_Gen]



Op_OvExcn_Gen



t



[t_OvExcn_Gen] [TrpLog_OvExc n_Gen].bit0



& [EBI_OvExc_Gen] [FD_Volt&OvExc_Gen]



Figure 3.3-30 Logic diagram of time over excitation protection U/F >[k n_InvOvExc_Gen]



&



&



[En_OvExc_Gen]



Op_InvOvExc_Gen



[TrpLog_InvOvExc_Gen].bit0



& [EBI_OvExc_Gen] [FD_Volt&OvExc_Gen]



Figure 3.3-31 Logic diagram of inverse time over excitation protection



3.3.13 Power protection Power protection comprises reverse power protection, sequence-tripping reverse power protection. Reverse power protection can prevent turbine blades or gears from damage in the case when the generator transforms into a motor mode and flows reverse power due to loss of its motive force. Operation criterion of this reverse power protection is P  - [P_RevP_Gen] , where P is the power calculated from three phase voltage and current and [P_RevP_Gen] is the reverse power setting. One stage for tripping and the other stage for alarm with independent delay setting respectively are equipped with this protection. Range of reverse power setting is 0.5% - 10% Pn, where Pn is rated active power of the generator. Range of delay is 0.1 s – 600 s. NR ELECTRIC CO., LTD



61



Chapter3 Description of Operation Theory



Figure 3.3-32 shows logic diagram of reverse power protection. Sometimes, when overload, over excitation or loss-of-excitation protection of generator initiate and tripping is needed, the steam valve of turbine has to be closed first. Sequent-tripping reverse power protection is used for this condition. Such protection is a reverse power protection that is blocked by the position contact of steam valve and circuit breaker of generator. It can trip relevant circuit breakers with a certain delay since the steam valve being closed. Its setting range is 0.5% 10% Pn. Figure 3.3-33 shows logic diagram of sequent-tripping reverse power protection. P>-[P_RevP_Gen] &



&



&



[En_PwrProt_Gen]



Op_RevP_Gen



t



[t_Trp_RevP_Gen]



[TrpLog_RevP_Gen].bit0 [EBI_PwrProt_Gen] [FD_Pwr&AccEnerg_Gen]



Figure 3.3-32 Logic diagram of reverse power [BI_52b_GCB] [BI_Valve_Turbine]



& P>-[P_SeqTrp_RevP_Gen]



Op_SeqTrpRevP_Gen



&



&



t



[En_PwrProt_Gen] [t_SeqTrp_RevP_Gen] [TrpLog_SeqTrp_RevP_Gen].bit0 [EBI_PwrProt_Gen] [FD_Pwr&AccEnerg_Gen]



Figure 3.3-33 Logic diagram of program reverse power protection



3.3.14 Frequency protection Frequency protection of generator comprises underfrequency and overfrequency protection. Permissive range of frequency of large generator is 48.5 Hz – 50.5 Hz. When frequency is lower than 48.5 Hz and if the accumulated time or duration of underfrequency operation in one continuous process reaches the setting value, the protection will issue an alarm signal or trip. This protection is blocked by the position contact of circuit breaker and no-current flag.



62



NR ELECTRIC CO., LTD



Chapter3 Description of Operation Theory



Three stages of underfrequency protection are equipped for RCS-985G, of which stages 1 is fixedly configured as accumulating time underfrequency protection, but stage 2 and stage 3 are designed as continuous time underfrequency characteristic. As to over frequency protection, two stages are equipped for RCS-985G and they will issue alarm or trip when it operates. [En_Alm_UFn_Gen] [Flg_Blk_FreqProt_Gen] f[I_OC_AccEnerg_Gen]



&



[Flg_NoCurr_CB_Tr]



Trip of other breakers



[En_AccEnerg_Gen]



&



&



[EBI_AccEnerg_Gen] [FD_Pwr&AccEnerg_Gen]



Figure 3.3-36 Logic diagram of unwanted closing protection of generator [BI_52b_CB] I2>[I2_Flash_GCB]



&



&



Op_Flash11_GCB



&



U>Uset.fix [En_AccEnerg_Gen] [EBI_AccEnerg_Gen]



t t>[t_Flash11_GCB] Op_Flash12_GCB t t>[t_Flash12_GCB]



[FD_Pwr&AccEnerg_Gen]



Figure 3.3-37 Logic diagram of breaker flashover protection



3.3.16 Breaker failure protection If breaker at the terminal of the generator fails when a generator internal fault occurs, it need to trip breakers at HV side of the transformer and plant transformer. So the breaker failure initiation for HV side breakers will be active. The current used is from terminal CT of generator. Breaker failure initiation (BFI) in RCS-985 is initiated by one of three elements: phase overcurrent element, zero sequence current element or negative sequence current element.



Figure 3.3-38 shows logic diagram of breaker failure protection.



NR ELECTRIC CO., LTD



65



Chapter3 Description of Operation Theory [BI_52b_GCB]



≥1 [En_CB_Ctrl_BFP_GCB] [BI_ExtProtTrp]



≥1 [En_ExtTrpCtrlBFP_GCB] I>[I_BFP_GCB] I2>[I_NegOC_BFP_GCB] &



&



≥1



t



&



&



[En_NegOC_BFP_GCB]



Op_BFP11_GCB



[t_BFP11_GCB]



3I0>[I_ROC_BFP_GCB]



t



&



Op_BFP12_GCB



[En_ROC_BFP_GCB] [t_BFP12_GCB]



[En_BFP_GCB] & [EBI_BFP_Gen] [FD_Bak_Gen]



Figure 3.3-38 Logic diagram of breaker failure protection



3.3.17 Generator startup and shutdown protection Protection for phase-to-phase fault and stator earth fault is provided during startup and shutdown process of the generator. Differential current protections are provided for faults of generator. A zero sequence overvoltage protection is provided for stator earth fault. Since frequency during startup and shutdown process is usually very low, algorithm independent of frequency is used for this protection. Whether the protection should be blocked or not by frequency element or auxiliary contact of circuit breaker can be determined by logic setting. F[t_**_StShut_Gen] &



t



Op_**_StShut_Gen



[TrpLog_**_StShut_Gen].bit0 [EBI_StShut_Gen] [FD_StShut_Gen]



Figure 3.3-39 Logic diagram of generator startup and shutdown protection Where:



66



NR ELECTRIC CO., LTD



Chapter3 Description of Operation Theory



―**‖ represent one of the three protective elements, ―GenDiff‖, ―UF_OC‖ and ―StaROV‖. The three protective elements‘ diagrams are so likely that they can be expressed in a figure instead of three for them respectively.



3.3.18 Excitation winding overload protection Excitation winding overload protection is equipped to reflect average heating condition of excitation winding. Excitation transformer current, exciter current or rotor current of generator can be taken as criterion of this protection. To exciter, frequency can be configured as 50 Hz or 100 Hz. Excitation winding protection comprises definite time and inverse time protection. 3.3.18.1 Definite time excitation winding overload protection One stage of alarm and one stage of tripping are equipped for definite time excitation winding overload protection. Figure 3.3-41 shows logic diagram of definite time excitation winding overload protection. 3.3.18.2 Inverse time excitation winding overload protection Inverse time excitation winding overload protection consists of three parts: low setting initiator, inverse time part and high setting definite part. Minimum operation time delay ([tmin_InvOvLd_RotWdg]) is provided for extreme overload condition. When current in excitation circuit reaches the low setting [I_InvOvLd_RotWdg], the inverse time protection initiates and the heating accumulation process starts. When the heating accumulation reaches its setting, alarm will be issued. The inverse time protection can simulate heating accumulation and radiation process. Il Ilh



Ilszd



t min



tmax t



Figure 3.3-40 Operation characteristic of inverse time overload protection of excitation winding In the figure,



I l is the current in excitation circuit,



I lh is corresponding value to tmin of the protection; NR ELECTRIC CO., LTD



67



Chapter3 Description of Operation Theory



I lsZD is the low setting of the protection [I_InvOvLd_RotWdg];



tmin is minimum delay [tmin_InvOvLd_RotWdg] . Tmax is corresponding time value to [I_InvOvLd_RotWdg] of the protection; Its operation criterion is:



[( I l I jzzd）  1]  t  KLzd 2



(Equation 3.3-19)



Where:



I jzzd is inverse time reference current of excitation circuit;



KLzd



is



setting



of



heat



capacity



factor



of



excitation



I>[I_InvOvLd_RotWdg]



&



&



[En_OvLd_RotWdg] tmin



Op_InvOvLd_RotWdg



&



[TrpLog_InvOvLd_RotWdg].bit0



&



[EBI_OvLd_RotWdg]



circuit.



[FD_Prot_Exc]



Figure 3.3-42 shows logic diagram of inverse time excitation winding overload protection. I>[I_Alm_OvLd_RotWdg] &



t



Alm_OvLd_RotWdg



&



t



Op_OvLd_RotWdg



[En_OvLd_RotWdg] I>[I_OvLd_RotWdg] & [En_OvLd_RotWdg] [TrpLog_OvLd_RotWdg].bit0 & [EBI_OvLd_RotWdg] [FD_Prot_Exc]



Figure 3.3-41 Logic diagram of definite time excitation winding overload protection



68



NR ELECTRIC CO., LTD



Chapter3 Description of Operation Theory I>[I_InvOvLd_RotWdg]



&



&



[En_OvLd_RotWdg] tmin



Op_InvOvLd_RotWdg



&



[TrpLog_InvOvLd_RotWdg].bit0 [EBI_OvLd_RotWdg]



&



[FD_Prot_Exc]



Figure 3.3-42 Logic diagram of inverse time excitation winding overload protection



3.3.19 Excitation transformer and exciter protection 3.3.19.1 Excitation transformer and exciter differential protection (1) Operation criterion of excitation transformer differential protection is:



 I d  K bl  I r  I cdqd   K bl  K bl1  K blr  ( I r / I e )   I d  K bl 2  ( I r  nIe )  b  I cdqd   K blr  ( K bl 2  K bl1 ) /( 2  n) b  ( K bl1  K blr  n)  nIe



( I r  nI e ) ( I r  nIe )



.



(Equation 3.3-20)    I 1  I2   Ir  2     I d  I 1  I 2 



The criterion is the same to Equation 3-1 except the differential current and restraint current. Here: For excitation transformer: I 1 and I 2 are currents of HV side and LV side respectively. (2) Operation criterion of exciter differential protection section 3.3.1. 3.3.19.2 Excitation transformer and exciter overcurrent protection Two stages of overcurrent protection are equipped for excitation transformer or exciter overcurrent protection as backup protection. These two stages will trip the circuit breaker with configurable delay. Figure 3.3-43 shows its logic diagram.



NR ELECTRIC CO., LTD



69



Chapter3 Description of Operation Theory [I>[I_OC n_Exc] &



[En_Bak_Exc] [EBI_Bak_Exc]



t



Op_OC n_Exc



[t_OC n_Exc] &



[TrpLog_OC n_Exc].bit0 [FD_Prot_Exc]



Figure 3.3-43 Logic diagram of excitation transformer or exciter overcurrent protection



3.3.20 CT circuit failure alarm 3.3.20.1 Three-phase current circuit failure alarm Operation criterion of the alarm is:



I 2  0.04 In  0.25I max (Equation 3.3-21) Where:



I 2 is negative sequence current; In is secondary rated current and



I max



is maximum phase current.



If this criterion is met, CT circuit failure alarm will be issued with 10s delay. Once the condition reverts to normal condition, the alarm will be reset with a 10s delay. 3.3.20.2 Differential current alarm in differential protection circuit This function is enabled only when relevant differential protection logic setting is set as enabled. If the criterion is met, the alarm will be sent after a delay of 10 s and corresponding differential protection will not be blocked. When the differential current is eliminated, the alarm will be reset with a delay of 10 s. In order to increase sensitivity of this alarm, the percentage restraint differential current alarm criterion is adopted as shown below.



 I d  I dbjzd  I d  k bj  I res



(Equation 3.3-22)



If the differential current reaches its threshold and also reaches the differential alarm level of percentage restraint factor multiplied by the restraint current, the differential current alarm will be issued.



70



NR ELECTRIC CO., LTD



Chapter3 Description of Operation Theory



3.3.20.3 Alarm or blocking to differential protection by CT circuit failure Function of instantaneous CT circuit failure discrimination is equipped for differential protection. Only when related logic settings and relevant enabling binary input of protection are set ―on‖, this function of alarm or blocking of instantaneous CT circuit failure discrimination will be enabled. If internal fault occurs, at least one of following four conditions will be present: (1) Negative sequence voltage at any side is greater than 2V; (2) Any phase current of a certain side increases after fault detector picks up; (3) Maximum phase current is greater than 1.2 Ie after initiation; (4) At least three phase-currents increase after the fault detector picks up. If none of the above four conditions occur within 40 ms of the differential protection‘s fault detectors being picked up, the protection treats it as a CT circuit failure. If the logic setting [Opt_CTS_Blk_PcntDiff_Gen] is set as ―1‖, the differential protection will be blocked and an alarm will be issued. If this logic setting is set as ―0‖, the differential protection will trip and an alarm will be issued simultaneously. If the alarm is issued, the signal can be removed only when the failure is removed and the equipment is reset manualy.



3.3.21 VT circuit failure alarm 3.3.21.1 VT circuit of any side failure alarm Operation criterion of this failure is: (1) Positive sequence voltage is less than 18V and any phase current is greater than 0.04 In; (2) Negative sequence voltage U2 is in excess of 8 V. If any one condition occurs, VT circuit failure alarm will be issued with delay 10 s, and the alarm will be removed automatically by delay 10 s when the failure is removed. 3.3.21.2 Voltage balance on generator terminals Two groups of VT are equipped at generator terminal. VT circuit failure can be detected by comparison of phase voltage and positive sequence voltage of these two groups of VT. Operation criterions are:



U AB1 - U AB2  5 V ; U BC1 - U BC2  5 V ; U CA1 - U CA2  5 V ;



(Equation 3.3-23)



U11 - U12  3 V ; Where:



NR ELECTRIC CO., LTD



71



Chapter3 Description of Operation Theory



UAB1, UBC1, UCA1 and U11 are phase-to-phase voltage and positive sequence voltage of VT group 1; UAB2, UBC2, UCA2 and U12 are phase-to-phase voltage and positive sequence voltage of VT group 2. If any of the conditions mentioned above occurs, the VT circuit failure alarm will be issued with a delay of 0.2 s and the VT group used will be switched over. When only a VT fails, it will not influence the functioning of related protection such as loss-of-excitation, out-of-step, overvoltage, over-excitation, reverse power, frequency, impedance protection and overcurrent protection. If only one group of VT is provided at generator‘s terminal, user can set this function to ―disable‖.



3.3.22 Output contacts driven by overcurrent element When a fault occurs at generator terminal and tripping is needed but, if breaking capacity of circuit breaker of generator is not high enough, these breakers shall be blocked until other related cuircuit breakers is tripped before. RCS-985 provides a set of output contacts driven by overcurrent element, which is used to be connected into the tripping circuit of breaker who flow more current than its capacity to be a blocking element before the breaker is tripped. Ia>[I_BO_OC_Gen] Operates Ib>[I_BO_OC_Gen]



≥1



&



Ic>[I_BO_OC_Gen]



[En_BO_OC_Gen]



Figure 3.3-44 Blocking logic diagram of overcurrent element for driving output contact



3.3.23 Mechanical protection Interfaces of mechanical protection such as emergency tripping, failure of condenser vacuum are equipped for the equipment. External protection equipments send those signals to RCS-985G which makes the event record and sends an alarm or tripping command to the relevant circuit breaker with a delay. Enabling binary inputs are provided for those protections. Setting ranges of time delay of those protection are all 0 s – 6000 s.



72



NR ELECTRIC CO., LTD



Chapter4 Self-supervision, metering and records



Chapter4 Self-supervision, metering and records 4.1



Self-supervision



If hardware failure of the equipment is detected, protection functions of the equipment will be blocked and an equipment blocking alarm will be issued. Hardware failure includes those on RAM, EPROM, settings, power supply, DSP and tripping coil. When the following abnormal statuses are detected, an abnormal warning will be issued: AC voltage or current circuit failure, persist pickup, mismatch state of pickup between CPU and DSP and alarm of protection element. The relay includes a number of self-monitoring functions to check the operation of its hardware and software when it is in service. These are included so that if an error or fault occurs within the relay‘s hardware or software, the relay is able to detect and report the problem and attempt to resolve it by performing a re-boot. This involves the relay being out of service for a short period of time that is indicated by the ‗Healthy‘ LED on the faceplate of the relay being off and the watchdog contact at the rear operating. If the restart fails to resolve the problem, then the relay will make itself permanently out of service. Again this will be indicated by the ‗ALARM‘ LED and watchdog contact. If a problem is detected by the self-monitoring functions, the relay attempts to store a maintenance record in battery backed-up SRAM to allow the nature of the problem to be notified to the user. The self-monitoring is implemented in two stages: firstly a thorough diagnostic check which is performed when the relay is booted-up, e.g. at power-on, and secondly a continuous self-checking operation which checks the operation of the relay‘s critical functions during the time it is in service.



4.1.1 Start-up self-testing The self-testing which is carried out when the relay is started takes a few seconds to complete, during which time the relay‘s protection is unavailable. This is signaled by the ‗Healthy‘ LED on the front of the relay which will illuminate when the relay has passed all of the tests and entered operation. If the testing detects a problem, the relay will remain out of service until it is manually restored to working order. The operations that are performed at start-up are as follows: 4.1.1.1 System boot The integrity of the flash memory is verified using a checksum before the program code and the data stored in it is copied into the SRAM to be used for execution by the processor. When the data has been copied to the SRAM, the data is compared to that in the flash to ensure the two are the same and no errors have occurred in the transfer of data from flash to SRAM. The entry point of the software code in SRAM is then called which is the relay initialization code.



NR ELECTRIC CO., LTD



73



Chapter4 Self-supervision, metering and records



4.1.1.2 Initialization software The initialization process includes the operations of initializing the processor registers and interrupts, starting the watchdog timers (used by the hardware to determine whether the software is still running), starting the real-time operating system and creating and starting the supervisor task. In the course of the initialization process the relay checks: • The integrity of the battery backed-up SRAM that is used to store event, fault and disturbance records. • The integrity of the flash that is used to store program. • The correctness of the settings that ensures relay‘s proper response to fault. • The operation of DSP and CPU. • The voltage level of the field voltage supply which is used to drive the opto-isolated inputs. • The operation of the LCD controller. • The watchdog operation. At the conclusion of the initialization software the supervisor task begins the process of starting the platform software. 4.1.1.3 Platform software initialization & monitoring In starting the platform software, the relay checks the integrity of the data held in non-volatile memory with a checksum. The final test that is made concerns the input and output of data, the presence and healthy condition of the input board is checked and the analog data acquisition system is checked through sampling of the reference voltage. At the successful conclusion of all of these tests the relay is entered into service and the protection started-up.



4.1.2 Continuous self-testing When the relay is in service, it continually checks the operation of the critical parts of its hardware and software. The checking is carried out by the system services software and the results reported to the platform software. The functions that are checked are as follows: • The flash containing all program code, setting values and language text is verified by a checksum • The code and constant data held in SRAM is checked against the corresponding data in flash to check for data corruption • The SRAM containing all data other than the code and constant data is verified with a checksum • The level of the field voltage • The integrity of the digital signal I/O data from the opto-isolated inputs and the relay contacts is checked by the data acquisition function every time it is executed. The operation of the analog data acquisition system is continuously checked by the acquisition function every time it is 74



NR ELECTRIC CO., LTD



Chapter4 Self-supervision, metering and records



executed, by means of sampling the reference voltages. In the unlikely event that one of the checks detects an error within the relay‘s subsystems, the platform software is notified and it will attempt to log a maintenance record in the battery backed-up SRAM. If the problem is of no importance (no possibility of leading to mal-operation), the relay will continue in operation. However, for problems detected in any important area the relay will initiate a shutdown and re-boot. This will result in a period of up to 5 seconds when the protection is unavailable, but the complete restart of the relay including all initializations should clear most problems that could occur. As described above, an integral part of the start-up procedure is a thorough diagnostic self-check. If this detects the same problem that caused the relay to restart, i.e. the restart has not cleared the problem; the relay will then make itself permanently out of service. This is indicated by the ‗Healthy‘ LED on the front of the relay, which will be off, and the watchdog contact that will operate. • Voltage transformer supervision (VTS). See section 3.3.21 for detail. • Current transformer supervision (CTS). See section 3.3.20 for detail. If the alarm is issued, the alarm signal can be reset only when the failure is removed and the equipment is reset by pressing ―RESET‖ button on panel or re-power it up. • Overload Alarm On the condition that the relay does not pick up due to adding of current in excess of the setting of the overload protection, an alarm message is displayed and ALARM LED is lit after the timer stage duration has elapsed. • Binary input status monitoring Any status of binary input changing will be monitored. • Tripping output circuit monitoring Tripping output relay driving transistor is always monitored in a normal program, and a blocking message will be issued when the equipment finds abnormality of the tripping output circuit.



4.1.3 List of alarm messages When hardware failure is detected, all protection functions will be blocked and block signal will be sent. The equipment cannot work in this case. Hardware failure such as failure of RAM, error of EEPROM, settings invalid, loss of power source of opto-coupler, error of DSP, tripping output circuit failure, etc, will be issued during which time the relay will be blocked. All the failure alarms can be found on LCD and in event recording report. The following table gives a list of these alarms signals and the behavior of the relay responding to these failures. Note: There are three alarm LEDs on HMI module: ―ALARM‖ LED, ―CT ALARM‖ LED and ―VT ALARM‖ LED. In following tables ―ALARM‖, ―CT ALARM‖ or ―CT ALARM‖ means the corresponding LED is turned on. NR ELECTRIC CO., LTD



75



Chapter4 Self-supervision, metering and records



Abnormality information printed or displayed on LCD and trouble shooting are described in following table. Table 4.1-1 Severe failure alarm list No.



Information (on LCD)



Notes



LED



LED



―HEALTHY‖



―Alarm‖



Off



On



Suggestion



Relay is Blocked?



1.



Alm_RAM_CPUBrd



Note1



2.



Alm_ROM_CPUBrd



Note2



3.



Alm_EEPROM_CPUBrd



Note3



4.



Alm_InvalidSetting



Note4



Note II



5.



Alm_ModifiedSetting



Note5



Note III



6.



Alm_PwrLoss_Opto



Note6



Note IV



7.



Alm_TripOutput



Note7



Note I



8.



Alm_DSP_CPUBrd



Note8



9.



Alm_DSP_MONBrd



Note9



10.



Alm_Sample_CPUBrd



Note10



11.



Alm_Sample_MONBrd



Note11



12.



Alm_RAM_MONBrd



Note12



13.



Alm_ROM_MONBrd



Note13



14.



Alm_EEPROM_MONBrd



Note14



15.



Alm_MONBrd



Note15



16.



Alm_PM_DSP2_CPUBrd



Note16



17.



Alm_PM_DSP1_CPUBrd



Note17



Note I



YES



Note: CPU module RAM damaged. Note2: CPU module flash memory damaged. Note3: CPU module EEPROM damaged judged by the mismatch of summation of all the settings with the CRC code . Note4: Without modifying protection setting after modification of rated secondary current of CT. Note5: In the proceeding of setting parameters. Note6: Loss of power supply of the optical couplers for binary inputs. Note7: Driving transistor of binary output damaged. Note8: The DSP chip in CPU board damaged. Note9: The DSP chip in MON board damaged. Note10: Failure of sampled data in CPU board. Note11: Failure of sampled data in MON board. Note12: MON module RAM damaged. Note13: MON module flash memory damaged. Note14: MON module EEPROM damaged. Note15: MON module damaged. Note16: The DSP2 chip on CPU board damaged. Note1:



76



NR ELECTRIC CO., LTD



Chapter4 Self-supervision, metering and records Note17: NoteI: NoteII: NoteIII: NoteIV:



The DSP1 chip on CPU board damaged. Inform manufacturer for maintenance. Modify and check protection setting again. Do nothing except waiting for completion of the process. Check if the power circuit of OPT module is connected correctly with DC module. Table 4.1-2 Common failure alarm list



No.



Information (on LCD)



Notes



LED



LED



―HEALTHY‖



―Alarm‖



On



On



Suggestion



Relay is Blocked?



1.



Alm_Inconsist_MechRly



Note1



2.



Note2



3.



Alm_PwrLoss_MechRly Alm_InconsistFD



Note3



Note II



4.



Alm_PersistFD_CPUBrd



Note4



Note III



5.



Alm_PersistFD_MONBrd



Note5



6.



Note6



Note IV



7.



Alm_BI_CPUBrd Alm_InnerComm



Note7



Note V



8.



Alm_Pos_GCB



Note8



Note VI



Note I



No



Note: Alarm of the mechanical protection due to inconsistance of input signal and repeated output signal. Note2: The power supply of mechanical protection is lost. Note3: Mismatch of pickup of same type fault detectors in CPU and MON. Note4: Duration of pickup of any fault detector in CPU board is in excess of 10s. Note5: Duration of pickup of any fault detector in MON board is in excess of 10s. Note6: Any one of binary input sampled directly doesn‘t match with that of reorganization of protection itself. Note7: Alarm indicating that the communication between MON and CPU interrupts. Note8: The sampled statuses of auxiliary contact of generator terminal breaker‘s don‘t match with that of operation condition identified from calculation of voltage and currents. Note1:



Check and recover the power supply of mechanical protection. NoteII: Check the difference of sampled value in CPU and MON board. NoteIII: Check and ensure that settings are not too low and secondary circuit of VT or CT is in proper working condition. NoteIV: Check and ensure the auxiliary contact of breaker position is in good working condition. NoteV: Check the cable used for connecting the CPU and MON board and ensure no interruption exist. NoteVI: Check the auxiliary contact of generator terminal breaker and ensure its proper working condition. NoteI:



Table 4.1-3 Alarm list of secondary circuit of VT and CT



NR ELECTRIC CO., LTD



77



Chapter4 Self-supervision, metering and records No.



Information (on LCD)



Notes



1.



Alm_SwOv_VTS1_Gen



Note1



2.



Alm_SwOv_VTS2_Gen



Note2



3.



Alm_BlkV3rdHDiff_VTS1



Note3



4.



Alm_BlkIntTurn_VTS2



Note4



5.



Alm_VTS_HVS_Tr



Note5



6.



Alm_VTS1_Term_Gen



Note6



7.



Alm_VTS2_Term_Gen



Note7



8.



Alm_VTS_NP_Gen



Note8



9.



Alm_DeltVTS1_Term_Gen



Note9



10.



Alm_DeltVTS2_Term_Gen



Note10



11.



Alm_VTS_LossExc_RotWdg



Note11



12.



Alm_CTS_SpareCT_Gen



Note12



13.



Alm_CTS_Term_Gen



Note13



14.



Alm_CTS_NP_Gen



Note14



15.



Alm_CTS_SP1_Gen



Note15



16.



Alm_CTS_SP2_Gen



Note16



17.



Alm_Diff_Gen



Note17



18.



Alm_SPTDiff_Gen



Note18



19.



Alm_CTS_Diff_Gen



Note19



20.



Alm_CTS_SPTDiff_Gen



Note20



21.



Alm_CTS_S1_Exc



Note21



22.



Alm_CTS_S2_Exc



Note22



23.



Alm_Diff_ET



Note23



24.



Alm_Diff_Exciter



Note24



25.



Alm_CTS_Diff_ET



Note25



26.



Alm_CTS_Diff_Exciter



Note26



LED



LED



―HEALTHY‖



―Alarm‖



On



On



Suggestion



Relay is Blocked?



Note I



No



Note: Alarm indicating VT1 circuit failure and start to switch over voltage circuit. Alarm indicating VT2 circuit failure and start to switch over voltage circuit. Note3: Alarm indicating VT1 circuit failure and blocking 3rd harmonics voltage differential protection. Note4: Alarm indicating VT2 circuit failure and blocking interturn protection. Note5: Alarm indicating secondary circuit failure of VT at HV side of main transformer. Note6: Alarm indicating secondary circuit failure of VT1 at generator terminal. Note7: Alarm indicating secondary circuit failure of VT2 at generator terminal. Note8: Alarm indicating secondary circuit failure of VT at the neutral point of generator. Note1: Note2:



78



NR ELECTRIC CO., LTD



Chapter4 Self-supervision, metering and records



Alarm indicating secondary circuit failure at open-delta side of VT1 at generator terminal. Note10: Alarm indicating secondary circuit failure at open-delta side of VT2 at generator terminal. Note11: Alarm indicating rotor voltage circuit failure which used by loss-of-excitation protection. Note12: Alarm indicating secondary circuit abnormality of spare CT at generator terminal. Note13: Alarm indicating secondary circuit abnormality of CT at generator terminal. Note14: Alarm indicating secondary circuit abnormality of CT at the neutral point of generator. Note15: Alarm indicating secondary circuit abnormality of CT installed in splitting-phase branch1 at the neutral point of generator . Note16: Alarm indicating secondary circuit abnormality of CT installed in splitting-phase branch2 at the neutral point of generator. Note17: Alarm indicating differential current of generator is in excess of normally endurable level. Note18: Alarm indicating splitting-phase transverse differential current of generator is in excess of normally endurable level. Note19: Alarm indicating secondary circuit failure of CTs used for differential protection. Note20: Alarm indicating secondary circuit failure of CTs used for splitting-phase transverse differential protection. Note21: Alarm indicating secondary circuit failure of CT at side1 of excitation set used in differential protection of excitation. Note22: Alarm indicating secondary circuit failure of CT at side2 of excitation set used in differential protection of excitation. Note23: Alarm indicating differential current of excitation transformer is in excess of normally endurable level. Note24: Alarm indicating differential current of exciter is in excess of normally endurable level. Note25: Alarm indicating secondary circuit failure of CT used in excitation transformer differential protection. Note26: Alarm indicating secondary circuit failure of CT used in exciter differential protection. NoteI: Locate the position of failure by checking sampled data in protection and secondary circuit to decide the maintenance scheme. Note9:



Table 4.1-4 Alarm list of protective elements No.



Information (on LCD)



Notes



1.



Alm_DPFC_IntTurn_Gen



Note1



2.



Alm_BO_OC_Term_Gen



Note2



3.



Alm_On_2PEF_RotWdg



Note3



4.



Alm_Ext_OOS_Gen



Note4



5.



Alm_Int_OOS_Gen



Note5



6.



Alm_Accel_OOS_Gen



Note6



7.



Alm_Decel_OOS_Gen



Note7



8.



Alm_LossExc_Gen



Note8



9.



Alm_OvExc_Gen



Note9



10.



Alm_OvLd_Sta



Note10



NR ELECTRIC CO., LTD



LED



LED



―HEALTHY‖



―Alarm‖



On



On



Suggestion



Relay is Blocked?



Note I



No



79



Chapter4 Self-supervision, metering and records 11.



Alm_NegOC_Gen



Note11



12.



Alm_OvLd_RotWdg



Note12



13.



Alm_ROV_Sta



Note13



14.



Alm_V3rdHRatio_Sta



Note14



15.



Alm_V3rdHDiff_Sta



Note15



16.



Alm_Sens_1PEF_RotWdg



Note16



17.



Alm_1PEF_RotWdg



Note17



18.



Alm_UF1_Gen



Note18



19.



Alm_UF2_Gen



Note19



20.



Alm_UF3_Gen



Note20



21.



Alm_OF1_Gen



Note21



22.



Alm_OF2_Gen



Note22



23.



Alm_RevP_Gen



Note23



24.



Alm_MechRly4



Note24



25.



Alm_MechRly3



Note25



26.



Alm_MechRly2



Note26



27.



Alm_MechRly1



Note27



Note: Alarm indicating operation of DPFC interturn protective element. Note2: Alarm indicating operation of overcurrent element used for driving a set of contact to block other circuit. Note3: Alarm indicating 2 points earth fault protection has been put input operation after operation of 1 point earth fault protection of rotor. Note4: Alarm indicating out-of-step of system occurs while its oscillation center is outside protective zone. Note5: Alarm indicating out-of-step of system occurs and its oscillation center is inside protective zone. Note6: Alarm indicating accelerate out-of-step occurs. Note7: Alarm indicating decelerate out-of-step occurs. Note8: Alarm indicating operation of loss-of-excitation protective element. Note9: Alarm indicating operation of over excitation protective element. Note10: Alarm indicating operation of overload element of stator. Note11: Alarm indicating operation of negative overcurrent protective element of stator. Note12: Alarm indicating operation of overload protective element of rotor. Note13: Alarm indicating operation of fundamental zero-sequence overvoltage earth fault protective element of stator. rd Note14: Alarm indicating operation of 3 harmonics ratio earth fault protective element of stator. rd Note15: Alarm indicating operation of 3 harmonics differential earth fault protective element of stator. Note1:



80



NR ELECTRIC CO., LTD



Chapter4 Self-supervision, metering and records Note16:



Alarm indicating operation of sensitive stage of 1 point earth fault protective element of



rotor. Note17:



Alarm indicating operation of normal stage of 1 point earth fault protective element of



rotor. Alarm indicating operation of stage 1 of under frequency protective element of generator. Note19: Alarm indicating operation of stage 2 of under frequency protective element of generator. Note20: Alarm indicating operation of stage 3 of under frequency protective element of generator. Note21: Alarm indicating operation of stage 1 of over frequency protective element of generator. Note22: Alarm indicating operation of stage 2 of over frequency protective element of generator. Note23: Alarm indicating operation of reverse power protective element of generator. Note24: Alarm indicating operation of mechanical repeater 4. In this project, this alarm means operation of stage 2 of 1PEF of rotor. Note25: Alarm indicating operation of mechanical repeater 3. In this project, this alarm means operation of stage 1 of 1PEF of rotor. Note26: Alarm indicating operation of mechanical repeater 2. In this project, this alarm means failure of condenser vacuum. Note27: Alarm indicating operation of mechanical repeater 1. In this project, this alarm means operation of manual emergency tripping. NoteI: Treat according to specific application requirement. Note18:



4.2



Metering



The relay produces a variety of both directly and calculated power system quantities. These measurement values are updated on a per half second basis and can be viewed in the menu ―VALUES‖ of the relay or via relay communication. This relay is able to measure and display the following quantities as summarized:



4.2.1 Measured voltages and currents The relay produces both phase-to-ground and phase-to-phase voltage and current values. They are produced directly from the DFT (Discrete Fourier Transform) used by the relay protection functions and present both magnitude and phase angle measurement.



4.2.2 Sequence voltages and currents Sequence quantities are produced by the relay from the measured Fourier values; these are displayed as magnitude and phase angle values.



4.2.3 Rms. voltages and currents Rms. phase voltage and current values are calculated by the relay using the sum of the samples squared over a cycle of sampled data.



4.2.4 Differential current and relevant quantities Differential current and restrained current calculated in differential protection is displayed to user for monitoring the correctness of operation or testing of the differential protection.



NR ELECTRIC CO., LTD



81



Chapter4 Self-supervision, metering and records



4.2.5 Phase angles Calculated phase angles are also displayed on LCD to help user to check the correctness of CT or VT circuit.



4.2.6 Measurement display quantities Here are ―VALUES‖ available in the relay for viewing of measurement quantities. All the measurement quantities can be divided into CPU quantities or DSP quantities by their origin where they are derived. These can also be viewed with RCSPC (see RCSPC User Manual) and are shown below:



4.2.7 All metering data displayed on LCD 4.2.7.1 Differential current and related values in CPU and MON



GEN DIFF CURR Id_Diff_Gen:



000.00 000.00 000.00 Ie



Ir_Diff_Gen:



000.00 000.00 000.00 Ie



I_Term_Gen:



000.00 000.00 000.00 A



I1_Term_Gen:



000.00 A



I2_Term_Gen:



000.00 A



I0_Term_Gen:



000.00 A



I_NP_Gen:



000.00 000.00 000.00 A



I1_NP_Gen:



000.00 A



Gen Diff Curr I2_NP_Gen: I0_NP_Gen: I_BakCT_Gen:



000.00 A 000.00 000.00 000.00 A



I1_BakCT_Gen:



000.00 A



I2_BakCT_Gen:



000.00 A



I0_BakCT_Gen:



000.00 A



I_PwrProt_Gen:



000.00 000.00 000.00 A



I1_PwrProt_Gen:



82



000.00 A



000.00 A



NR ELECTRIC CO., LTD



Chapter4 Self-supervision, metering and records



Gen Diff Curr I2_PwrProt_Gen:



000.00 A



I0_PwrProt_Gen:



000.00 A



Figure 4.2-1 Differential current and related values in CPU and MON Where: [Ie]: secondary calculated rated current of generator. [Id_Diff_Gen]: Phase A, B and C of per unit value of generator differential current. [Ir_Diff_Gen]: Phase A, B and C of per unit value of generator restraint current. [I_Term_Gen]: Phase A, B and C of current derived from CT at generator‘ terminal. [I1_Term_Gen]: Positive sequence current of generator terminal. [I2_Term_Gen]: Negative sequence current of generator terminal. [I0_Term_Gen]: Calculated zero sequence current of generator terminal. [I_NP_Gen]: Phase A, B and C of current derived from CT at generator‘ neutral point. [I1_NP_Gen]: Positive sequence current of generator neutral point. [I2_NP_Gen]: Negative sequence current of generator neutral point. [I0_NP_Gen]: Calculated zero sequence current of generator neutral point. [I_BakCT_Gen]: Phase A, B and C of current derived from backup CT at generator‘ terminal. [I1_BakCT_Gen]: Positive sequence component of the current derived from backup CT at generator neutral point. [I2_BakCT_Gen]: Negative sequence component of the current derived from backup CT at generator neutral point. [I0_BakCT_Gen]: Calculated zero sequence component of the current derived from backup CT at generator neutral point. Access path in menu is ―VALUES CPU METERINGGEN DIFF CURR‖ and ―VALUES MON



NR ELECTRIC CO., LTD



83



Chapter4 Self-supervision, metering and records



METERINGGEN DIFF CURR‖. Note: The contents inside the first window are the default display seen by user entering this submenu. User can navigate to the following items (as shown in the other two windows) by scrolling the arrow keys on the faceplate of the relay. What user meets similar to this case later can be dealt with in same way. 4.2.7.2 Transverse differential current and related values in CPU and MON



GEN TRVDIFF CURR Id_TrvDiff_Gen:



000.00 A



Id_3rdH_TrvDiff_Gen:



000.00 A



Id_SPTDiff_Gen:



000.00 000.00 000.00 Ie



Ir_SPTDiff_Gen:



000.00 000.00 000.00 Ie



Icorr_SP1_Gen:



000.00 000.00 000.00 Ie



Icorr_SP2_Gen:



000.00 000.00 000.00 Ie



I_SP1_Gen:



000.00 000.00 000.00 A



I1_SP1_Gen:



000.00 A



GEN TRVDIFF CURR I2_SP1_Gen:



000.00 A



I0_SP1_Gen:



000.00 A



I_SP2_Gen:



000.00 000.00 000.00 A



I1_SP2_Gen:



000.00 A



I2_SP2_Gen:



000.00 A



I0_SP2_Gen:



000.00 A



Figure 4.2-2 Transverse differential current and related values in CPU and MON Where: [Id_TrvDiff_Gen]: transverse differential current of generator. [Id_3rdH_TrvDiff_Gen]: 3rd harmonics component of transverse differential current. [Id_SPTDiff_Gen]: Phase A, B and C of per unit value of phase-splitting transverse differential 84



NR ELECTRIC CO., LTD



Chapter4 Self-supervision, metering and records



current of generator. [Ir_SPTDiff_Gen]: Phase A, B and C of per unit value of restraint current of phase-splitting transverse differential protection. [Icorr_SP1_Gen]: Phase A, B and C of per unit value of branch1‘s corrected current. [Icorr_SP2_Gen]: Phase A, B and C of per unit value of branch2‘s corrected current. [I_SP1_Gen]: Phase A, B and C of splitted branch1‘s current. [I1_SP1_Gen]: Splitted branch1‘s positive sequence current. [I2_SP1_Gen]: Splitted branch1‘s negative sequence current. [I0_SP1_Gen]: Splitted branch1‘s zero sequence current. [I_SP2_Gen]: Phase A, B and C of Splitted branch2‘s current. [I1_SP2_Gen]: Splitted branch2‘s positive sequence current. [I2_SP2_Gen]: Splitted branch2‘s negative sequence current. [I0_SP2_Gen]: Splitted branch2‘s zero sequence current. Access path in menu is ―VALUES CPU METERING GEN TRVDIFF CURR‖ and VALUES MON METERING GEN TRVDIFF CURR‖. 4.2.7.3 Voltages and related values in CPU and MON



GEN VOLTAGE U_VT1_Term_Gen: U1_VT1_Term_Gen:



000.00 V



U2_VT1_Term_Gen:



000.00 V



U0_VT1_Term_Gen:



000.00 V



U_VT2_Term_Gen:



NR ELECTRIC CO., LTD



000.00 000.00 000.00 V



000.00 000.00 000.00 V



U1_VT2_Term_Gen:



000.00 V



U2_VT2_Term_Gen:



000.00 V



U0_VT2_Term_Gen:



000.00 V



85



Chapter4 Self-supervision, metering and records



GEN VOLTAGE Upp_VT1_Term_G:



000.00 000.00 000.00 V



Upp_VT2_Term_G:



000.00 000.00 000.00 V



U0_DeltVT1_Term_Gen:



000.00 V



U0_NP_Gen:



000.00 V



U0_3rdH_VT1_Term_G:



000.00 V



U0_3rdH_NP_Gen:



000.00 V



Ud_3rdH_Sta:



000.00 V



U0_Longl_Gen:



000.00 V



GEN VOLTAGE U0_3rdH_Longl_Gen:



000.00 V



U_Busbar:



000.00 V



Figure 4.2-3 Voltages and related values in CPU and MON Where: [U_VT1_Term_Gen]: Phase A, B and C of voltage derived from VT1 at the generator‘s terminal. [U1_VT1_Term_Gen]: Calculated positive sequence voltage of VT1. [U2_VT1_Term_Gen]: Calculated negative sequence voltage of VT1. [U0_VT1_Term_Gen]: Calculated zero sequence voltage of VT1. [U_VT2_Term_Gen]: Phase A, B and C of voltage derived from VT2 at the generator‘s terminal. [U1_VT2_Term_Gen]: Calculated positive sequence voltage of VT2. [U2_VT2_Term_Gen]: Calculated negative sequence voltage of VT2. [U0_VT2_Term_Gen]: Calculated zero sequence voltage of VT2. [Upp_VT1_Term_G]: Phase-to-phase voltage of VT1—Uab, Ubc, Uca.



86



NR ELECTRIC CO., LTD



Chapter4 Self-supervision, metering and records



[Upp_VT2_Term_G]: Phase-to-phase voltage of VT2—Uab, Ubc, Uca. [U0_DeltVT1_Term_Gen]: Zero sequence voltage derived from open-delta side of VT1 at the generator‘s terminal. [U0_NP_Gen]: Zero sequence voltage derived from open-delta side of VT at the neutral point of generator. [U0_3rdH_VT1_Term_Gen]: Calculated 3rd harmonics of VT1 at the generator‘s terminal. [U0_3rdH_VT_NP_Gen]: Calculated 3rd harmonics of VT at the neutral point of generator. [Ud_3rdH_Sta]: 3rd harmonics differential voltage between the terminal and the neutral point of generator. [U0_Longl_Gen]: Longitude zero sequence voltage of generator. [U0_3rdH_Longl_Gen]: 3rd harmonics voltage in longitude zero voltage. [U_Busbar]: Single phase voltage derived from busbar voltage transformer. Access path in menu is ―VALUES CPU METERING GEN VOLTAGE‖ and VALUES MON METERING GEN VOLTAGE‖. 4.2.7.4 Misc metering quantities of generator in CPU and MON



GEN MISC VALUES



NR ELECTRIC CO., LTD



P_Gen:



+ 000.00 %



Q_Gen:



+ 000.00 %



Accu_InvOvLd_Sta:



000.00 %



Accu_InvNegOC_Gen:



000.00 %



U/F_OvExc_Gen:



00.000



Accu_InvOvExc_Gen:



000.00 %



f_Gen:



000.00 Hz



Accu_UF1_Gen:



000.00 Min



87



Chapter4 Self-supervision, metering and records



GEN MISC VALUES Accu_UF2_Gen:



000.00 Min



U1_2ndH_VT1_Term_Gen:



000.00 V



U2_2ndH_VT1_Term_Gen:



000.00 V



Figure 4.2-4 Misc metering quantities of generator Where: [P_Gen]: Active power of generator. [Q_Gen]: Reactive power of generator. [Accu_InvOvLd_Sta]: Accumulation of thermal due to overload of stator. [Accu_InvNegOC_Gen]: Accumulation of thermal due to negative sequence current through stator result from interaction between rotor and stator. [U/F_OvExc_Gen]: Calculated ratio of per unit values of voltage and frequency. [Accu_InvOvExc_Gen]: Accumulation of thermal due to overexcitation of generator. [f_Gen]: real-time calculated frequency of generator. [Accu_UF1_Gen]: Accumulation of underfrequency condition time of generator to decide operation of state 1 of underfrequency protection. [Accu_UF2_Gen]: Accumulation of underfrequency condition time of generator to decide operation of state 1 of underfrequency protection. [U1_2ndH_VT1_Term_Gen]: Positive sequence voltage of 2nd harmonics voltage of stator derived from VT1 at the generator‘s terminal. [U2_2ndH_VT1_Term_Gen]: Negative sequence voltage of 2nd harmonics voltage of stator derived from VT1 at the generator‘s terminal. Access path in menu is ―VALUES CPU METERING GEN MISC VALUES‖ and VALUES MON METERING GEN MISC VALUES‖.



88



NR ELECTRIC CO., LTD



Chapter4 Self-supervision, metering and records



4.2.7.5 Rotor Winding Metering in CPU and MON



RotWdg METERING U(+)_RotWdg:



0000.0 V



U(-)_RotWdg:



0000.0 V



U_RotWdg:



0000.0 V



Rg_RotWdg:



000.00 kΩ



Location_EF_RotWdg:



050.00 %



I_RotWdg:



-0000



I_Exc:



000.00 A



Accu_InvOvLd_RotWdg:



A



000.00 %



Figure 4.2-5 Rotor Winding Metering quantities of generator Where: [U(+)_RotWdg]: voltage of positive pole of rotor to ground. [U(-)_RotWdg]: voltage of negative pole of rotor to ground. [U_RotWdg]: voltage of positive pole of rotor to negative pole. [Rg_RotWdg]: calculated grounded resistance of rotor. [Location_EF_RotWdg]: the position of earth fault in rotor. [I_RotWdg: excitation current through rotor winding. [I_Exc]: alternative excitation current on the rectifier‘s AC side [Accu_InvOvLd_RotWdg]: accumulation of thermal of rotor winding. Access path in menu is ―VALUES CPU METERING RotWdg METERING‖ and VALUES MON METERING ROTWDG METERING‖.



NR ELECTRIC CO., LTD



89



Chapter4 Self-supervision, metering and records



4.2.7.6 Excitation System Metering in CPU and MON



EXC AC METERING Id_Diff_Exc:



000.00 000.00 000.00 Ie



Ir_Diff_Exc:



000.00 000.00 000.00 Ie



Id_2ndH_Exc:



000.00 000.00 000.00 Ie



Icorr_S1_Exc:



000.00 000.00 000.00 Ie



Icorr_S2_Exc:



000.00 000.00 000.00 Ie



I_S1_Exc:



000.00 000.00 000.00 A



I1_S1_Exc:



000.00 A



I2_S1_Exc:



000.00 A



EXC AC METERING I0_S1_Exc:



I_S2_Exc:



000.00 A 000.00 000.00 000.00 A



I1_S2_Exc:



000.00 A



I2_S2_Exc:



000.00 A



I0_S2_Exc:



00.00 A



Figure 4.2-6 Excitation System metering of generator Where: [Id_Diff_Exc]: Phase A, B and C of differential current of excitation transformer or exciter. [Ir_Diff_Exc]: Phase A, B and C of restraint current of excitation transformer or exciter. [Id_2ndH_Exc]: Phase A, B and C of 2nd harmonics component in differential current of excitation transformer or exciter. [Icorr_S1_Exc]: Phase A, B and C of corrected current on the high voltage side of excitation transformer or terminal side of exciter (Side 1). [Icorr_S2_Exc]: Phase A, B and C of corrected current on the low voltage side of excitation transformer or neutral point side of exciter (Side 2). [I_S1_Exc]: Phase A, B and C current on side 1 of excitation transformer or exciter.



90



NR ELECTRIC CO., LTD



Chapter4 Self-supervision, metering and records



[I1_S1_Exc]: Positive sequence current of side 1 of excitation transformer or exciter. [I2_S1_Exc]: negative sequence current of side 1 of excitation transformer or exciter. [I0_S1_Exc]: zero sequence current of side 1 of excitation transformer or exciter. [I_S2_Exc]: Phase A, B and C current on side 2 of excitation transformer or exciter. [I1_S2_Exc]: Positive sequence current of side 2 of excitation transformer or exciter. [I2_S2_Exc]: negative sequence current of side 2 of excitation transformer or exciter. [I0_S2_Exc]: zero sequence current of side 2 of excitation transformer or exciter. Access path in menu is ―VALUES CPU METERING EXC AC METERING‖ and VALUES MON METERING EXC AC METERING‖. 4.2.7.7 Phase Angle of Generator‘ relevant quantities



GEN PH ANG φ_Term_&_NP_Gen:



000 000 000



o



φ_SP1_&_SP2_Gen:



000 000 000



o



φipp_Term_Gen:



000 000 000



o



φipp_NP_Gen:



000 000 000



o



φipp_PwrProt_Gen:



000 000 000



o



φipp_SP1_Gen:



000 000 000



o



φipp_SP2_GenTV1:



000 000 000



o



φvpp_VT1_Term_Gen:



000 000 000



o



GEN PH ANG φvpp_VT2_Term_Gen:



000 000 000



o



φv_VT1_&_VT2_Gen:



000 000 000



o



φ_V3rdH_Gen:



000.0



o



φvi_Term_Gen:



000 000 000



o



φvi_Term_&_Bak_Gen:



000 000 000



o



Figure 4.2-7 Excitation System metering of generator Where: NR ELECTRIC CO., LTD



91



Chapter4 Self-supervision, metering and records



[φ_Term_&_NP_Gen]：phase angle between same-phase currents derived from CT at generator‘s terminal and at generator‘s neutral point. [φ_SP1_&_SP2_Gen]: phase angle between same-phase currents derived from CT at phase-splitting branch 1 and branch2. [φipp_Term_Gen]: phase angle between phase A and B, B and C, C and A of current derived from CT at generator‘s terminal. [φipp_NP_Gen]: phase angle between phase A and B, B and C, C and A of current derived from CT at generator‘s neutral point. [φipp_PwrProt_Gen]: phase angle between phase A and B, B and C, C and A of current specially used for power protection. [φipp_SP1_Gen]: phase angle between phase A and B, B and C, C and A of current derived from CT at the phase-splitting branch 1. [φipp_SP2_Gen]: phase angle between phase A and B, B and C, C and A of current derived from CT at the phase-splitting branch 2. [φvpp_VT1_Term_Gen]: phase angle between phase A and B, B and C, C and A of voltage derived from VT1 at generator‘s terminal. [φvpp_VT2_Term_Gen]: phase angle between phase A and B, B and C, C and A of voltage derived from VT2 at generator‘s terminal. [φv_VT1_&_VT2_Gen]: phase angle between same-phase voltages derived from VT1 and VT2 at generator‘s terminal. [φ_V3rdH_Gen]: phase angle between phase A and B, B and C, C and A of 3rd harmonics voltage derived from VT1 at generator‘s terminal. [φvi_Term_Gen]: phase angle between same-phase voltage and current of generator‘s terminal. [φvi_Term_&_Bak_Gen]: phase angle between same-phase voltage from VT1 and current derived from spare CT at generator‘s terminal. Access path in menu is ―VALUES PHASE ANGLE GEN PH ANG‖.



92



NR ELECTRIC CO., LTD



Chapter4 Self-supervision, metering and records



4.2.7.8 Phase Angle of excitation relevant quantities



EXC PH ANG φi_S1_&_S2_Exc:



000 000 000



o



φipp_S1_Exc:



000 000 000



o



φipp_S2_Exc:



000 000 000



o



Figure 4.2-8 Excitation System metering of generator Where: [φi_S1_&_S2_Exc]: phase angle between same-phase currents derived from CT at generator‘s terminal and that at generator‘s neutral point [φipp_S1_Exc]: phase angle between phase A and B, B and C, C and A of current derived from CT at side 1 of excitation transformer or exciter. [φipp_S2_Exc]: phase angle between phase A and B, B and C, C and A of current derived from CT at side 2 of excitation transformer or exciter. Access path in menu is ―VALUES PHASE ANGLE EXC PH ANG‖.



4.3



Signaling



Signals here mean changes of binary inputs. All these signals can be displayed on LCD, locally printed or sent to automation system of substation via communication channel.



NR ELECTRIC CO., LTD



93



Chapter4 Self-supervision, metering and records



4.3.1 Enabling Binary Inputs of generator



GEN PROT EBI EBI_Diff_Gen:



0



EBI_SPTDiff_Gen:



0



EBI_PPF_Gen:



0



EBI_IntTurn_Gen:



0



EBI_ROV&ROC_Sta: :



0



EBI_V3rdH_Sta:



0



EBI_1PEF_RotWdg:



0



EBI_2PEF_RotWdg:



0



GEN PROT EBI EBI_FreqProt_Gen:



0



EBI_OvLd_Sta:



0



EBI_NegOC_Sta:



0



EBI_LossExc_Gen:



0



EBI_OOS_Gen:



0



EBI_VoltProt_Gen:



0



EBI_OvExc_Gen:



0



EBI_PwrProt_Gen:



0



Prot EBI Status EBI_AccEnerg_Gen:



0



EBI_SeqTrpRevP_Gen:



0



EBI_StShut_Gen:



0



EBI_BFP_GCB:



0



Figure 4.3-1 Enabling Binary Inputs of generator protection Where: 94



NR ELECTRIC CO., LTD



Chapter4 Self-supervision, metering and records



[EBI_Diff_Gen]：Enabling binary input of differential protection of generator. [EBI_SPTDiff_Gen]: Enabling binary input of coast protection of generator. [EBI_PPF_Gen]： Enabling binary input of phase-to-phase backup protection of generator. [EBI_IntTurn_Gen]：Enabling binary input of interturn protection of generator. [EBI_ROV_Sta]: Enabling binary input of zero sequence overvoltage protection of stator. [EBI_V3rdH_Sta]: Enabling binary input of 3rd harmonics voltage protection of generator. [EBI_1PEF_RotWdg]: Enabling binary input of 1 point earth fault protection of rotor. [EBI_2PEF_RotWdg]: Enabling binary input of 2 points earth fault protection of rotor. [EBI_OvLd_Sta]: Enabling binary input of overload protection of stator. [EBI_NegOC_Gen]: Enabling binary input of negative overcurrent protection of stator. [EBI_LossExc_Gen]: Enabling binary input of loss-of-excitation protection of generator. [EBI_OOS_Gen]: Enabling binary input of out-of-step protection of generator. [EBI_VoltProt_Gen]: Enabling binary input of overvoltage and undervoltage protection of generator. [EBI_OvExc_Gen]: Enabling binary input of overexcitation protection of generator. [EBI_PwrProt_Gen]: Enabling binary input of power protection of generator. [EBI_FreqProt_Gen]: Enabling binary input of overfrequency and underfrequency protection of generator. [EBI_AccEnerg_Gen]: Enabling binary input of accidental energization protection of generator. [EBI_SeqTrpRevP_Gen]: Enabling binary input of sequence tripping reverse power protection of generator. [EBI_StShut_Gen]: Enabling binary input of startup and shutdown protection of generator. [EBI_BFP_GCB]: Enabling binary input of breaker failure protection of generator. Access path in menu is ―VALUES CPU BI STATE  GEN PROT EBI‖ and ―VALUES MON BI STATE  GEN PROT EBI‖.



NR ELECTRIC CO., LTD



95



Chapter4 Self-supervision, metering and records



4.3.2 Enabling Binary Inputs of excitation protection



EXC PROT EBI EBI_Diff_Exc:



0



EBI_Bak_Exc:



0



EBI_OvLd_Exc:



0



Figure 4.3-2 Enabling Binary Input list of excitation protection Where: [EBI_Diff_Exc]: Enabling binary input of differential protection of excitation transformer of exciter. [EBI_Bak_Exc]: Enabling binary input of backup protection of excitation transformer of exciter. [EBI_OvLd_Exc]: Enabling binary input of overload protection of excitation transformer of exciter.. Access path in menu is ―VALUES CPU BI STATE  EXC PROT EBI‖ and ―VALUES MON BI STATE  EXC PROT EBI‖.



4.3.3 Binary Inputs of mechanical protection



Mech Prot BI EBI_Trp_MechRly1:



0



EBI_Trp_MechRly2:



0



EBI_Trp_MechRly3:



0



EBI_Trp_MechRly4:



0



BI_MechRly1:



0



BI_MechRly2:



0



BI_MechRly3:



0



BI_MechRly4:



0



Figure 4.3-3 Binary Inputs of mechanical protection



96



NR ELECTRIC CO., LTD



Chapter4 Self-supervision, metering and records



Where: [EBI_Trp_MechRly 1]: Enabling binary input of mechanical protection to allow mechanical repeater 1 (manual emergency tripping) to initial tripping. [EBI_Trp_MechRly 2]: Enabling binary input of mechanical protection to allow mechanical repeater 2 (failure of condenser vacuum) to initial tripping. [EBI_Trp_MechRly 3]: Enabling binary input of mechanical protection to allow mechanical repeater 3 (stage 1 of 1PEF of rotor) to initial tripping. [EBI_Trp_MechRly 4]: Enabling binary input of mechanical protection to allow mechanical repeater 4 (stage 2 of 1PEF of rotor) to initial tripping. [BI_MechRly 1]: Binary input indicating operation of mechanical repeater 1(manual emergency tripping). [BI_MechRly 2]: Binary input indicating operation of mechanical repeater 2(failure of condenser vacuum). [BI_MechRly 3]: Binary input indicating operation of mechanical repeater 3(stage 1 of 1PEF of rotor). [BI_MechRly 4]: Binary input indicating operation of mechanical repeater 4(stage 2 of 1PEF of rotor). Access path in menu is ―VALUES CPU BI STATE  EXC PROT EBI‖ and ―VALUES MON BI STATE  EXC PROT EBI‖.



4.3.4 Auxiliary Contacts



AUX BI BI_52b_GCB:



0



BI_ExtProtTrp:



0



BI_Valve_Turbine:



0



BI_UrgBrake:



0



BI_SyncCondenser:



0



BI_Pwr_Superv:



0



Figure 4.3-4 Auxiliary Contacts for used in protection logic Where: [BI_52b_GCB]：Binary input of auxiliary contact of open position of circuit breaker at generator‘s NR ELECTRIC CO., LTD



97



Chapter4 Self-supervision, metering and records



terminal. [BI_ExcProtTrp]: Binary input indicating the external trip contact of other protection is closed. [BI_Valve_Turbine]: Binary input indicating the valve of steam turbine is in close position. [BI_UrgBrake]: Binary input indicating the operation of urgent brake of generator.. [BI_SyncCondenser]: Binary input indicating the synchronous condenser is put into operation. [BI_Pwr_Superv]: Binary input indicating the power supply for all binary input circuit is working in good condition. Access path in menu is ―VALUES CPU BI STATE  AUX BI‖ and ―VALUES MON BI STATE  AUX BI‖.



4.3.5 Internally generated binary inputs by MON



INTER GENERATED BI FD_Diff_Gen:



0



FD_EF_Sta:



0



FD_EF_RotWdg:



0



FD_OvLd_Sta:



0



FD_PPF_Gen:



0



FD_Volt&OvExc_Gen:



0



FD_FreqProt_Gen: FD_LossExc&OOS_Gen:



0 0



INTER GENERATED BI FD_Pwr&AccEnerg_Gen:



0



FD_StShut_Gen:



0



FD_Prot_Exc:



0



FD_MechRly:



0



Figure 4.3-5 Auxiliary Contacts for used in protection logic Where: 98



NR ELECTRIC CO., LTD



Chapter4 Self-supervision, metering and records



[FD_Diff_Gen]：Internally generated binary input indicating operation of fault detector of differential protection of generator. [FD_EF_Sta]: Internally generated binary input indicating operation of fault detector of earth fault protection of stator. [FD_EF_RotWdg]: Internally generated binary input indicating operation of fault detector of earth fault protection of rotor. [FD_OvLd_Sta]: Internally generated binary input indicating operation of fault detector of overload protection of stator. [FD_PPF_Gen]: Internally generated binary input indicating operation of fault detector of backup protection of generator. [FD_Volt&OvExc_Gen]: Internally generated binary input indicating operation of fault detector of overvoltage and overexciatation protection of generator. [FD_FreqProt_Gen]: Internally generated binary input indicating operation of fault detector of frequency protection of generator. [FD_LossExc&OOS_Gen]: Internally generated binary input indicating operation of fault detector of loss-of-excitation and out-of-step protection of generator. [FD_Pwr&AccEnerg_Gen]: Internally generated binary input indicating operation of fault detector of power protection and accidental energization protection of generator. [FD_StShut_Gen]: Internally generated binary input indicating operation of fault detector of startup and shutdown protection of generator. [FD_Prot_Exc]: Internally generated binary input indicating operation of fault detector of protections of excitation transformer or exciter. [FD_MechRly]: Internally generated binary input indicating operation of fault detector of mechanical protection of excitation transformer. Access path in menu is ―VALUES CPU BI STATE  MONF FD‖ and ―VALUES MON BI STATE  MON FD‖.



NR ELECTRIC CO., LTD



99



Chapter4 Self-supervision, metering and records



4.3.6 Other Binary Inputs



PS SUPERV BI BI_Pwr_MechRly:



1



BI_Pwr_Opto:



1



BI_RstTarg:



0



BI_Pulse_GPS:



0



BI_Print:



0



Figure 4.3-6 Others binary input Where: [BI_Pwr_MechRly]: binary input indicating the power supply of mechanical repeater is in proper working condition. [BI_Pwr_Opto]: binary input indicating the power supply of optical isolators is in proper working condition. [BI_Print]: binary input represents the print button. [BI_Pulse_GPS]: binary input of GPS clock synchronous pulse. [BI_RstTarg]: binary input of signal reset button. Access path in menu is ―VALUES CPU BI STATE  PS SUPERV BI‖ and ―VALUES MON BI STATE  PS SUPERV BI‖ .



4.4



Event & fault records



4.4.1 Introduction The RCS-985G is equipped with integral measurements, event, fault and disturbance recording facilities suitable for analysis of complex system disturbances. The relay is flexible enough to allow for the programming of these facilities to specific user application requirements that is discussed below.



4.4.2 Event & Fault records The relay records and time tags up to 32 events and stores them in non-volatile (battery backed up) memory. This enables the system operator to establish the sequence of events that occurred within the relay following a particular power system condition, switching sequence etc. When the



100



NR ELECTRIC CO., LTD



Chapter4 Self-supervision, metering and records



available space is exhausted, the oldest event is automatically overwritten by the new one. The real time clock within the relay provides the time tag to each event, to a resolution of 1ms. The event records are available for viewing either via the frontplate LCD or remotely, via the communications ports (courier and MODBUS versions only). Local viewing on the LCD is achieved in the menu column entitled ―REPORT‖. This column allows viewing of event and fault records and is shown by setting sequence No. of the event or fault report by user. Refer to section 8 for details of operation method.



4.4.3 Type of event An event may be a change of state of a control input or output relay, an alarm condition and operation reports of protection etc.



4.4.4 Change of state of opto-isolated inputs If one or more of the opto inputs has changed state since the last time that the protection algorithm ran, the new status is logged as an event. When this event is selected to be viewed on the LCD, the applicable cells will become visible as shown below:



Record No. BI CHANG REPORT Data：xxxx - xx – xx Time：xx : xx : xx : xxx Binary input name



Changing manner



Figure 4.4-1 Format of Event Report Where ―Record NO.‖ means the sequence No. of the record which is generated by RCS-985G automatically. ―Date: DD-MM-YY‖ and ―Time: HH:MM:SS:xxxxms‖ commonly comprise the absolute time tag of the record. ―Binary input Name‖ shows the name of the binary input whose state changes. ―Changing manner‖ shows how to change of the state of the binary input. For instance:



NR ELECTRIC CO., LTD



101



Chapter4 Self-supervision, metering and records



No. 011



BI CHANG REPORT 2007 - 01 - 01 15 : 19 : 00 : 003



EBI_Diff_Gen



0 -> 1



Figure 4.4-2 Example of Binary Input Changing Report All the binary input that may be shown in the menu can be found in section 4.3, here list them again. Table 4.4-1 List of binary input of RCS-985G No. 1.



BI name



22.



EBI_Trp_MechRly1



EBI_Diff_Gen



23.



2.



EBI_IntTurn_Gen



24.



EBI_PPF_Gen EBI_SPTDiff_Gen



3.



EBI_ROV_Sta



25.



BI_SyncCondenser



4.



EBI_V3rdH_Sta



26.



5.



EBI_1PEF_RotWdg



27.



BI_UrgBrake BI_ExtProtTrp



6.



EBI_2PEF_RotWdg



28.



BI_Pwr_Superv



7.



EBI_OvLd_Sta



29.



EBI_OvLd_RotWdg



8.



EBI_NegOC_Gen



30.



EBI_Trp_MechRly1



9.



EBI_LossExc_Gen



31.



BI_MechRly1



10.



EBI_OOS_Gen



32.



BI_MechRly2



11.



EBI_VoltProt_Gen



33.



BI_MechRly3



12.



EBI_OvExc_Gen



34.



BI_MechRly4



13.



EBI_PwrProt_Gen



35.



EBI_SeqTrpRevP_Gen



14.



EBI_FreqProt_Gen



36.



EBI_BFP_GCB



15.



EBI_AccEnerg_Gen



37.



BI_Print



16.



EBI_StShut_Gen



38.



BI_Pulse_GPS



17.



EBI_Diff_Exc



39.



BI_RstTarg



18.



EBI_Bak_Exc



40.



BI_Pwr_Opto



19.



EBI_Trp_MechRly3



41.



BI_Pwr_MechRly



20.



EBI_Trp_MechRly4



42.



BI_52b_GCB



21.



EBI_Trp_MechRly2



43.



BI_Valve_Turbine



102



NR ELECTRIC CO., LTD



Chapter4 Self-supervision, metering and records



44.



FD_Diff_Gen



51.



FD_LossExc&OOS_Gen



45.



FD_EF_Sta



52.



FD_Pwr&AccEnerg_Gen



46.



FD_EF_RotWdg



53.



FD_StShut_Gen



47.



FD_OvLd_Sta



54.



FD_Prot_Exc



48.



FD_PPF_Gen



55.



FD_MechRly



49.



FD_Volt&OvExc_Gen



50.



FD_FreqProt_Gen



4.4.5 Relay alarm signals Any alarm signal generated by the relays will also be logged as individual events. The access method and display format is similar to that of binary input changing record as shown below.



Record No. ALARM REPORT Data：xxxx - xx – xx Time：xx : xx : xx : xxx ALARM ELEMENT



Figure 4.4-3 Format of alarm report on LCD The above figure shows the abbreviated description that is given to the various alarm conditions and also a corresponding value between 0 and 31. This value is appended to each alarm event in a similar way as for the input events previously described. It is used by the event extraction software, such as RCSPC, to identify the alarm and is therefore invisible if the event is viewed on the LCD. The following table shows all of the alarm elements that may be displayed in this item. Table 4.4-2 List of alarm elements No. 1. 2. 3. 4. 5. 6.



Alarm name



7.



Alm_VTS2_Term_Gen



Alm_SwOv_VTS1_Gen



8.



Alm_VTS_NP_Gen



Alm_SwOv_VTS2_Gen



9.



Alm_DeltVTS1_Term_Gen



Alm_BlkV3rdHDiff_VTS1



10.



Alm_DeltVTS2_Term_Gen



Alm_BlkIntTurn_VTS2



11.



Alm_VTS_LossExc_RotWdg



Alm_VTS_HVS_Tr



12.



Alm_Pos_GCB



Alm_VTS1_Term_Gen



13.



Alm_PM_DSP1_CPUBrd



NR ELECTRIC CO., LTD



103



Chapter4 Self-supervision, metering and records



14.



Alm_CTS_BakCT_Gen



48.



Alm_CTS_S2_Exc



15.



Alm_CTS_Term_Gen



49.



Alm_Diff_ET



16.



Alm_CTS_NP_Gen



50.



Alm_Diff_Exciter



17.



Alm_CTS_SP1_Gen



51.



Alm_CTS_Diff_ET



18.



Alm_CTS_SP2_Gen



52.



Alm_CTS_Diff_Exciter



19.



Alm_Diff_Gen



53.



Alm_MechRly2



20.



Alm_SPTDiff_Gen



54.



Alm_MechRly4



21.



Alm_DPFC_IntTurn_Gen



55.



Alm_MechRly3



22.



Alm_CTS_Diff_Gen



56.



Alm_MechRly1



23.



Alm_CTS_SPTDiff_Gen



57.



Alm_Inconsist_MechRly



24.



Alm_BO_OC_Term_Gen



58.



Alm_PwrLoss_MechRly



25.



Alm_On_2PEF_RotWdg



59.



Alm_PM_DSP2_CPUBrd



26.



Alm_Ext_OOS_Gen



60.



Alm_RAM_CPUBrd



27.



Alm_Int_OOS_Gen



61.



Alm_ROM_CPUBrd



28.



Alm_Accel_OOS_Gen



62.



Alm_EEPROM_CPUBrd



29.



Alm_Decel_OOS_Gen



63.



Alm_InvalidSetting



30.



Alm_LossExc_Gen



64.



Alm_ModifiedSetting



31.



Alm_OvExc_Gen



65.



Alm_PwrLoss_Opto



32.



Alm_OvLd_Sta



66.



Alm_TripOutput



33.



Alm_NegOC_Gen



67.



Alm_InnerComm



34.



Alm_OvLd_RotWdg



68.



Alm_DSP_CPUBrd



35.



Alm_ROV_Sta



69.



Alm_PersistFD_CPUBrd



36.



Alm_V3rdHRatio_Sta



70.



Alm_InconsistFD



37.



Alm_V3rdHDiff_Sta



71.



Alm_Sample_CPUBrd



Alm_Sens1PEF_RotWdg



72.



Alm_BI_CPUBrd



Alm_1PEF_RotWdg



73.



Alm_RAM_MONBrd



Alm_UF1_Gen



74.



Alm_ROM_MONBrd



Alm_UF2_Gen



75.



Alm_EEPROM_MONBrd



Alm_UF3_Gen



76.



Alm_DSP_MONBrd



Alm_OF1_Gen



77.



Alm_PersistFD_MONBrd Alm_MONBrd Alm_Sample_MONBrd



38. 39. 41. 42. 43. 44. 45.



Alm_OF2_Gen



78.



46.



Alm_RevP_Gen



79.



47.



Alm_CTS_S1_Exc



4.4.6 Protection element Any operation of protection elements, (either a pickup or a trip condition) will be logged as an event record, consisting of a text string indicating the operated element and an event sequence NO.. Again, this number is intended not only for use by the event extraction software, such as RCSPC, but also for the user, and is therefore visible when the event is viewed on the LCD. The figure below shows the format of operation record of protection element.



104



NR ELECTRIC CO., LTD



Chapter4 Self-supervision, metering and records



Record No. TRIP REPORT Data：xxxx - xx – xx Time：xx : xx : xx : xxx OPERATE ELEMENT



xxx ms



Figure 4.4-4 Format of trip report Where: ―Record NO.‖ means the sequence No. of the record which is generated by RCS-985G automatically. ―Date: xxxx-xx-xx‖ and ―Time: xx:xx:xx:xxxxms‖ commonly comprise the absolute time tag of the record. ―Operation Element‖ shows the name of the operating element. If there are more than one elements operating, they will scroll one by one to display on LCD. ―xxx ms‖ shows the relative time of operation element to fault detector of the relay. The following table lists all the operation elements that may be displayed on LCD. Table 4.4-3 List of operation elements Operation element name



13.



Op_InsensIntTurn_Gen



1.



Op_InstDiff_Gen



14.



Op_SensROV_Sta



2.



Op_PcntDiff_Gen



15.



Op_InsensROV_Sta



3.



Op_DPFC_Diff_Gen



16.



Op_V3rdHRatio_Sta



4.



Op_InstSPTDiff_Gen



17.



Op_V3rdHDiff_Sta



5.



Op_PcntSPTDiff_Gen



18.



Op_1PEF_RotWdg



6.



Op_Diff_StShut_Gen



19.



Op_2PEF_RotWdg



7.



Op_UFOC_StShut_Gen



20.



Op_OvLd_Sta



8.



Op_StaROV_StShut_Gen



21.



Op_InvOvLd_Sta



9.



Op_DPFC_IntTurn_Gen



22.



Op_NegOC1_Gen



10.



Op_SensTrvDiff_Gen



23.



Op_NegOC2_Gen



11.



Op_InsensTrvDiff_Gen



24.



Op_InvNegOC_Gen



12.



Op_SensIntTurn_Gen



25.



Op_OvLd_RotWdg



No.



NR ELECTRIC CO., LTD



105



Chapter4 Self-supervision, metering and records



26.



Op_InvOvLd_RotWdg



52.



Op_Flash11_GCB



27.



Op_OC1_Gen



53.



Op_Flash12_GCB



28.



Op_OC2_Gen



54.



Op_InstDiff_Exciter



29.



Op_OV1_Gen



55.



Op_PcntDiff_Exciter



30.



Op_OV2_Gen



56.



Op_InstDiff_ET



31.



Op_UV_Gen



57.



Op_PcntDiff_ET



32.



Op_OvExc1_Gen



58.



Op_OC1_Exc



33.



Op_OvExc2_Gen



59.



Op_OC2_Exc



34.



Op_InvOvExc_Gen



60.



Op_MechRly1



35.



Op_UF1_Gen



61.



Op_MechRly2



36.



Op_UF2_Gen



62.



Op_MechRly3



37.



Op_UF3_Gen



63.



Op_MechRly4



38.



Op_OF1_Gen



64.



39.



Op_OF2_Gen



65.



TrpOutp1 TrpOutp2



40.



Op_Z1_Gen



66.



TrpOutp3



41.



Op_Z2_Gen



67.



TrpOutp4



42.



Op_LossExc1_Gen



68.



TrpOutp5



43.



Op_LossExc2_Gen



69.



TrpOutp6



44.



Op_LossExc3_Gen



70.



TrpOutp7



45.



Op_Ext_OOS_Gen



71.



TrpOutp8



46.



Op_Int_OOS_Gen



72.



TrpOutp9



47.



Op_BFP11_Gen



73.



TrpOutp10



48.



Op_BFP12_Gen



74.



TrpOutp11



49.



Op_RevP_Gen



75.



TrpOutp12



50.



Op_SeqTrpRevP_Gen



51.



Op_AccEnerg_Gen



4.4.7 Viewing event records via RCSPC support software What the event records are extracted and viewed on a PC they look slightly different than what viewed on the LCD. The following figure shows an example of how various events appear when displayed using RCSPC:



106



NR ELECTRIC CO., LTD



Chapter4 Self-supervision, metering and records



Figure 4.4-5 Trip reports seen by RCSPC



4.5



Disturbance Record



The integral disturbance recorder has an area of memory specifically set aside for record storage. The number of records that may be stored by the relay is dependent upon the selected recording duration. The recorder of CPU board can typically store a minimum of 32 records, among them 8 records with instantaneous waveform. The record is composed of tripping element, faulty phase and operation time. The waveform content is composed of differential currents, corrected current of each side of generator or transformer, three-phase current of each side, zero sequence current of each side (if available), three-phase voltages, zero sequence voltage of each side, negative sequence voltage and tripping pulse. The MON board can store up to 4 seconds (24 sampling points per cycle) or 8 seconds (12 sampling points per cycle) continual waveform, which include all channels analog quantities (sampled data, diferential currents and so on), all binary input changing states, binary output, pick up flags of fault detectors, alarm signals, operation signals and tripping signals. Disturbance records continue to be recorded until the available memory is exhausted, at which time the oldest record(s) are overwritten to make space for the newest one. It is not possible to view the disturbance records locally via the LCD; they must be extracted using suitable software such as RCSPC. This process is fully explained in the section 11.6. The CPU board can also record the latest 8 cycles of waveform in normal operatin condition, which is composed of three phase current, corrected current of each side for differential protection, three phases voltage and zero sequence voltage of each side. This function can help the user to check the pole‘s correctness of secondary circuit by comparing the phase of related quantities shown in wave figure. This manual gives the detail instruction of getting normal operation waveform in section 8.2.6.



NR ELECTRIC CO., LTD



107



Chapter4 Self-supervision, metering and records



4.6



Time Synchronization



In modern protective schemes it is often desirable to synchronize the relays real time clock so that events from different relays can be placed in chronological order. This can be done using the IRIG-B input, if fitted, or via the communication interface connected to the substation control system. In addition to these methods the RCS-985G range offers the facility to synchronize via an opto-input. Pulsing this input will result in the real time clock snapping to the nearest minute. The recommended pulse duration is 20ms to be repeated no more than once per minute. An example of the time sync. function is shown. Time of ―Sync. Pulse‖



Corrected Time



19:47:00 to 19:47:29



19:47:00



19:47:30 to 19:47:59



19:48:00



Note: The above assumes a time format of hh:mm:ss



108



NR ELECTRIC CO., LTD



Chapter5 Hardware Description



Chapter5 Hardware Description 5.1



Hardware overview



The protection‘s hardware is based on a modular design whereby the relay is made up of an assemblage of several modules that are drawn from a standard range. Some modules are essential while others are optional depending on the user‘s requirements. The case materials of the relay are constructed from pre-finished steel that has a conductive covering of aluminum and zinc. This provides good earthing at all joints giving a low impedance path to earth that is essential for performance in the presence of external noise. The boards and modules use a multi-point earthing strategy to improve the immunity to external noise and minimize the effect of circuit noise. Ground planes are used on boards to reduce impedance paths and spring clips are used to ground the module metalwork. Heavy duty terminal blocks are used at the rear of the relay for the current and voltage signal connections. Medium duty terminal blocks are used for the digital logic input signals, the output relay contacts, the power supply and the rear communication port. A BNC connector may be used for the optional IRIG-B signal. 9-pin and 25-pin female D-connectors are used at the front of the relay for data communication. Inside the protection the PCBs plug into the connector blocks at the rear, and can be removed from the rear of the relay only. The connector blocks to the relay‘s CT inputs are provided with internal shorting links inside the relay which will automatically short the current generator circuits before they are broken when the board is removed. The front panel consists of a membrane keypad with tactile dome keys, an LCD and 5 LEDs mounted on an aluminum face plate.



5.1.1 Front view RCS-985G is made of a single layer 8U height 19‖ chassis with 15 connectors on its rear. Figure 5.1-1 shows front view.



NR ELECTRIC CO., LTD



109



Chapter5 Hardware Description



RCS-985 GENERATOR PROTECTION



CT ALARM ALARM TRIP



ENT



ESC



VT ALARM



GRP



HEALTHY



NARI RELAYS ELECTRIC CO., LD



Figure 5.1-1 Front view of RCS-985G Components mounted on its front include a 240×128 dot matrix LCD, a 9 button keypad, 5 LED indicators, a signal reset button, a DB9 connector for communication with HELP-90A or PC and a DB15 connector for analog quantity inputs during commissioning. The five LED indicators are, from top to bottom: HEALTHY:



Equipment running normally;



VT ALARM :



Voltage circuit failure ;



CT ALARM:



Current circuit failure;



ALARM:



Abnormal;



TRIP:



Tripping output;



As to the buttons of the keypad, ―ENT‖ is ―enter‖, ―GRP‖ is ―setting group selector‖ and ―ESC‖ is ―escape‖.



110



NR ELECTRIC CO., LTD



Chapter5 Hardware Description



5.1.2 Rear view



1 1 A2 4 6 8 10 12 14 16 18 20 22 24 26 28 A30



1 3 5 7 9 11 13 15 17 19 21 23 25 27 29



1 1 B2 4 6 8 10 12 14 16 18 20 22 24 26 B 28 30



1 3 5 7 9 11 13 15 17 19 21 23 25 27 29



2 2 A2 4 6 8 10 12 14 16 18 20 22 24 26 28 A30



1 3 5 7 9 11 13 15 17 19 21 23 25 27 29



2 2 B2 4 6 8 10 12 14 16 18 20 22 24 26 B 28 30



3 3 A2 4 6 8 10 12 14 16 18 20 22 24 26 28A30



1 3 5 7 9 11 13 15 17 19 21 23 25 27 29



3 3 B2 4 6 8 10 12 14 16 18 20 22 24 26 B 28 30



1 3 5 7 9 11 13 15 17 19 21 23 25 27 29



4 4 B2 4 6 8 10 12 14 16 18 20 22 24 26 B 28 30 51 3 5 7 9 11 13 15 17 19 21 23 25 27529 B2 4 6 8 10 12 14 16 18 20 22 24 26 B 28 30



1 3 5 7 9 11 13 15 17 19 21 23 25 27 29



1 3 5 7 9 11 13 15 17 19 21 23 25 27 29



1 3 5 7 9 11 13 15 17 19 21 23 25 27 29



4 4 A2 4 6 8 10 12 14 16 18 20 22 24 26 28A30



1 3 5 7 9 11 13 15 17 19 21 23 25 27 29



6 6 B2 4 6 8 10 12 14 16 18 20 22 24 26B 28 30 1 3 5 7 9 11 13 15 17 19 21 23 25 27 29



7 7 B2 4 6 8 10 12 14 16 18 20 22 24 26B 28 30



1



3



5



7



9



11 13



15 17



8 C



1 3 5 7 9 11 13 15 17 19 21 23 25 27 29



8 8 B2 4 6 8 10 12 14 16 18 20 22 24 26B 28 30 1



3



5



7



9



11 13



15 17



2



4



6



8



10



1



3



5



7



9



12 14 16 18 11 13



15 17



9 B



9 C 2



4



6



8



10



12 14 16 18



2



4



6



8



10



12 14 16 18



Figure 5.1-2 Rear view of RCS-985G



5.1.3 Functional block diagram of RCS-985G 5.1.3.1 Functional block diagram of RCS-985G



AC current and voltage



A/D



optocoupler



DSP1 DSP2



binary status input



CPLD



LPF



MMI



LCD



output relay



CPU1



CPU module MMI-CPU



QDJ



comm ports and port to printer



E+



MMI



A/D



binary status input



CPLD



＋24 V



MMI ±24 V to optic-coupler



optocoupler



DSP3 DSP4



＋5 V ±12 V



DC/DC



DC 220 V or 110 V



LPF



CPU2



management module comm ports and port to printer



Figure 5.1-3 Functional block diagram of RCS-985G



NR ELECTRIC CO., LTD



111



Chapter5 Hardware Description



5.1.3.2 Brief description of operation The equipment RCS-985G uses Motorola 32 bits monolithic microprocessor MC68332 as control kernel for output logic and management functions, and high-speed digital signal processor DSP for protection calculation. Sampling rate of the equipment is 24 points per cycle. Real time data are processed in parallel for all algorithms during whole fault process. So the equipment can ensure very high inherent reliability and security. AC currents and voltages of CT and VT are transferred to low voltage signals by isolating transformers and are inputted to the CPU module and MON module. Data and logic are processed respectively in these two modules with same type of hardware. The CPU module carries out functions of protection algorithms, tripping logic, event record and printing. The MON module comprises of general fault detector and the fault recorder. The fault detector will connect to the positive pole of power supply of output relays after pickup. Format of the record is compatible with COMTRADE, and the data recorded can be uploaded via separate serial port for communication or printing. Power supply part is located in DC module. It converts DC 250/220/125/110 V into different DC voltage levels needed by various modules of the equipment. DC module also comprises 24V and 250/220/125/110V opto-couplers for binary inputs. AC current and voltage are converted to low voltage signals in modules AC1 and AC2. Two ratings of AC current are option, 1A or 5A. It shall be stated definitely during ordering and checked during commissioning. Binary outputs of tripping commands, tripping signal outputs and status binary input parts are comprised in three modules: RLY, SIG1 and SIG2. 24V and 250/220/125/110V opto-couplers are used here for binary input. Briefly, the equipment is composed of ten modules to achieve the work of generator protection. The modules are AC voltage and current input module1(AC1), AC current input modules(AC2), management/record module(MON), protection CPU module(CPU), power supply module(DC), binary input module (OPT2), signal modules(SIG1 and SIG2), tripping contacts output(RLY), and human machine interface（HMI）. The relay hardware is based on a modular design whereby the relay is made up of an assemblage of several modules.



5.2



Standard connectors and terminals



5.2.1 General description There are 15 connectors for external connections mounted on rear panel of the equipment as shown in Figure 5.1-2, of which, 12 connectors are 30 pins while 3 connectors are 18 pins. Connectors with 30 pins are used for DC power supply, binary input, communication and printer, tripping, alarm and other signal output and AC voltage input. Numbers of these connectors are 1A, 1B, 2A, 2B, 3A, 3B, 4A, 4B, 5B, 6B, 7B and 8B. Figure 5.2-1 a) shows layout of 30 pins of these connectors. 112



NR ELECTRIC CO., LTD



Chapter5 Hardware Description



Connectors with 18 pins are used for current input. Numbers of these connectors are 8C, 9B and 9C. Figure 5.2-1 b) shows layout of pins of these connectors. 1



3



2



5



4



7



6



9



8



11



10



13



12



15



14



17



16



19



18



21



20



23



22



25



24



27



26



1



29



28



2



30



a) connector with 30 pins



3



5



7



9



4



6



8



10



11



12



13



14



15



17



16



18



b) connector with 18 pins



Figure 5.2-1 Layout of pins of two kinds of connectors Each connector will be introduced in detail in the following sections.



5.2.2 Pins definition of ‗1A‘ connectors Connector 1A: 30 pins male connector for tripping output Attention: For showing the relation of each terminal clearly, the terminal‘s location shown in the Figure may be different from the real physical location, and we needn‘t figure out the blank terminals.



1



3



2



5



4



7



6



9



8



11



10



12



13



15



14



16



17



18



19



20



21



22



23



24



25



26



27



28



29



30



Figure 5.2-2 Connector 1A of RCS-985G 1A1,1A30



blank



Binary output of tripping: 1A3-1A5



BO_TripOutp1-1 (TJ1-1)



Tripping output channel 1-1



1A7-1A9



BO_TripOutp1-2 (TJ1-2)



Tripping output channel 1-2



1A11-1A13



BO_TripOutp1-3 (TJ1-3)



Tripping output channel 1-3



1A15-1A17



BO_TripOutp1-4 (TJ1-4)



Tripping output channel 1-4



1A19-1A21



BO_TripOutp2-1 (TJ2-1)



Tripping output channel 2-1



1A23-1A25



BO_TripOutp2-2 (TJ2-2)



Tripping output channel 2-2



1A27-1A29



BO_TripOutp2-3 (TJ2-3)



Tripping output channel 2-3



1A2-1A4



BO_TripOutp3-1 (TJ3-1)



Tripping output channel 3-1



1A6-1A8



BO_TripOutp3-2 (TJ3-2)



Tripping output channel 3-2



1A10-1A12



BO_TripOutp3-3 (TJ3-3)



Tripping output channel 3-3



1A14-1A16



BO_TripOutp3-4 (TJ3-4)



Tripping output channel 3-4



1A18-1A20



BO_TripOutp4-1 (TJ4-1)



Tripping output channel 4-1



1A22-1A24



BO_TripOutp4-2 (TJ4-2)



Tripping output channel 4-2



NR ELECTRIC CO., LTD



113



Chapter5 Hardware Description



1A26-1A28



BO_TripOutp5-1 (TJ5-1)



Tripping output channel 5-1



5.2.3 Pins definition of ‗1B‘ connectors Connector 1B: 30 pins male connector for tripping output



1



3



2



5



4



7



6



9



8



11



10



13



12



15



14



17



16



19



18



21



20



23



22



25



24



27



26



29



28



30



Figure 5.2-3 Connector 1B of RCS-985G Binary output of tripping: 1B1-1B3



BO_TripOutp2-4 (TJ2-1)



Tripping output channel 2-4



1B5-1B7



BO_TripOutp6-1 (TJ6-1)



Tripping output channel 6-1



1B9-1B11



BO_TripOutp6-2 (TJ6-2)



Tripping output channel 6-2



1B13-1B15



BO_TripOutp6-3 (TJ6-3)



Tripping output channel 6-3



1B17-1B19



BO_TripOutp7-1 (TJ7-1)



Tripping output channel 7-1



1B21 -1B23



BO_TripOutp8-1 (TJ8-1)



Tripping output channel 8-1



1B25-1B27



BO_TripOutp9-1 (TJ9-1)



Tripping output channel 9-1



1B2-1B4



BO_TripOutp5-2 (TJ5-2)



Tripping output channel 5-2



1B6-1B8



BO_TripOutp5-3 (TJ5-3)



Tripping output channel 5-3



1B10-1B12



BO_TripOutp5-4 (TJ5-4)



Tripping output channel 5-4



1B14-1B16



BO_TripOutp11-1 (TJ11-1)



Tripping output channel 11-1



1B18-1B20



BO_TripOutp11-2 (TJ11-2)



Tripping output channel 11-2



1B22-1B24



BO_TripOutp12-1 (TJ12-1)



Tripping output channel 12-1



1B26-1B28



BO_TripOutp12-2 (TJ12-2)



Tripping output channel 12-2



1B29-1B30



BO_TripOutp10-1 (TJ10-1)



Tripping output channel 10-1



5.2.4 Pins definition of ‗2A‘ connectors Connector 2A:



1



30 pins male connector for signal output



7



2



13



8



19 25



14



20



3



26



9



4



15



10



21



16



27



22



5



28



11



6



17



23



12 18



29



24



30



Figure 5.2-4 Connector 2A of RCS-985G 114



NR ELECTRIC CO., LTD



Chapter5 Hardware Description



Binary output of local signal: 2A1



common 1



common terminal 1



2A1-2A7



BO_Diff_Gen



local signal: generator differential protection tripping



2A1-2A13



BO_EF_Sta



local signal: stator earth fault protection tripping



2A1-2A19



BO_OvLd_Sta



local signal: stator overload protection tripping



2A1-2A25



BO_LossExc



local signal: generator loss-of-excitation protection tripping



2A2



common 2



common terminal 2



2A2-2A8



BO_IntTurn_Gen



Local signal: generator interturn protection tripping



2A2-2A14



BO_EF_RotWdg



Local signal: rotor earth fault protection tripping



2A2-2A20



BO_NegOC_Gen



Local signal: negative sequence overcurrent protection tripping



2A2-2A26



BO_OSS_Gen



Local signal: generator out-of-step protection tripping



Binary output of remote signal: 2A3



common 1



Remote signal: common terminal 1



2A3-2A9



BO_Diff_Gen



Remote signal: generator differential protection tripping



2A3-2A15



BO_EF_Sta



Remote signal: stator earth fault protection tripping



2A3-2A21



BO_OvLd_Sta



Remote signal: stator overload protection tripping



2A3-2A27



BO_LossExc



Remote signal: generator loss-of-excitation protection tripping



2A4



common 2



Remote signal: common terminal 2



2A4-2A10



BO_IntTurn_Gen



Remote signal: generator interturn protection tripping



2A4-2A16



BO_EF_RotWdg



Local signal: rotor earth fault protection tripping



2A4-2A22



BO_NegOC_Gen



Remote signal: negative sequence overcurrent protection tripping



2A4-2A28



BO_OSS_Gen



Remote signal: generator out-of-step protection tripping



Binary output of event record: 2A5



common 1



Event signal: common terminal 1



2A5-2A11



BO_Diff_Gen



Event signal: generator differential protection tripping



2A5-2A17



BO_EF_Sta



Event signal: stator earth fault protection tripping



2A5-2A23



BO_OvLd_Sta



Event signal: stator overload protection tripping



2A5-2A29



BO_LossExc



Event signal: generator loss-of-excitation protection tripping



2A6



common 2



Event signal: common terminal 2



2A6-2A12



BO_IntTurn_Gen



Event signal: generator interturn protection tripping



2A6-2A18



BO_EF_RotWdg



Local signal: rotor earth fault protection tripping



2A6-2A24



BO_NegOC_Gen



Event signal: negative sequence overcurrent protection tripping



2A6-2A30



BO_OSS_Gen



Event signal: generator out-of-step protection tripping



5.2.5 Pins definition of ‗2B‘ connectors Connector 2B:



30 pins male connector for signal output



NR ELECTRIC CO., LTD



115



Chapter5 Hardware Description 2A1



2A2



1



7



2



13



8



19 25



14



20



2A3



26



3



2A4



9



4



15



10



21



16



27



22



2A5 5



28



2A6



11



6



17



23



12 18



29



24



30



Figure 5.2-5 Connector 2B of RCS-985G Binary output of local signal: 2A1-2B1



BO_OV_Gen



local signal: generator overvoltage protection tripping



2A1-2B7



BO_PwrProt_Gen



local signal: generator reverse power protection tripping



2A1-2B13



BO_FreqProt_Gen



local signal: generator frequency protection tripping



2A1-2B19



BO_AccEnerg_Gen



local signal: generator accidental energization protection tripping



2A1-2B25



BO_Diff_Exc



local signal: differential protection of excitation transformer of exciter tripping



2A2-2B2



BO_OvExc_Gen



Local signal: generator overexcitation protection



2A2-2B8



BO_RepP_Gen



Local signal: generator sequence trip reverse power protection tripping



2A2-2B14



BO_PPF_Gen



Local signal: generator phase-to-phase backup protection tripping



2A2-2B20



BO_MechRly



Local signal: transformer mechanical protection tripping



2A2-2B26



BO_Bak_Exc



Local signal: excitation backup protection tripping



Binary output of remote signal: 2A3-2B3



BO_OV_Gen



Remote signal: generator overvoltage protection tripping



2A3-2B9



BO_PwrProt_Gen



Remote signal: generator reverse power protection tripping



2A3-2B15



BO_FreqProt_Gen



Remote signal: generator frequency protection tripping



2A3-2B21



BO_AccEnerg_Gen



Remote signal: generator accidental energization protection tripping



2A3-2B27



BO_Diff_Exc



Remote signal: differential protection of excitation transformer of exciter tripping



2A4-2B4



BO_OvExc_Gen



Remote signal: generator overexcitation protection



2A4-2B10



BO_RepP_Gen



Remote signal: generator sequence trip reverse power protection tripping



2A4-2B16



BO_PPF_Gen



Remote signal: generator phase-to-phase backup protection tripping



116



NR ELECTRIC CO., LTD



Chapter5 Hardware Description



2A4-2B22



BO_MechRly



Remote signal: transformer mechanical protection tripping



2A4-2B28



BO_Bak_Exc



Remote signal: excitation backup protection tripping



Binary output of event record: 2A5-2B5



BO_OV_Gen



Event record: generator overvoltage protection tripping



2A5-2B11



BO_PwrProt_Gen



Event record: generator reverse power protection tripping



2A5-2B17



BO_FreqProt_Gen



Event record: generator frequency protection tripping



2A5-2B23



BO_AccEnerg_Gen



Event record: generator accidental energization protection tripping



2A5-2B29



BO_Diff_Exc



Event record: differential protection of excitation transformer of exciter tripping



2A6-2B6



BO_OvExc_Gen



Event record: generator overexcitation protection



2A6-2B12



BO_RepP_Gen



Event record: generator sequence trip reverse power protection tripping



2A6-2B18



BO_PPF_Gen



Event record: generator phase-to-phase backup protection tripping



2A6-2B24



BO_MechRly



Event record: transformer mechanical protection tripping



2A6-2B30



BO_Bak_Exc



Event record: excitation backup protection tripping



Note: Signals contacts for stator earth fault protection will be driven when stator zero sequence overvoltage elements operates in generator startup and shutdown. Signals contacts for generator differential protection will be driven when differential current element operates in generator startup and shutdown.



5.2.6 Pins definition of ‗3A‘ connectors Connector 3A:



1



30 pins male connector for signal and alarm output.



3



2



5



4



7



6



9



8



11



10



13



12



15



14



17



16



19



18



21



20



23 25



22



24



27



26



29



28



30



Figure 5.2-6 Connector 3A of RCS-985G



NR ELECTRIC CO., LTD



117



Chapter5 Hardware Description



Binary output of local signal: 3A1



Common terminal



3A1-3A3



COMMON BO_FAIL



3A1-3A5



BO_Alm_Abnor



Equipment alarm



3A1-3A7



BO_Alm_CTS



CT circuit failure alarm



3A1-3A9



BO_Alm_VTS



VT circuit failure alarm



3A1-3A11



BO_Alm_OvLd



Overload alarm



3A1-3A13



BO_Alm_NegOC



Negative sequence overcurrent alarm



3A1-3A15



BO_Alm_OvLd_RotWdg



Excitation overload alarm



3A1-3A17



BO_Alm_EF_Sta



Stator earth fault alarm



3A1-3A19



BO_Alm_1PEF_Gen



Rotor 1 point earth fault alarm



3A1-3A21



BO_Alm_LossExc_Gen



Loss-of-excitation alarm



3A1-3A23



BO_Alm_OOS_Gen



Out-of-step alarm



3A1-3A25



BO_Alm_FreqProt_Gen



Under frequency alarm



3A1-3A27



BO_Alm_PwrProt_Gen



Reverse power alarm



3A1-3A29



BO_Alm_OvExc_Gen



Overexcitation alarm



Equipment being blocked



Binary output of remote signal: 3A2



COMMON



Common terminal



3A2-3A4



BO_FAIL



Equipment being blocked



3A2-3A6



BO_Alm_Abnor



Equipment alarm



3A2-3A8



BO_Alm_CTS



CT circuit failure alarm



3A2-3A10



BO_Alm_VTS



VT circuit failure alarm



3A2-3A12



BO_Alm_OvLd



Overload alarm



3A2-3A14



BO_Alm_NegOC



Negative sequence overcurrent alarm



3A2-3A16



BO_Alm_OvLd_RotWdg



Excitation overload alarm



3A2-3A18



BO_Alm_EF_Sta



Stator earth fault alarm



3A2-3A20



BO_Alm_1PEF_Gen



Rotor 1 point earth fault alarm



3A2-3A22



BO_Alm_LossExc_Gen



Loss-of-excitation alarm



3A2-3A24



BO_Alm_OOS_Gen



Out-of-step alarm



3A2-3A26



BO_Alm_FreqProt_Gen



Under frequency alarm



3A2-3A28



BO_Alm_PwrProt_Gen



Reverse power alarm



3A2-3A30



BO_Alm_OvExc_Gen



Overexcitation alarm



5.2.7 Pins definition of ‗3B‘ connectors Connector 3B:



118



30 pins male connector for alarm and other output



NR ELECTRIC CO., LTD



Chapter5 Hardware Description



1



3



2



5



4



7



6



9



8



11



10



13



12



15



14



17



16



19



18



21



20



23



22



25



24



27



26



29



28



30



Figure 5.2-7 Connector 3B of RCS-985G



3B2



blank



Binary output of abnormality contact: 3B1-3B3



BO_OC_InitBFP



Normal opened contact indicating operation of generator terminal overcurrent element for initial breaker failure protection



3B5-3B7



BO_OC_InitBFP



Normal closed contact indicating operation of generator terminal overcurrent element for initial breaker failure protection



3B9-3B11



Reserved



3B13-B15



Reserved



3B17-3B19



Reserved



3B21-3B23



Reserved



3B25-3B27



Blank



Binary output of event record signal: 3B2



blank



3B4



COMMON



Event record: common terminal



3B4-3B6



BO_Alm_CTS



CT circuit failure alarm



3B4-3B8



BO_Alm_VTS



VT circuit failure alarm



3B4-3B10



BO_Alm_OvLd



Overload alarm



3B4-3B12



BO_Alm_NegOC



Negative sequence overload alarm



3B4-3B14



BO_Alm_OvLd_RotWdg



Excitation overload alarm



3B4-3B16



BO_Alm_EF_Sta



Stator earth fault alarm



3B4-3B18



BO_Alm_1PEF_Gen



Generator coasting alarm



3B4-3B20



BO_Alm_LossExc_Gen



Loss-of-excitation alarm



3B4-3B22



BO_Alm_OOS_Gen



Out-of-step alarm



3B4-3B24



BO_Alm_FreqProt_Gen



Under frequency alarm



3B4-3B26



BO_FAIL



Equipment being blocked



NR ELECTRIC CO., LTD



119



Chapter5 Hardware Description



3B4-3B28



BO_Alm_Abnor



Equipment alarm



3B4-3B29



BO_Alm_PwrProt_Gen



Reverse power alarm



3B4-3B30



BO_Alm_OvExc_Gen



Overexcitation alarm



5.2.8 Pins definition of ‗4A‘ connectors Connector 4A: 30 pins male connector for status input (via 220V/250V or 110V/125V opto-coupler)



1



3



2



5



4



7



6



9



8



11



10



13



12



15



14



16



17



19



18



21



20



22



23



＋



－



27



29



25



24



26



28



30



Figure 5.2-8 Connector 4A of RCS-985G Binary output of remote signal of mechanical repeaters: 4A1



COMMON



common terminal



4A1-4A3



BO_MR3



External mechanical repeater3



4A1-4A5



BO_MR4



External mechanical repeater4



4A1-4A7



BO_MR2



External mechanical repeater2



4A1-4A9



BO_MR1



External mechanical repeater1



Binary output of event record of mechanical repeaters: 4A2



COMMON



common terminal



4A2-4A4



BO_MR3



External mechanical repeater3



4A2-4A6



BO_MR4



External mechanical repeater4



4A2-4A8



BO_MR2



External mechanical repeater2



4A2-4A10



BO_MR1



External mechanical repeater1



Binary output of local signal of mechanical repeaters: 4A11



COMMON



common terminal



4A11-4A12



BO_MR4



External mechanical repeater4



4A11-4A13



BO_MR2



External mechanical repeater2



4A11-4A14



BO_Pwr_MR



Monitoring of power supply voltage



4A11-4A15



BO_MR3



External mechanical repeater3



4A11-4A16



BO_MR1



External mechanical repeater1



Binary input (via 220V or 110V opto-coupler) : 4A17



BO_MR3



Binary input of external mechanical repeater3



4A18



BO_MR4



Binary input of external mechanical repeater4



4A19



BO_MR2



Binary input of external mechanical repeater2



120



NR ELECTRIC CO., LTD



Chapter5 Hardware Description



4A20



BO_MR1



Binary input of external mechanical repeater1



Binary input of auxiliary contact(via 220V or 110V opto-coupler) 4A21



BI_Pwr_Superv



Monitoring auxiliary contact of power supply of mechanical protection



4A22



BI_52b_GCB



auxiliary contact of open position of circuit breaker at generator‘s terminal.



4A23



BI_Reserved4



Reserved binary input 4



4A24



BI_ExtProtTrp



Binary input indicating the operation of other protection



4A25



BI_Reserved1



Reserved binary input 1



4A26



BI_Valve_Turbine



Auxiliary contact of valve of steam turbine



4A27



+



Positive pole of mechanical repeaters‘ power supply.



4A28



Blank



4A29



Negative pole of mechanical repeaters‘ power supply.



-



4A30



Blank



5.2.9 Pins definition of ‗4B‘ connectors Connector 4B: 30 pins male connector for binary input



1



3



5



7



9



11



13



15



17



19



21



23



25



27



29



+24 V



2



4



6



8



10



12



14



16



18



20



22



24



26



28



30



0V



Figure 5.2-9 Connector 4B of RCS-985G 4B30



negative pole of DC 24V for 24 V opto-coupler



4B29



positive pole of DC 24V for 24 V opto-couple



Binary input (via 24 V opto-coupler): 4B1



Blank



4B2



Blank



4B3



EBI_Diff_Gen



Enabling binary input of generator differential protection



4B4



EBI_IntTurn_Gen



Enabling binary input of generator interturn protection



4B5



EBI_ROV_Sta



Enabling binary input of fundamental zero sequence overvoltage stator earth fault protection



4B6



EBI_V3rdH_Sta



Enabling binary input of 3rd harmonics voltage stator earth fault protection



4B7



EBI_1PEF_RotWdg



Enabling binary input of rotor 1 point earth fault protection



NR ELECTRIC CO., LTD



121



Chapter5 Hardware Description



4B8



EBI_2PEF_RotWdg



Enabling binary input of rotor 2 points earth fault protection



4B9



EBI_OvLd_Sta



Enabling binary input of stator overload protection



4B10



EBI_NegOC_Gen



Enabling binary input of generator negative sequence overcurrent protection



4B11



EBI_LossExc_Gen



Enabling binary input of generator loss-of-excitation protection



4B12



EBI_OOS_Gen



Enabling binary input of generator out-of-step protection



4B13



EBI_VoltProt_Gen



Enabling binary input of generator overvoltage and undervoltage protection



4B14



EBI_OvExc_Gen



Enabling binary input of generator overexcitation protection



4B15



EBI_PwrProt_Gen



Enabling binary input of generator reverse power protection



4B16



EBI_FreqProt_Gen



Enabling binary input of generator frequency protection



4B17



EBI_AccEnerg_Gen



Enabling binary input of generator accidental energization protection



4B18



EBI_StShut_Gen



Enabling binary input of generator startup and shutdown protection



4B19



EBI_Diff_Exc



Enabling binary input of excitation transformer differential protection



4B20



EBI_Bak_Exc



Enabling binary input of excitation backup protection



4B21



EBI_Trp_MechRly3



Enabling binary input of external mechanical repeater 3 for tripping



4B22



EBI_Trp_MechRly4



Enabling binary input of external mechanical repeater 4 for tripping



4B23



EBI_Trp_MechRly2



Enabling binary input of external mechanical repeater 2 for tripping



4B24



EBI_Trp_MechRly1



Enabling binary input of external mechanical repeater 1 for tripping



4B25



EBI_PPF_Gen



Enabling binary input of generator overcurrent protection



4B26



EBI_SPTDiff_Gen



Enabling binary input of generator splitting transverse differential protection



4B27



Blank



4B28



Blank



5.2.10 Pins definition of ‗5B‘ connectors Connector 5B: 30 pins male connector for status input



122



NR ELECTRIC CO., LTD



Chapter5 Hardware Description



1



3



5



7



9



11



13



15



17



19



21



23



25



27



29



+＋24V DC/DC 0V



2



4



6



8



10



12



14



16



18



20



22



24



26



28



30



Figure 5.2-10 Connector 5B of RCS-985G 5B27



negative pole of DC 220V/250V or 110V/125V opto-coupler



5B25



positive pole of DC 220V/250V or 110V/125V opto-couple



5B16



negative pole of DC 24V for 24 V opto-coupler



5B17



positive pole of DC 24V for 24 V opto-couple



Binary input (via 24 V opto-coupler): 5B1



EBI_OvLd_Exc



Enabling binary input of excitation overload protection



5B2



EBI_BFP_GCB



Enabling binary input of generator breaker failure protection



5B3



EBI_SeqTrpRevP_Gen



Enabling binary input of sequence tripping reverse power protection



5B4



Reserved binary input



5B5



Reserved binary input



5B6



Reserved binary input



5B7



Reserved binary input



5B8



Reserved binary input



5B9



Reserved binary input



5B10



Reserved binary input



5B11



Reserved binary input



5B12



Reserved binary input



5B13



BI_Print



Binary input of print button



5B14



BI_Pulse_GPS



Binary input of clock synchronization pulse



5B15



BI_RstTarg



Binary input of signal reset button



5B18



Blank



5B19



BI_UrgBrake



Binary input indicating the operation of urgent brake of generator



5B20



BI_SyncCondenser



Binary input indicating the synchronize condenser generator is put into operation



5B21



BI_Reserved3



Reserved binary input 3



5B22



BI_Reserved2



Reserved binary input 2



5B23



BI_Pwr_Opto



Binary input used for monitoring the power supply of all the BIs



NR ELECTRIC CO., LTD



123



Chapter5 Hardware Description



5B24



Blank



5B26



Blank



5B28



Blank



5B29



Earth



5B30



Earth



5.2.11 Pins definition of ‗6B‘, ‗7B‘ connectors Connector 6B, 7B: 30 pins male connector for communication and printing. Note: The definitions of connector 6B and connector 7B are same.



1



3



5



7



9



11



A



B



A



B



A



B



13



15



17



19



21



23



TX



RX



4



6



8



10



12



27



29



Earth



Printer PORT



485PORT 485PORT 485PORT



2



25



14



16



18



20



22



24



26



28



30 G



Figure 5.2-11 Connectors 6B, 7B of RCS-985G 6B1/7B1



clock synchronizing pulse input, RS-485 A



6B3/7B3



clock synchronizing pulse input, RS-485 B



6B5/7B5



conmmunication RS-485 port1 A



6B7/7B7



conmmunication RS-485 port1 B



6B9/7B9



conmmunication RS-485 port2 A



6B11/7B11



conmmunication RS-485 port2 B



6B21/7B21



printer RS232 port, Tx



6B23/7B23



printer RS232 port, Rx



6B27/7B27



ground of communication port



6B30/7B30



ground of chassis



5.2.12 Pins definition of ‗8B‘ connectors Connector 8B:



124



30 pins for voltage input



NR ELECTRIC CO., LTD



Chapter5 Hardware Description 1



2



7



8



9



UA’



UA



UA



UB UB’



3



4



UC



5



UC’



6



10



13



14



UC



UC’



UA’ UB



11



17



21



U bus U’ bus



22



25



26



29



30



U0TV2 U0TV2'



UNP UNP’



UB’



12



18



15



16



19



20



23



24



27



28



Figure 5.2-12 Connector 8B of RCS-985G



8B1



UA



phase A voltage of TV 1 at generator‘s terminal (polarity mark)



8B2



UA ‘



phase A voltage of TV 1 at generator‘s terminal



8B3



UB



phase B voltage of TV 1 at generator‘s terminal (polarity mark)



8B4



UB‘



phase B voltage of TV 1 at generator‘s terminal



8B5



UC,



phase C voltage of TV 1 at generator‘s terminal (polarity mark)



8B6



UC‘



phase C voltage of TV 1 at generator‘s terminal



8B7



Reserved voltage channel (polarity mark)



8B8



Reserved voltage channel



8B9



UA



phase A voltage of TV 2 at generator‘s terminal (polarity mark)



8B10



UA ‘



phase A voltage of TV 2 at generator‘s terminal



8B11



UB



phase B voltage of TV 2 at generator‘s terminal (polarity mark)



8B12



UB‘



phase B voltage of TV 2 at generator‘s terminal



8B13



UC,



phase C voltage of TV 2 at generator‘s terminal (polarity mark)



8B14



UC‘



phase C voltage of TV 2 at generator‘s terminal



8B15



Reserved voltage channel (polarity mark)



8B16



Reserved voltage channel



8B17



UB



Single phase of busbar (polarity mark)



8B18



U B‘



Single phase of busbar



8B19



U0



Zero-sequence voltage of generator‘s neutral point (polarity mark)



8B20



U0‘



Zero-sequence voltage of generator‘s neutral point



8B21



U0



Zero-sequence voltage of TV2 at generator‘s terminal (polarity mark)



8B22



U0‘



Zero-sequence voltage of TV2 at generator‘s terminal



8B23



Reserved voltage channel (polarity mark)



8B24



Reserved voltage channel



8B25



Reserved voltage channel (polarity mark)



8B26



Reserved voltage channel



NR ELECTRIC CO., LTD



125



Chapter5 Hardware Description



8B27



Reserved voltage channel (polarity mark)



8B28



Reserved voltage channel



8B29



Reserved voltage channel (polarity mark)



8B30



Reserved voltage channel



5.2.13 Pins definition of ‗8C‘ connectors Connector 8C:



18 pins for voltage and current input 1



3



5



7



9



11



13



15



17



20K UR+2



2



UR-2 IR+



4



6



IR-



8



10



UR+



12



UR-



14



16



18



Figure 5.2-13 Connector 8C of RCS-985G Terminal



Name



Function



8C3



UR+2



DC voltage input of rotor



8C5



UR-2



8C7



IR+



8C9



IR-



8C11



Test terminal



8C13



UR+



8C15



Axis of rotor



8C17



UR-



others



DC current input of rotor DC voltage input for rotor earth fault protection



Reserved



5.2.14 Pins definition of ‗9B‘ connectors Connector 8B:



126



18 pins for current input



NR ELECTRIC CO., LTD



Chapter5 Hardware Description 1



2



3



4



5



I AN



IA



I BN



IB



ICN



6



IC



7



I AN



TO LPF TO LPF



9



IA



I BN



10



IB



11



12



ICN



IC



TO LPF



I ' trans



I trans I ' shaft



I shaft U '0TV1 U0TV1



13



14



16



15



8



17



18



Figure 5.2-14 Connector 9B of RCS-985G



9B1



IA‘



phase A current of excitation transformer of exciter on side1



9B2



IA



phase A current of excitation transformer of exciter on side1 (polarity mark)



9B3



IB‘



phase B current of excitation transformer of exciter on side1



9B4



IB



phase B current of excitation transformer of exciter on side1 (polarity mark)



9B5



IC‘



phase C current of excitation transformer of exciter on side1



9B6



IC



phase C current of excitation transformer of exciter on side1 (polarity mark)



9B7



IA‘



phase A current of excitation transformer of exciter on side2



9B8



IA



phase A current of excitation transformer of exciter on side2 (polarity mark)



9B9



IB‘



phase B current of excitation transformer of exciter on side2



9B10



IB



phase B current of excitation transformer of exciter on side2 (polarity mark)



9B11



IC‘



phase C current of excitation transformer of exciter on side2



9B12



IC



phase C current of excitation transformer of exciter on side2 (polarity mark)



9B13



Itrs‘



Transverse current



9B14



Itrs



Transverse current (polarity mark)



9B15



Shaft current



9B16



Shaft current(polarity mark)



9B17



U0‘



9B18



U0



Zero sequence voltage derived from open-delta of TV1



Note: Current channel of side 1 can be configured as the current of HV side of excitation transformer or the neutral current of exciter. Current channel of side 2 can be configured as the current of LV side of excitation transformer or the terminal current of exciter.



NR ELECTRIC CO., LTD



127



Chapter5 Hardware Description



5.2.15 Pins definition of ‗9C‘ connectors Connector 9C:



18 pins for current input 1



2



3



4



5



I AN



IA



I BN



IB



I CN



6



7



I AN



IC



TO LPF



8



9



IA



10



I BN



11



IB



I CN



12



IC



TO LPF



TO LPF I AN



13



IA



I BN



IB



I CN



IC



14



15



16



17



18



Figure 5.2-15 Connector 9C of RCS-985G 9C1



IA‘



phase A current of generator‘s terminal



9C2



IA



phase A current of generator‘s terminal (polarity mark)



9C3



IB‘



phase B current of generator‘s terminal



9C4



IB



phase B current of generator‘s terminal (polarity mark)



9C5



IC‘



phase C current of generator‘s terminal



9C6



IC



phase C current of generator‘s terminal (polarity mark)



9C7



IA‘



phase A current of phase-splitting branch1 of generator



9C8



IA



phase A current of phase-splitting branch1 of generator (polarity mark)



9C9



IB‘



phase B current of phase-splitting branch1 of generator r



9C10



IB



phase B current of phase-splitting branch1 of generator (polarity mark)



9C11



IC‘



phase C current of phase-splitting branch1 of generator



9C12



IC



phase C current of phase-splitting branch1 of generator (polarity mark)



9C13



IA‘



phase A current of configurable current input channel



9C14



IA



phase A current of configurable current input channel (polarity mark)



9C15



IB‘



phase B current of configurable current input channel



9C16



IB



phase B current of configurable current input channel (polarity mark)



9C17



IC‘



phase C current of configurable current input channel



9C18



IC



phase C current of configurable current input channel (polarity mark)



Note: 9C13—9C18 can be configured as the current of phase-splitting branch2, dedicate current for reverse power protection and current used for distance protection of voltage-controlled overcurrent protection. The protection can either use zero sequence voltage derived from 9B17, 9B18 or calculated zero sequence voltage of TV1 depending on the setting way of the related logic setting. 128



NR ELECTRIC CO., LTD



Chapter5 Hardware Description



5.3



Output



5.3.1 Tripping outputs The equipment provides 12 groups of tripping relays with 29 pairs of contacts totally as shown in the following figure. These tripping relays can be configured by tripping output logic setting, and practical and flexible tripping modes can be provided by each protective function then. The tripping output logic setting is a specific setting of each certain protective function. Please refer to Chapter 7 for details of setting. Trip CB of GROUP1--TJ1 TJ1-1



1A03



TJ1-2



1A07



TJ1-3



1A11



1A18



1A09



1A22



1A13



TJ1-4



1A15



1A05



1A17



TJ2-1



1A25



TJ2-3



1A27



1A29



TJ2-4



1B01



1A02



1A21



TJ2-2



1A23



1B03



Trip CB OF GROUP3--TJ3 TJ3-1 TJ3-2



1A06



TJ3-3



1A10



TJ3-4



1A14



TJ4-2 Trip CB of GROUP5--TJ5 TJ5-1 TJ5-2



1B02



Trip CB of GROUP2--TJ2 1A19



1A26



Trip CB of GROUP4--TJ4 TJ4-1



TJ5-3



1B06



TJ5-4



1B10



1B05



Trip CB of GROUP6--TJ6 TJ6-1 TJ6-2



1B09



TJ6-3



1B13 1A04 1A08



1B17



1A12 1A16



1B21



Trip CB of GROUP7--TJ7 TJ7-1 Trip CB of GROUP8--TJ8 TJ8-1



1A20



1B25



Trip CB of GROUP9--TJ9 TJ9-1 Trip CB of GROUP10--TJ10 TJ10-1



1A24 1B29



Trip CB of GROUP11--TJ11 TJ11-1



1A28 1B04



1B14



1B08



1B18



TJ11-2



1B30



1B16 1B20



Trip CB of GROUP12--TJ12 TJ12-1



1B12



1B24



1B22 1B07



1B27



1B26



TJ12-2



1B28



1B11 1B15



1B19



1B23



Figure 5.3-1 List of tripping outputs The tripping output logic setting is a 4 digits hexadecimal number or a 16 bits binary number. Every bit corresponds to a circuit breaker. The breaker will be tripped if the corresponding bit is set as ―1‖ and not tripped if the bit is set as ―0‖. Table 5.3-1 Tripping logic and contacts of output relays No 1 2 3



Bit No. Bit 0 Bit 1 Bit 2



Tripping group No. Tripping function enabled BO_TrpOutp1 (TJ1) BO_TrpOutp2 (TJ2)



4 4



4



Bit 3



BO_TrpOutp3 (TJ3)



4



5



Bit 4



BO_TrpOutp4 (TJ4)



2



6



Bit 5



BO_TrpOutp5 (TJ5)



4



7



Bit 6



BO_TrpOutp6 (TJ6)



3



8



Bit 7



BO_TrpOutp7 (TJ7)



1



9



Bit 8



BO_TrpOutp8 (TJ8)



1



10



Bit 9



BO_TrpOutp9 (TJ9)



1



11



Bit 10



BO_TrpOutp10 (TJ10)



1



NR ELECTRIC CO., LTD



Quantity of tripping contacts



129



Chapter5 Hardware Description



12



Bit 11



BO_TrpOutp11 (TJ11)



2



13



Bit 12



BO_TrpOutp12 (TJ12)



2



5.3.2 Signaling outputs The equipment provides 18 signals and each signal consists of 1 magnetic latching contact (for local signals) and 2 wiper-type contacts (for SOE and remote signals). See the figure below. Local signal BO_Diff_Gen BO_EF_Sta BO_OvLd_Sta BO_LosExc_Gen BO_OV_Gen BO_RevP_Gen BO_FreqProt_Gen BO_AccEnerg_Gen BO_UV_Gen



2A01 2A07 2A13 2A19 2A25 2B01 2B07 2B13 2B19 2B25



Remote signal BO_Diff_Gen BO_EF_Sta BO_OvLd_Sta BO_LosExc_Gen BO_OV_Gen BO_RevP_Gen BO_FreqProt_Gen BO_AccEnerg_Gen BO_UV_Gen



2A02 BO_IntTurn_Gen BO_EF_Rot BO_NegOC_Gen BO_OOS_Gen BO_OvExc_Gen BO_SeqTrpRevP_Exc BO_PPF_Gen BO_Trp_MechRly_ BO_Bak_Exc



2A08 2A14 2A20 2A26 2B02 2B08 2B14 2B20 2B26



2A03 2A09 2A15 2A21 2A27 2B03 2B09 2B15 2B21 2B27



Event Record BO_Diff_Gen BO_EF_Sta BO_OvLd_Sta BO_LosExc_Gen BO_OV_Gen BO_RevP_Gen BO_FreqProt_Gen BO_AccEnerg_Gen BO_UV_Gen



BO_EF_Rot BO_NegOC_Gen BO_OOS_Gen BO_OvExc_Gen BO_SeqTrpRevP_Exc BO_PPF_Gen BO_Trp_MechRly_ BO_Bak_Exc



2A10 2A16 2A22 2A28 2B04 2B10 2B16 2B22 2B28



2A11 2A17 2A23 2A29 2B05 2B11 2B17 2B23 2B29 2A06



2A04 BO_IntTurn_Gen



2A05



BO_IntTurn_Gen BO_EF_Rot BO_NegOC_Gen BO_OOS_Gen BO_OvExc_Gen BO_SeqTrpRevP_Exc BO_PPF_Gen BO_Trp_MechRly_ BO_Bak_Exc



2A12 2A18 2A24 2A30 2B06 2B12 2B18 2B24 2B30



Figure 5.3-2 List of signaling outputs



130



NR ELECTRIC CO., LTD



Chapter5 Hardware Description



5.3.3 Alarming outputs Local signal BO_Alm_FAIL BO_Alm_Abnor BO_Alm_CTS BO_Alm_VTS BO_Alm_OvLd BO_Alm_NegaOC_Gen BO_Alm_UV_Gen BO_Alm_EF_Sta BO_Alm_1PEF BO_Alm_LossEXC_Gen BO_Alm_OOS_Gen BO_Alm_FreqProt_Gen BO_Alm_RevPwr_Gen BO_Alm_OvExc_Gen



3A01 3A03 3A05 3A07 3A09 3A11 3A13 3A15 3A17 3A19 3A21 3A23 3A25 3A27 3A29



Remote signal BO_Alm_FAIL BO_Alm_Abnor BO_Alm_CTS BO_Alm_VTS BO_Alm_OvLd BO_Alm_NegaOC_Gen BO_Alm_UV_Gen BO_Alm_EF_Sta BO_Alm_1PEF BO_Alm_LossEXC_Gen BO_Alm_OOS_Gen BO_Alm_FreqProt_Gen BO_Alm_RevPwr_Gen BO_Alm_OvExc_Gen



Event record



3A02



BO_Alm_FAIL



3A04



BO_Alm_Abnor



3A06



BO_Alm_CTS



3A08



BO_Alm_VTS



3A10



BO_Alm_OvLd



3A12



BO_Alm_NegaOC_Gen



3A14



BO_Alm_UV_Gen



3A16



BO_Alm_EF_Sta



3A18



BO_Alm_1PEF



3A20



BO_Alm_LossEXC_Gen



3A22



BO_Alm_OOS_Gen



3A24



BO_Alm_FreqProt_Gen



3A26



BO_Alm_RevPwr_Gen



3A28



BO_Alm_OvExc_Gen



3A30



3B04 3B26 3B28 3B06 3B08 3B10 3B12 3B14 3B16 3B18 3B20 3B22 3B24 3B29 3B30



Figure 5.3-3 List of alarming outputs



5.3.4 Other outputs 3B01 3B05



BO_OC_InitBFP BO_OC_InitBFP



3B03 3B07



Figure 5.3-4 List of other outputs



NR ELECTRIC CO., LTD



131



Chapter5 Hardware Description



132



NR ELECTRIC CO., LTD



Chapter6 Software Overview



Chapter6 Software Overview 6.1



Software Overview



The software for the relay can be conceptually split into three elements: the system services software, the platform software and the protection and control software. These three elements are not distinguishable to the user, and are all processed by the same processor board. The distinction between the three parts of the software is made purely for the purpose of explanation here: Protection& control Software



Measurement and event, fault & disturbance records



Disturbance recorder task



Protection task Scheme logic



Platform Software



Protection algorithms



Fourier signal processing



Protection & Control Settings



Supervisor task



Event, fault, disturbance maintenance record logging



Settings database



Sampling function



Front panel interface – LCD & keypad



Control of output contacts and LEDs



Remote communication interface – IEC60870-5-103



Remote communication interface - Modbus



Local & Remote communication interface



Control of interfaces to keypad, LCD, LEDS & rear communication ports. Self-checking maintenance records



Sample data & digital logic input



System services software



Relay hardware



Figure 6.1-1 Software structure of RCS-985G



6.2



System services software



As shown in Figure 6.1-1, the system services software provides the interface between the relay‘s hardware and the higher-level functionality of the platform software and the protection & control software. For example, the system services software provides drivers for items such as the LCD display, the keypad and the remote communication ports, and controls the boot of the processor and downloading of the processor code into SRAM from flash EPROM at power up. NR ELECTRIC CO., LTD



133



Chapter6 Software Overview



6.3



Platform software



The platform software has three main functions: To control the logging of records that are generated by the protection software, including alarms and event, fault, and maintenance records. To store and maintain a database of all of the relay‘s settings in non-volatile memory. To provide the internal interface between the settings database and each of the relay‘s user interfaces, i.e. the front panel interface and the front and rear communication ports, using whichever communication protocol has been specified (Courier, MODBUS, and IEC 60870-5-103).



6.3.1 Record logging The logging function is provided to store all alarms, events, faults and maintenance records. The records for all of these incidents are logged in a battery backed-up SRAM in order to provide a non-volatile log of what has happened. The relay maintains four logs: one each for up to 32 alarms, 32 event records, 32 fault records and 8 cycles of normal operation waveform. The logs are maintained such that the oldest record is overwritten with the newest record. The logging function can be initiated from the protection software or the platform software is responsible for logging of a maintenance record in the event of a relay failure. This includes errors that have been detected by the platform software itself or error that are detected by either the system services or the protection software function. See also the section on supervision and diagnostics in this manual.



6.3.2 Settings database The settings database contains all of the settings and data for the relay, including system parameters, equipments parameters and the protection settings. The parameters and settings are maintained in non-volatile memory. The platform software‘s management of the settings database includes the responsibility of ensuring that only one user interface modifies the settings of the database at any one time. This feature is employed to avoid conflict between different parts of the software during a setting change.



6.3.3 Database interface The other function of the platform software is to implement the relay‘s internal interface between the database and each of the relay‘s user interfaces. The database of settings and measurements must be accessible from all of the relay‘s user interfaces to allow read and modify operations. The platform software presents the data in the appropriate format for each user interface.



6.3.4 Protection and control software The protection and control software task is responsible for processing all of the protection elements and measurement functions of the relay. To achieve this it has to communicate with both the system services software and the platform software as well as organize its own operations. The protection software has the highest priority of any of the software tasks in the relay in order to provide the fastest possible protection response. The protection & control software has a



134



NR ELECTRIC CO., LTD



Chapter6 Software Overview



supervisor task that controls the start-up of the task and deals with the exchange of messages between the task and the platform software. 6.3.4.1 Overview - protection and control scheduling After initialization at start-up, the protection and control task is suspended until there are sufficient samples available for it to process. The acquisition of samples is controlled by a ‗sampling function‘ which is called by the system services software and takes each set of new samples from the input module and stores them in a two-cycle buffer. The protection and control software resumes execution when the unprocessed sample‘s in the buffer reaches a certain number. For the RCS-985G protection relay, the protection task is executed at the same speed as the sampling rate, i.e. the calculation of all relays is finished before next sampling process. During the residual time, operations by other software tasks take place. 6.3.4.2 Signal processing The sampling function provides filtering of the digital input signals from the opto-isolators and frequency tracking of the analog signals. The digital inputs are checked against their previous value over 15ms. Hence a change in the state of one of the inputs must be maintained at least 15ms before it is registered with the protection and control software. The frequency tracking of the analog input signals is achieved by a recursive Fourier algorithm which is applied to one of the input signals, and works by detecting a change in the measured signal‘s phase angle. The calculated value of the frequency is used to modify the sample rate being used by the AC modules so as to achieve a constant sample rate of 24 samples per cycle of the power waveform. The value of the frequency is also stored for use by the protection and control task. 6.3.4.3 Event and fault recording A change in any digital input signal, protection element output signal, operation flags of fault detectors, tripping flags causes an event record to be created. When this happens, the protection and control task sends a message to the supervisor task to indicate that an event is available to be processed and writes the event data to a fast buffer in SRAM which is controlled by the supervisor task. When the supervisor task receives either an event or fault record message, it instructs the platform software to create the appropriate log in the battery backed-up SRAM. The operation of the record logging to battery backed-up SRAM is slower than the supervisor‘s buffer. This means that the protection software is not delayed waiting for the records to be logged in by the platform software. 6.3.4.4 Disturbance recorder The disturbance recorder operates as a separate task from the protection and control task. It can record the waveforms for up to 32 analog channels and the values of all digital signals of RCS-985G. The recording time is user selectable up to a maximum of 8 seconds. The disturbance recorder is supplied with data by the protection and control task once per sampling period. The disturbance recorder collates the data that it receives into the required length disturbance record. The disturbance records can be extracted by RCSPC that can also store the data in



NR ELECTRIC CO., LTD



135



Chapter6 Software Overview



COMTRADE format, thus allowing the use of other packages to view the recorded data.



6.4



Software downloading



The relay supports software downloading for the purpose of debugging or updating on site. Hardware requirement Basic requirement of computer: CPU: Pentium II 300 or higher level CPU, OS: Win98, Win98SE, WinMe, WinNT4.0(service pack 4 or higher), Win2000, WinXP; RAM: at least 128M, 256M is recommended; Space requirement: at least 200M free space on system hard disk; Displayer: support 800*600 or higher resolution at the 16bit color model; RS232 communication port; Software requirement: Special software RCSPC. Downloading method Note: Ensure that the board is not blank before downloading software to it, i.e., certain versions of software already exists on the board. Warning: If some unexpected cases occur, please do inform the factory first instead of dealing with it by yourself. RCS-985 GENERATOR PROTECTION



TRIP



ESC



CT ALARM



GRP



HEALTHY VT ALARM



ALARM



ENT



NARI RELAYS ELECTRIC CO., LD



5



3



2



2 3 5



136



NR ELECTRIC CO., LTD



Chapter6 Software Overview



Figure 6.4-1 Software downloading communication port Steps： 1. Connect RS-232 communication port of the computer and that mounted on front panel of RCS-985G protection equipment by a cable with DB-9 connectors on both ends, see Figure 6.4-1. 2. Run the program RCSPC. If the connection and settings are correct, the screen will display ―RCS-985G connected‖, such as Figure 6.4-2. But if it is not connected, please check whether the parameter setting of RCSPC corresponds with the relay, such as ―COM port‖ and ―Baud rate‖, see Figure 6.4-3.



Figure 6.4-2 Succeed connecting of RCSPC



NR ELECTRIC CO., LTD



137



Chapter6 Software Overview COM port must be the same with that connected with the relay Baud rate must be 9600bps



Figure 6.4-3 Parameter setting of RCSPC 3. Download CPU program. At first, make sure it is at CPU mode as ―CPU>‖, then press the button and select the correct program file, such as CPU.s19, to download into the CPU module. Make sure that the file FLASHCPU.s19 is in the same folder as the program file. 4. Download MON program. Change it to MON mode by typing ―MON‖, then ―MON>‖ will appear. Then repeat step 3 to download MON.s19 to MON module. Make sure the file FLASHMON.s19 is in the same folder as the program file. See Figure 6.4-4.



138



NR ELECTRIC CO., LTD



Chapter6 Software Overview



Figure 6.4-4 Change to MON mode and download program 5．After downloading CPU and MON programs, reset the equipment and download default settings. Then the ‗HEALTHY‘ LED on the front panel of the relay will illuminate. 6. Download FACE program. Change it to FACE mode by typing ―FACE‖ or ―PNL‖, then ―PNL>‖ will appear. Press the button



and select the 985xx_FACE.hex file to download it into the



panel module. Make sure the file FLASH_FACE.hex is in the same folder as the program file. 7. The user should now check and ensure that the software version, CRC code and the generating time of software are same as those recorded in the relevant documentations. Enter the menu ―Version‖, then new version of protection will be displayed on the LCD, see Figure 6.4-5.



VERSION CPUBrd: ABCDEFGH MONBrd: ABCDEFGH HMI:



RCS-985G3QM 1.00 2007-01-01 09:00 RCS-985G3QM 1.00 2007-01-01



09:00



RCS-985G3QM 1.00 2007-01-01



SUBQ_ID:



09:00



ABCD T_060902



SUBQ_12345678



Figure 6.4-5 Version of protection



NR ELECTRIC CO., LTD



139



Chapter6 Software Overview



140



NR ELECTRIC CO., LTD



Chapter7 Settings



Chapter7 Settings The relay must be configured to the system and application by means of appropriate settings. The settings of this relay include system parameters, protection element settings and scheme logic settings.



7.1



Equipment parameters



7.1.1 Setting list Table 7.1-1 List of equipment settings No.



Symbol



Range



Step



Default



1



Active_Grp



0～1



1



0



2



Equip_ID



6 characters maximum



3



Comm_Addr



0～255



1



1



4



COM1_Baud



1.2/2.4/4.8 / 9.6 /14.4/ 19.2 / 38.4 kbit/s



19.2 kbit/s



5



COM2_Baud



1.2/2.4/4.8 / 9.6 /14.4/ 19.2 / 38.4 kbit/s



19.2 kbit/s



6



Printer_Baud



4.8 / 9.6 /19.2 kbit/s



9.6k bit/s



7



Protocol



0000-FFFF



0011



logic setting ―1‖ - enable, ―0‖ - disable 8



En_Auto_Print



0/1



0



9



En_Net_Print



0/1



0



10



En_Remote_Cfg



0/1



0



11



GPS_Pulse



0/1



0



Note: Symbols of the parameter listed in above table are used for communication, printing and displaying on LCD.



7.1.2 Setting instruction of the parameters 1



No.1-- [Active_Grp]



Two setting groups can be configured for the equipment, and only one is active at one time. However, equipment parameters and system parameters are common for all protection setting groups. 2



No.2-- [Equip_ID]



The setting consists of ASCII codes, which is identification for report printing only. It can be configured according to the name or number of generator. 3



No.3-- [Comm_Addr]



NR ELECTRIC CO., LTD



141



Chapter7 Settings



The address used for the host computer to identify the equipment, usually provided by substation system. If the equipment is not connected to automation system, equipment address may be random. 4



No.4-- [Com1_Baud]



The baud rate of serial port 1 shall be selected from specified range. 5



No.5-- [Com2_Baud]



The baud rate of serial port 2 shall be selected from specified range. 6



No.6--[Printer_Baud]



The baud rate used for printer port shall be selected from specified range. 7



No.7-- [Protocol]



The logic setting consists of 16 binary digits but four hexadecimal digits can be viewed through device LCD screen. Every digit has a dedicated meaning and some digits have no definition. Following will be seen on PC through RCSPC software. 9



8



7



6



5



4



3



2



1



0



A: 103



10



A: LFP



11



A: MODBUS



12



B: 103



13



B: LFP



14



B: MODBUS



15



The definitions of digits are: Table 7.1-2 Definition of logic setting of communication protocol Bit 0 1 2 3 4 5 6 7-15



Definition communication port A using protocol IEC 60870-5-103 communication port A using proprietary protocol LFP communication port A using MODBUS protocol No definition communication port B using protocol IEC 60870-5-103 communication port B using proprietary protocol LFP communication port B using MODBUS protocol No definitions



For example, if logic setting [Protocol] is set as ―0011‖, it means communication both port A and B use IEC 60870-5-103 protocol. 8



No.8-- [En_Auto_Print]



This setting shall be set as ―1‖ if automatic report printing is expected after the relay operates when a fault occurs. Otherwise it shall be set as ―0‖. It is suggested that the user may set this parameter of the equipment as ―1‖ (i.e. automatic printing), if the equipment is always connected 142



NR ELECTRIC CO., LTD



Chapter7 Settings



directly with a printer, or set as ―0‖ (i.e. not automatic printing) if the equipment is connected with a printer by through switch on panel. 9



No.9-- [En_Net_Print]



Set it as ―1‖ if shared network printer is used for printing. Set it as ―0‖ if dedicated printer is used. Network printer means several protection equipments share one printer through a printer management unit and RS-485 port. Dedicated printer means the protection equipment is connected with a printer through RS232 port directly. 10 No.10--[En_Remote_Cfg] Set it as ―0‖ if only local configuration is permitted. Set it as ―1‖ if local and remote configurations are both permitted. 11 No.11-- [GPS_Pulse] Set it as ―1‖ for minute pulse and ―0‖ for second pulse.



7.1.3 Setting path Access path in menu is: Main Menu -> SETTINGS -> EQUIP SETTINGS -> [setting symbol]



7.2



System Settings



7.2.1 Logic settings of configuring functions 7.2.1.1 Settings list Table 7.2-1 List of protection configuration setting No.



Symbol



Range



Default



1



En_Diff_Gen



0/1



0



2



En_SPTDiff_Gen



0/1



0



3



En_IntTurn_Gen



0/1



0



4



En_PPF_Gen



0/1



0



5



En_EF_Sta



0/1



0



6



En_EF_RotWdg



0/1



0



7



En_OvLd_Sta



0/1



0



8



En_NegOC_Gen



0/1



0



9



En_LossExc_Gen



0/1



0



10



En_OOS_Gen



0/1



0



11



En_VoltProt_Gen



0/1



0



12



En_OvExc_Gen



0/1



0



13



En_PwrProt_Gen



0/1



0



14



En_FreqProt_Gen



0/1



0



NR ELECTRIC CO., LTD



143



Chapter7 Settings



15



En_StShut_Gen



0/1



0



16



En_AccEnerg_Gen



0/1



0



17



En_Diff_Exc



0/1



0



18



En_Bak_Exc



0/1



0



19



En_OvLd_RotWdg



0/1



0



20



En_MechRly



0/1



0



21



En_VTComp_Term_Gen



0/1



0



22



En_BFP_GCB



0/1



0



23



En_TestMode(＃)



Disable/Enable



Disable



Note: Symbols of the parameter listed in above table are used for communication, printing and displaying on LCD. Setting marked with “＃” means that it is can not be seen on LCD or by printing and only can be seen through RCSPC software. 7.2.1.2 Explanation of the parameters for setting 1



No.1-- [En_Diff_Gen]



This logic setting is used for configuration of protection functions. Setting it as ―1‖ means the generator differential protection is enabled and setting as ―0‖ means the protection is disabled. 2



No.2-- [En_SPTDiff_Gen]



This logic setting is used to enable phase-splitting transverse differential protection. 3



N0.3-- [En_IntTurn_Gen]



This logic setting is used to enable interturn fault protection. 4



No.4-- [En_PPF_Gen]



This logic setting is used to enable phase-to-phase backup protection of generator. 5



No.5-- [En_EF_Sta]



This logic setting is used to enable earth fault protection of stator. 6



No.6-- [En_EF_RotWdg]



This logic setting is used to earth fault protection of rotor. 7



No.7-- [En_OvLd_Sta]



This logic setting is used to enable overload function of stator. 8



No.8-- [En_NegOC_Gen]



This logic setting is used to enable negative sequence overcurrent protection of stator. 9



144



No.9-- [En_LossExc_Gen]



NR ELECTRIC CO., LTD



Chapter7 Settings



This logic setting is used to enable loss-of-excitation protection of generator. 10 No.10-- [En_OOS_Gen] This logic setting is used to enable out-of-step protection of generator. 11 No.11-- [En_VoltProt_Gen] This logic setting is used to enable overvoltage and undervoltage protection of generator. 12 No.12-- [En_OvExc_Gen] This logic setting is used to enable overexcitation protection of generator. 13 No.13-- [En_PwrProt_Gen] This logic setting is used to enable overpower and underpower protection of generator. 14 No.14-- [En_FreqProt_Gen] This logic setting is used to enable overfrequency and underfrequency protection of generator. 15 No.15-- [En_StShut_Gen] This logic setting is used to enable all relevant protections in Startup/shutdown conditions of generator. 16 No.16-- [En_AccEnerg_Gen] This logic setting is used to enable relevant protection in case of accident energization of generator. 17 No.17-- [En_Diff_Exc] This logic setting is used to enable differential protection of exciting transformer or exciter. 18 No.18-- [En_Bak_Exc] This logic setting is used to enable backup protection of exciting transformer or exciter. 19 No.19-- [En_OvLd_RotWdg] This logic setting is used to enable overload function of rotor winding. 20 No.20-- [En_MechRly] This logic setting is used to enable mechanical protection. 21 No.21-- [En_VTComp_Term_Gen] This logic setting is used to enable comparison function of VTs at the generator terminal. 22 No.22-- [En_BFP_GCB] This logic setting is used to enable breaker failure protection of generator. 23 No.24-- [En_TestMode] (#)



NR ELECTRIC CO., LTD



145



Chapter7 Settings



This logic setting is configured especially for equipment debugging status. It is only seen by RCSPC, which is used for generating messages of alarm or operation element for remote PC. ―Enable‖: enable sending all tripping contacts signals, protection tripping signals, alarm signals and monitoring signals through DBU2000 software. ―Disable‖: disable the function mentioned above. 7.2.1.3 Setting path All logic settings of configuring functions are accessible in the following path: Main Menu -> SETTINGS -> SYSTEM SETTINGS -> PROT CONFIG -> [setting symbol]



7.2.2 Generator system parameters After one selects current and voltage channel according to the requirement of specific application, next step is to configure generator system parameters. Please note voltage or current setting of channel selecting in implicit configuration settings is almost corresponding to the setting of ratio of VT or CT except few ones which will be mentioned later. 7.2.2.1 Setting list Table 7.2-2 List of generator system settings No. 1



fn_Gen



Range 50/60 Hz



2



Pn_Gen



0-6000.0 MW



0.1 MW



300



3



PF_Gen



0.00-1.00



0.01



0.85



4



U1n_Gen



0-600.00 kV



0.01 kV



20



5



U1n_VT_Term_Gen



0-600.00 kV



0.01 V



11.55



6



U2n_VT_Term_Gen



57.74-110.00 V



0.01 V



57.74



7



U2n_DeltVT_Term_Gen



33.33-330.00 V



0.01 V



33.33



8



U1n_VT_NP_Gen



0-600.00 kV



0.01 kV



11.55



9



U2n_VT_NP_Gen



0-600.00 V



0.01 V



110



10



I1n_CT_Term_Gen



0-60000 A



1A



12000



11



I2n_CT_Term_Gen



1A/5A



1A



1



12



k_SP1_Gen



0-100.00 %



0.01 %



50



13



k_SP2_Gen



0-100.00 %



0.01 %



50



14



I1n_CT_SP1_Gen



0-60000 A



1A



15



I2n_CT_SP1_Gen



1A/5A



16



I1n_CT_SP2_Gen



0-60000 A



17



I2n_CT_SP2_Gen



1A/5A



18



I1n_CT_TrvDiff_Gen



0-60000 A



19



I2n_CT_TrvDiff_Gen



1A/5A



I1n_RotWdg



0-60000 A



20 146



Symbol



Step



Default 50



12000 1



1A



12000 5



1A



600 1



1A



1000 NR ELECTRIC CO., LTD



Chapter7 Settings



21



U2n_Shunt_RotWdg



0-100.00 mV



0.01 mV



75



Note: Symbol of the parameters listed in above table are used for communication, printing and displaying on LCD. 7.2.2.2 Setting instruction of the parameters 1



No.1-- [fn_Gen]



This setting indicates the nominal frequency of power system in which the generator protection equipment is in service. 2



No.2-- [Pn_Gen]



Capacity of active power of the generator shall be configured as its name plate stated. 3



No.3-- [PF_Gen]



Rated power factor of generator. 4



No.4-- [U1n_Gen]



System rated voltage at the terminal of generator. This setting is used for calculating the rated current of generator. It should be set according to the real operating voltage of the power system. 5



No.5-- [U1n_VT_Term_Gen]



Rated primary voltage of VT at the terminal of generator. This parameter can be configured as either phase voltage or phase-to-phase voltage value. For example, if the terminal VT ratio is



20kV 100V 3 3



100V , this parameter and the following two (NO.6 and NO.7) can be set as 3



11.55kV, 57.74V and 33.33V or can be set as 20kV, 100V and 57.74V. This is used for substation automation system. From this setting and the next two ones, VT ratio can be got. Secondary voltage and current recorded by the equipment will be transferred to primary value by multiplying VT ratio when fault oscillogram is sent to the host. 6



No.6-- [U2n_VT_Term_Gen]



Rated secondary voltage of VT at the terminal of generator. 7



No.7-- [U2n_DeltVT_Term_Gen]



Rated secondary open-delta voltage at the terminal of generator. 8



No.8-- [U1n_VT_NP_Gen]



Rated primary voltage of VT at the neutral point of generator. 9



No.9-- [U2n_VT_NP_Gen]



Rated secondary voltage of VT at the neutral point of generator. NR ELECTRIC CO., LTD



147



Chapter7 Settings



10 No.10-- [I1n_CT_Term_Gen] Rated primary current of CT at the terminal of the generator. 11 No.11-- [I2n_CT_Term_Gen] Rated secondary current of CT at the terminal of the generator. 12 No.12-- [k_SP1_Gen] Branching coefficient of the first group of windings to the whole stator. At the generator neutral point, two channels of CT input are reserved which can meet the requirement of both differential protection and phase-splitting transverse differential protection. The branching coefficient can be set according to the proportion of per branch occupying in the whole winding. For the case that only one branch can be drawn out from the neutral point of generator, the branching coefficient of the first one group branch must be set as 100% and the other branching coefficient must be set as 0%. 13 No.13-- [k_SP2_Gen] Branching coefficient of the second group of windings to the whole of stator. 14 No.14-- [I1n_CT_SP1_Gen] Rated primary current of CT of the first splitting branch of stator. 15 No.15-- [I2n_CT_SP1_Gen] Rated secondary current of CT of the first splitting branch of stator. 16 No.16-- [I1n_CT_SP2_Gen] Rated primary current of CT of the second splitting branch of stator. 17 No.17-- [I2n_CT_SP2_Gen] Rated secondary current of CT of the second splitting branch of stator. 18 No.18-- [I1n_CT_TrvDiff_Gen] Rated primary current of CT used for transverse differential protection. 19 No.19-- [I2n_CT_TrvDiff_Gen] Rated secondary current of CT used for transverse differential protection. 20 No.20-- [I1n_RotWdg] Primary rated current of rotor. This setting and the next one can be set conveniently by inputting the rated primary and secondary parameters of the shunt. 21 No.21-- [U2n_Shunt_RotWdg] Secondary rated voltage of rotor shunt.



148



NR ELECTRIC CO., LTD



Chapter7 Settings



7.2.2.3 Setting path All settings of generator system parameters are accessible in the following path: Main Menu -> SETTINGS -> SYSTEM SETTINGS -> GEN SYS SETTINGS -> [setting symbol] Note: These parameters are as important as the settings. They have to be configured according to actual application on site.



7.2.3 System parameters of excitation transformer or exciter 7.2.3.1 Setting list Table 7.2-3 List of excitation transformer of exciter settings No.



Symbol



Range



Step



Default



1



fn_Exc



50,100, 150Hz



2



Sn_Exc



0-100.00 MVA



0.01 MVA



0.5



3



U1n_S1_Exc



0-600.00 kV



0.01 kV



20



4



U1n_S2_Exc



0-600.00 kV



0.01 kV



6.3



5



I1n_CT_S1_Exc



0-60000 A



1A



20



6



I2n_CT_S1_Exc



1A,5A



7



I1n_CT_S2_Exc



0-60000 A



8



I2n_CT_S2_Exc



1A,5A



50



1 1A



60 1



Logic setting ―1‖ - enable, ―0‖ – disable 9



Opt_Exc



0, 1



0



10



Yy12_Conn_ET



0, 1



0



11



Dd12_Conn_ET



0, 1



0



12



Dy11_Conn_ET



0, 1



0



13



Yd11_Conn_ET



0, 1



1



14



Dy1_Conn_ET



0, 1



0



7.2.3.2 Setting instruction of the parameters 1



No.1-- [fn_Exc]



This setting indicates the nominal frequency of exciter. If excitation transformer is used, this setting can be set as 50Hz and the other settings in this table should be set according to relevant parameters of excitation transformer. 2



No.2-- [Sn_Exc]



Capacity of the exciter or excitation transformer shall be configured as its name plate stated. 3



No.3-- [U1n_S1_Exc]



NR ELECTRIC CO., LTD



149



Chapter7 Settings



The system rated voltage on HV side of the excitation transformer. This setting is used to calculate the correction coefficient of differential protection of excitation transformer. If exciter is used, this setting and NO.4 setting are all set as the rated voltage of exciter. 4



No.4-- [U1n_S2_Exc]



System rated voltage on LV side of the excitation transformer. This setting is used to calculate the correction coefficient of differential protection of excitation transformer. 5



No.5-- [I1n_CT_S1_Exc]



Primary rated current of the CT on HV side of the excitation transformer or CT at the terminal of the exciter. 6



No.6-- [I2n_CT_S1_Exc]



Secondary rated current of the CT on HV side of the excitation transformer or CT at the terminal of the exciter. 7



No.7-- [I1n_CT_S2_Exc]



Primary rated current of the CT on LV side of the excitation transformer or CT at the neutral point of the exciter. 8



No.8-- [I2n_CT_S2_Exc]



Secondary rated current of the CT on LV side of the excitation transformer or CT at the neutral point of the exciter. 9



No.9-- [Opt_Exc]



Exciter is used in the system. If this setting is set as ―1‖, that means exciter is used in the generator system instead of excitation transformer. Otherwise means the contrary. 10 No.10-- [Yy12_Conn_ET] The connection mode of excitation transformer is Yy-12 mode. Note: In the symbol of ―Yy-12‖, the first letter ―Y‖ represents the connection mode of windings on HV side, and the other ―y‖ represents the connection mode of windings on LV side, ―12‖ represents connection group between HV and LV windings. The following four settings are similar to this one. 11 No.11-- [Dd12_Conn_ET] The connection mode of excitation transformer is Dd-12 mode. 12 No.12-- [Dy11_Conn_ET] The connection mode of excitation transformer is Dy-11 mode. 13 No.13-- [Yd11_Conn_ET]



150



NR ELECTRIC CO., LTD



Chapter7 Settings



The connection mode of excitation transformer is Yd-11 mode. 14 No.14-- [Dy1_Conn_ET] The connection mode of excitation transformer is Dy-1 mode. 7.2.3.3 Setting path All settings of generator system parameters are accessible in the following path: Main Menu -> SETTING -> SYSTEM SETTINGS -> EXC SYS Settings -> [setting symbol]



7.2.4 Implicit configuration settings The settings in the following list are associated with application-specific primary layout of generator and exciter, tripping logics. These settings can not be seen on LCD of equipment and only be viewed and configured on PC through RCSPC software in the submenu “CONFIG SETTINGS‖. These settings are usually configured in factory or configured by field commission engineer according to the design drawing and project requirement. 7.2.4.1 Setting list Table 7.2-4 List of implicit configuration settings No. 1



Symbol Opt_Polar_CT (＃)



Range 0000-FFFF



Default 4:Curr_Chan



003F



2



Cfg_BakCT_Gen(＃)



A



3



Cfg_CT_Power_Gen (＃)



A



4:Curr_Chan No



4



En_MeterCT_Power_Gen (＃)



Yes/No



5



Opt_Gen_V0_by_Calc(＃)



Yes/No



No



6



Opt_SLD_1 (＃) Opt_SLD_2 (＃)



0/1



1 0



9



Opt_SLD_3 (＃) Opt_WaveRec_MON(＃)



0/1 0/1 Pickup/Trip



Pickup



10



Opt_Debug_MON(＃)



DSP2/DSP1



DSP2



11



Opt_Dur_WaveRec_MON(＃)



4S/8S



4S



12



En_Displ_Pickup(＃)



Yes/No



No



13



En_WaveRec_Alm (＃)



Yes/No



No



7 8



0



Note: For definitions of A in column range, please refer to section 7.2.4.2. Setting marked with ―＃‖ means that it is can not be seen on LCD or by printing, but only can be seen through RCSPC software.



NR ELECTRIC CO., LTD



151



Chapter7 Settings



7.2.4.2 CT channel selection A Three-phase current channel selection There are 6 options in three-phase current channel selection. 0: Curr_Chan 1 (Three-phase current channel 1) 1: Curr_Chan 2 (Three-phase current channel 2) 2: Curr_Chan 3 (Three-phase current channel 3) 3: Curr_Chan 4 (Three-phase current channel 4) 4: Curr_Chan 5 (Three-phase current channel 5) 5: Curr_Chan 6 (Three-phase current channel 6) 7.2.4.3 Explanation of the parameters and notice for setting 1



No.1-- [Opt_Polar_CT](＃)



This is the logic setting of CT polarity definition, which consists of sixteen binary digits. Every digit has specified meaning and some digits have no definition. Generally, CT polarity definition is as Figure 1.1-1 show. However if some CT polarity direction is reversed by incorrect wiring connection, there is still a chance to correct it by configuring this logic setting easily. Please set the corresponding digit of the logic setting.



10



9



8



7



6



5



4



3



2



1



0



Curr_Chann1(CT1_Exc)



11



Curr_Chann2(CT2_Exc)



12



Curr_Chann3(SpareCT1)



13



Curr_Chann4(CT_Term_Gen)



14



Curr_Chann5(CT_NP)



15



Curr_Chann6(SpareCT_Gen)



Following will be seen on PC through RCSPC software.



The definitions of digits are: Table 7.2-5 Definition of logic setting of CT polarity Bit 0 1 2 3 4 152



Definition CTs polarity of current channel 1 (CT1_Exc) reversed CTs polarity of current channel 2 (CT2_Exc) reversed CTs polarity of current channel 3 (SpareCT1) reversed CTs polarity of current channel 4 (CT_Term_Gen) reversed CTs polarity of current channel 5 (CT_NP) reversed NR ELECTRIC CO., LTD



Chapter7 Settings



5 6-15 2



CTs polarity of current channel 6 (SpareCT_Gen) reversed No definition



No.2-- [Cfg_BakCT_Term_Gen] (＃)



Logic setting of selecting three-phase current channel for backup protection of generator. 3



No.3-- [Cfg_CT_Power_Gen] (＃)



Logic setting of selecting three-phase current channel for reverse-power protection of generator. 4



No.4-- [En_MeterCT_Power_Gen] (＃)



Logic setting of selecting measuring CT for reverse-power protection of generator. If the external CT is measuring class, then the setting is remanded to set as ―Yes‖. Otherwise if the external CT is protection class, then the setting is set as ‖No‖. 5



No.5-- [Opt_Gen_V0_by_Calc](＃)



Logic setting of enabling zero sequence voltage is calculated from the terminal TV of generator. 6



No.6-- [Opt_SLD_1] , No.7-- [Opt_SLD_2], No.8-- [Opt_SLD_3](＃)



These three settings are the logic settings of generator connection. Settings [Opt_SLD_1] as ―1‖ means the scheme type consists of only the generator. Settings [Opt_SLD_2] as ―1‖ means the scheme type consists of generator and excitation transformer. Settings [Opt_SLD_3] is the backup connection type of generator and exciter. Note: Only one of the three settings can be set as ―1‖. 7



No.9--[Opt_WaveRec_MON] (＃)



Logic setting of selecting recording triggering mode of MON module. ―0‖: recording is triggered when any fault detector picks up. ―1‖: recording is triggered when any protection element trips. 8



No.10--[Opt_Debug_MON] (＃)



This logic setting is provided especially for software developing, not for ordinary users. 9



No.11--[Opt_Dur_WaveRec_MON] (＃)



Logic setting of selecting recording time of MON module. ―0‖: recording persisting time is 4s with 24 samples per cycle. ―1‖: recording persisting time is 8s with 12 samples per cycle.



NR ELECTRIC CO., LTD



153



Chapter7 Settings



10 No.12--[En_Displ_Pickup] (＃) This logic setting is provided especially for software developing, not for ordinary users. 11 No.13--[ En_WaveRec_Alm] (＃) Logic setting for enabling alarm signal to trigger wave record. Note: It is suggested to configure settings No.9-No.13 as default settings.



7.3



Protection Settings



7.3.1 Differential protection settings 7.3.1.1 Settings list Table 7.3-1 List of generator differential protection settings No.



Symbol



Range



Step



Default



1



I_Pkp_PcntDiff_Gen



0.10–1.50 (Ie)



0.01 (Ie)



0.1



2



I_InstDiff_Gen



2.00–14.00 (Ie)



0.01 (Ie)



6



3



Slope1_PcntDiff_Gen



0.00–0.50



0.01



0.05



4



Slope2_PcntDiff_Gen



0.30–0.80



0.01



0.5



5



TrpLog_Diff_Gen



0000–FFFF



1



1FFF



Logic setting ―1‖ - enable, ―0‖ – disable 6



En_InstDiff_Gen



0, 1



1



7



En_PcntDiff_Gen



0, 1



1



8



En_DPFC_Diff_Gen



0, 1



1



9



Opt_CTS_Blk_PcntDiff_Gen



0, 1



1



Note: Symbol of the parameters listed in above table are used for communication, printing and displaying on LCD. 7.3.1.2 Explanation of the settings 1



No.1-- [I_Pkp_PcntDiff_Gen]



This is a pickup setting of percentage current differential protection, which is also the setting of fault detector of percentage differential protection. It shall be higher than the maximum unbalanced current when the generator is operating on normal rated load, i.e.



I cdqd  K rel  2 0.03 I f 2 n



154



or



I cdqd  K rel  I unb .0



(Equation 7.3-1)



NR ELECTRIC CO., LTD



Chapter7 Settings



Where:



I f 2 n is secondary rated current of generator, I f 1n



I f 2n 



n fLH



Where:



I f 1n is primary rated current of generator and n fLH is ratio of generator CT.



I f 1n 



Pn / cos 3U f 1n



Where:



Pn is rated capacity of generator; cos  is power factor of generator and U f 1n is rated voltage of generator terminal.



K rel is reliability factor, 1.5 in general; I unb.0 is the measured actual unbalance current during rated load of generator, 0.2 I f 2 n -0.3 I f 2 n is recommended for reference. Where:



I cdqd represents the setting [I_Pkp_PcntDiff_Gen]. 2



No.2-- [I_InstDiff_Gen]



Setting of unrestrained instantaneous differential protection. Unrestraint instantaneous differential protection is a complementary part of differential protection. Its current setting shall be higher than the maximum unbalanced current due to breaker‘s asynchronous closure. For large unit, it can be set as high as 3 or 4 times of the rated current. 4 times of rated current is recommended. 3



No.3-- [Slope1_PcntDiff_Gen]



Setting of the first slope of percentage differential protection, it shall be:



NR ELECTRIC CO., LTD



155



Chapter7 Settings



K bl1  K rel  K cc  K er



(Equation 7.3-2)



Where:



K rel is reliability coefficient which is considered to be 1.0~2.0 in general; K cc



is the type factor of CT, 0.5 in general;



K er



is error factor of CT ratio, no more than 0.1.



K bl1 4



represents [Slope1_PcntDiff_Gen] which is set as 0.05~0.1 in general.



No.4-- [Slope2_PcntDiff_Gen]



Maximum value of restraint coefficient of the differential characteristic curve. With type factor of CT not taken into account, the maximum unbalance current is, ,



K unb . max  K ap  K er  K k . max



(Equation 7.3-3)



Where:



K ap



K er



is non periodic component factor, usually no less than 2.0;



is error factor of CT ratio, no more than 0.1;



I k . max



is periodic component of secondary value of external three phase short circuit current and it



can be taken as 4 times of rated current if it is less than 4 times of rated current. Maximum slope of percentage differential protection is:



k bl2 



I unb. max*  I cdqd*  2k bl1 I k . max*  2



（Equation 7.3-4）



where:



I unb. max*



，



I cdqd *



and



I k . max*



are all per unit value of rated current of generator;



kbl2 ([Slope2_PcntDiff_Gen] ) is taken as 0.50 generally. If the percentage differential protection is configured based on rules mentioned above, then when the phase-to-phase metallic short circuit fault occurs at the terminal of generator, sensitivity factor 156



NR ELECTRIC CO., LTD



Chapter7 Settings



will meet requirement 5



K sen



≥ 2 surely.



No.5-- [TrpLog_Diff_Gen]



TJ12: TrpOutp 12



TJ11: TrpOutp 11



TJ10: TrpOutp 10



6



5



4



3



2



1



0 Protection Enabled



No definition



7



TJ1: TrpOutp 1



No definition



8



TJ2: TrpOutp 2



No definition



9



TJ3: TrpOutp 3



10



TJ4: TrpOutp 4



11



TJ5: TrpOutp 5



12



TJ6: TrpOutp 6



13



TJ7: TrpOutp 7



14



TJ8: TrpOutp 8



15



TJ9: TrpOutp 9



bit



Function



Tripping output logic setting of differential protection is used to specify which breaker or breakers will be tripped by this protection. This word comprises of 16 binary bits as follows and is displayed as a hexadecimal number of 4 digits from 0000H to FFFFH on LCD of equipment. The tripping output logic setting is specified as follows:



Note: Set bit 0 as ―1‖ means this protection element will trip breaker or breakers when operating. The bit corresponding to the output channal shall be set as―1‖ and other bits shall be ―0‖. For example, if differential protection is defined to trip output channel 5, the bit ―0‖ and ―5‖ bit shall be set as ―1‖ and other bits ―0‖. Then a hexadecimal number 0021H is formed as the tripping output logic setting. Please note that tripping output logic settings of the equipment have to be set on the basis of application-specific drawings. All the tripping logic settings mentioned below is defined as same as this one. 6



No.6-- [En_InstDiff_Gen]



Unrestrained instantaneous differential protection enabled. If this setting is set as ―1‖, it means this protection is enabled. Otherwise it means the protection is disabled. 7



No.7-- [En_PcntDiff_Gen]



Percentage differential protection enabled. 8



No.8-- [En_DPFC_Diff_Gen]



DPFC percentage differential protection enabled. 9



No.9-- [Opt_CTS_Blk_PcntDiff_Gen]



If this logic setting is set as ―1‖, it means percentage differential protection will be blocked when CT circuit failure take place. Otherwise it means the blocking function is disabled. 7.3.1.3 Setting path All settings of differential protection settings are accessible in the following path: NR ELECTRIC CO., LTD



157



Chapter7 Settings



Main Menu -> SETTINGS -> PROT SETTINGS -> GEN DIFF PROT --> [setting symbol]



7.3.2 Splitting-phase transverse differential protection settings 7.3.2.1 Setting list Table 7.3-2 List of splitting-phase transverse differential protection settings No.



Symbol



Range



Step



Default



1.



I_Pkp_PcntSPTDiff_Gen



0.10 – 1.50 (Ie)



0.01 (Ie)



0.1



2.



I_InstSPTDiff_Gen



2.00 – 14.00 (Ie)



0.01 (Ie)



6



3.



Slope1_PcntSPTDiff_Gen



0.00 -- 0.50



0.01



0.05



4.



Slope2_PcntSPTDiff_Gen



0.30 – 0.80



0.01



0.5



5.



TrpLog_SPTDiff_Gen



0000 -- FFFF



1



1FFF



Logic setting ―1‖ - enable, ―0‖ – disable 6.



En_InstSPTDiff_Gen



0，1



1



7.



En_PcntSPTDiff_Gen



0，1



1



8.



Opt_CTS_PcntSPTDiff_Gen



0，1



1



7.3.2.2 Explanation of the settings 1



No.1-- [I_Pkp_PcntSPTDiff_Gen]



This is pickup setting of splitting-phase transverse percentage current differential protection, which is also the setting of fault detector of this protection. It shall be higher than maximum unbalance current when the generator operates on normal rated load, i.e. ' I ' op.0  K rel ( I ' unb.1  I unb.2 )



（Equation 7.3-5） Where:



I ' op.0 : represents the setting [I_Pkp_PcntSPTDiff_Gen],



K rel : is reliability coefficient. In general, Krel = 1.3 – 1.5,



I ' unb.1 : is unbalance current due to amplitude error between the CTs used in this protection in load condition. In practical application, I



'



unb.1



= 0.06 I



'



2n



. Here, I



'



2n



is the secondary rated



current of CT.



I ' unb.2 : the second type unbalance current. Because each shunt branch of every phase is distributed in different grooves on the surface of rotor for hydro generator and the air gap field of each groove is different, therefore this second type of unbalance current appears.



158



NR ELECTRIC CO., LTD



Chapter7 Settings



User can also get the maximum unbalance current value by metering the real transverse unbalance current in full load condition of the generator. Generally speaking, the value is a little greater than the one of differential protection of generator. For reference, it can be set as I 2



'



op.0



 0.5I ' e . Here, I e' is secondary rated current of generator.



No.2-- [I_InstSPTDiff_Gen]



Setting of unrestrained splitting-phase transverse differential protection. 3



No.3-- [Slope1_PcntSPTDiff_Gen]



Setting of the first slope of percentage differential protection 4



No.4-- [Slope2_PcntSPTDiff_Gen]



Maximum value of restraint coefficient of the differential characteristic curve. 5



No.5-- [TrpLog_SPTDiff_Gen]



Tripping output logic setting of splitting-phase transverse differential protection. 6



No.6-- [En_InstSPTDiff_Gen]



Instantaneous splitting-phase transverse differential protection enabled. 7



No.7-- [En_PcntSPTDiff_Gen]



Percentage splitting-phase transverse differential protection enabled. 8



No.8-- [Opt_CTS_PcntSPTDiff_Gen]



If this logic setting is set as ―1‖, it means percentage splitting-phase transverse differential protection will be blocked when CT circuit failure happens. Otherwise it means the function is disabled. Setting path Settings of generator phase-splitting transverse protection are accessible in the following path: Main Menu -> SETTINGS -> PROT SETTINGS -> GEN SPTDIFF PROT->[setting symbol]



7.3.3 Settings of turn-to-turn fault protection of generator 7.3.3.1 Setting list Table 7.3-3 List of turn-to-turn fault protection settings No.



Symbol



Range



Step



Default



1



I_SensTrvDiff_Gen



0.10 – 50.00 A



0.01 A



2.0



2



I_InsensTrvDiff_Gen



0.10 – 50.00 A



0.01 A



10



3



t_TrvDiff_Gen



0.00 – 10.00 S



0.01 S



0.2



4



V_SensROV_Longl_Gen



1 – 10.00 V



0.01 V



1



NR ELECTRIC CO., LTD



159



Chapter7 Settings



1 – 20.00 V



0.01 V



6



t_ROV_Longl_Gen



0.00 – 10.00 S



0.01 S



0.1



7



TrpLog_IntTurn_Gen



0000 - FFFF



1



1FFF



8



Logic setting ―1‖ - enable, ―0‖ – disable 0，1 En_SensTrvDiff_Gen



9



En_InsensTrvDiff_Gen



0，1



1



10



En_SensROV_Longl_Gen



0，1



0



11



En_InsensROV_Longl_Gen



0，1



0



12



En_DPFC_IntTurn_Gen



0，1



0



5



V_InsensROV_Longl_Gen



6



1



7.3.3.2 Explanation of the parameters and notice for setting 1



NO.1—[I_SensTrvDiff_Gen]



Current setting of high sensitive transverse differential protection. Setting of this protection shall be higher than the maximum unbalanced current during normal operating condition. Reliability factor can be more than 2. The setting value is usually:



I op  0.05 I f ln / n a



（Equation 7.3-6）



Where:



I OP represents the setting [I_SensTrvDiff_Gen]. I f ln



na



is primary rated current of generator and is ratio of zero sequence CT of transverse differential protection.



Phase current restraint factor is a fixed coefficient in the program. 2



NO.2—[I_InsensTrvDiff_Gen]



Current setting of high-setting transverse differential protection. It is equivalent to traditional transverse differential protection. Setting of this protection is as follows which shall be higher than maximum unbalance current during external short circuit fault.



I op （0.20 ~ 0.30）I f ln / n a



（Equation 7.3-7）



Where:



I OP represents the setting [I_SensTrvDiff_Gen]. I f ln



na 160



is primary rated current of generator and is ratio of zero sequence CT of transverse differential protection. NR ELECTRIC CO., LTD



Chapter7 Settings



3



NO.3—[t_TrvDiff_Gen]



Delay of transverse differential protection (act on only after the occurrence of one-point ground of rotor). When one point earth fault occurs within rotor of generator and one point earth fault protection operates, in order to prevent unwanted operation of transverse protection due to instantaneous two points earth fault within the rotor, operation of this protection shall be delayed for 0.5 s – 1 s. Note: When a turn-to-turn fault occurs, the equipment will trip relevant breakers without delay according to the tripping output logic setting, but a time delay decided by user will be activated after the occurrence of one-point ground of rotor. 4



NO.4—[V_SensROV_Longl_Gen]



Voltage setting of high sensitive longitudinal zero sequence overvoltage protection . Setting of this protection shall be higher than maximum unbalance voltage during normal operation condition, usually:



U op  0.5 - 3 V



（Equation 7.3-8）



At beginning of configuration, 2 – 3 V is preferred. After fault waveform analysis, the setting can be reduced properly and sensitivity of the protection can be improved than. Phase current restraint factor is a fixed coefficient in the program. 5



NO.5—[V_InsensROV_Longl_Gen]



Setting of this protection shall be higher than maximum unbalance voltage during external fault, usually:



U op  8 - 12 V 6



（Equation 7.3-9）



NO.6—[t_ROV_Longl_Gen]



Delay of longitudinal zero sequence overvoltage. Short delay 0.10 s – 0.20 s is recommended for operation and output of this protection. 7



NO.7—[TrpLog_IntTurn_Gen]



Tripping output logic setting of turn-to-turn fault protection of generator. 8



NO.8—[En_SensTrvDiff_Gen]



Enable high sensitive transverse differential protection of generator. 9



NO.9—[En_InsensTrvDiff_Gen]



Enable high-setting transverse differential protection of generator. NR ELECTRIC CO., LTD



161



Chapter7 Settings



10 NO.10—[En_SensROV_Longl_Gen] Enable high sensitive longitude zero sequence overvoltage protection of generator. 11 NO.11—[En_InsensROV_Longl_Gen] Enable high-setting longitude zero sequence overvoltage protection of generator. 12 NO.12—[En_DPFC_IntTurn_Gen] Enable directional DPFC turn-to-turn fault protection of generator. 7.3.3.3 Setting path Settings of generator interturn protection are accessible in the following path: Main Menu -> SETTINGS -> PROT SETTINGS -> GEN INTTURN PROT --> [setting symbol].



7.3.4 Settings of backup protection of generator 7.3.4.1 Setting list Table 7.3-4 List of backup protection settings No.



Symbol



Range



Step



Default



1



V_NegOV_VCE_Gen



1.00 – 20.00 V



0.01 V



4



2



Vpp_UV_VCE_Gen



2.00 –100.00 V



0.01 V



60



3



I_OC1_Gen



0.10 –100.00 A



0.01 A



20



4



t_OC1_Gen



0.00 – 10.00 S



0.01 S



1



5



TrpLog_OC1_Gen



0000 - FFFF



1



000F



6



I_OC2_Gen



0.10 –100.00 A



0.01 A



17



7



t_OC2_Gen



0.00 – 10.00 S



0.01 S



2



8



TrpLog_OC2_Gen



0000 - FFFF



1



0F01



9



Z1_Fwd_Gen



0.00 –100.00 Ω



0.01 Ω



20



10



Z1_Rev_Gen



0.00 –100.00 Ω



0.01 Ω



20



11



t_Z1_Gen



0.00 – 10.00 S



0.01 S



1



12



TrpLog_Z1_Gen



0000 - FFFF



1



0FFF



13



Z2_Fwd_Gen



0.00 –100.00 Ω



0.01 Ω



20



14



Z2_Rev_Gen



0.00 –100.00 Ω



0.01 Ω



20



15



t_Z2_Gen



0.00 – 10.00 S



0.01 S



1



16



TrpLog_Z2_Gen



0000 - FFFF



1



0FFF



17



I_BO_OC_Gen



0.10 –100.00 A



0.01 A



20



18



Logic setting ―1‖ - enable, ―0‖ – disable 0，1 En_VCE_Ctrl_OC1_Gen



19



En_VCE_Ctrl_OC2_Gen



0，1



1



20



Opt_VTS_Ctrl_OC_Gen



0，1



1



21



Opt_ExcMode_Gen



0，1



1



22



En_BO_OC_Gen



0，1



1



162



1



NR ELECTRIC CO., LTD



Chapter7 Settings



7.3.4.2 Explanation of the settings 1



No.1-- [V_NegOV_VCE_Gen]



Negative sequence voltage setting of composite voltage control element. Setting and displayed value of negative sequence voltage are U2. Setting of negative sequence voltage relay shall be higher than unbalance voltage during normal operation, generally



U op.2  (0.06 - -0.08 ) U n



（Equation 7.3-10）



Where: U n is secondary rated voltage. Sensitivity factor shall be checked by phase-to-phase short circuit fault on HV side bus of main transformer:



K sen 



U 2. min U op2



（Equation 7.3-11）



Where:



U 2. min is minimum negative sequence voltage at location of the equipment during phase-to-phase short circuit fault on HV side bus of main transformer. K sen ≥ 1.5 is required. 2



NO.2—[Vpp_UV_VCE_Gen]



Setting of phase-to-phase undervoltage of composite voltage control element. Its operating voltage U op can be set as following: For turbine generator, U op  0.6 U gn and for hydro-generator, U op  0.7 U gn



Where



U gn



is rated phase-to-phase voltage of generator.



Sensitivity factor shall be checked by three-phase short circuit fault on HV side bus of main transformer:



K sen 



Where



U op ) X t  I k(3. max



) I k( 3. max



（Equation 7.3-12）



is maximum secondary fault current during three-phase short circuit on HV side bus



NR ELECTRIC CO., LTD



163



Chapter7 Settings



of main transformer; 3



Xt



is reactance of main transformer,



X t  Zt



.



K sen



≥ 1.2 is required.



NO.3—[I_OC1_Gen]



Setting of overcurrent protection stage 1. Setting of overcurrent relay shall be higher than rated current of generator.



I op 



K rel I gn Kr



（Equation 7.3-13）



Where:



K rel



is reliability factor, 1.3 – 1.5;



K r is release factor, 0.85 – 0.95; I gn



is secondary rated current of generator.



Sensitivity factor of overcurrent relay shall be checked by following:



K sen 



Where



) I k( 2. min I op



) I k( 2. min



（Equation 7.3-14）



is minimum fault current through location of the relay during phase-to-phase



metallic short circuit on HV side of main transformer. 4



K sen



≥ 1.2 is required.



NO.4—[t_OC1_Gen]



Time delay of overcurrent protection stage 1. Delay of this protection shall be higher than that of operation of backup protection of step-up transformer. This protection is used for islanding and generator shut off. 5



NO.5—[TrpLog_OC1_Gen]



Tripping output logic setting of overcurrent protection stage 1. 6



NO.6—[I_OC2_Gen]



Setting of overcurrent protection stage 2. Setting of overcurrent relay shall be higher than rated current of transformer. 7



NO.7—[t_OC2_Gen]



Time delay of overcurrent protection stage2.



164



NR ELECTRIC CO., LTD



Chapter7 Settings



8



NO.8—[TrpLog_OC2_Gen]



Tripping output logic setting of overcurrent protection stage2. 9



NO.9—[Z1_Fwd_Gen]



Positive direction impedance setting of distance protection stage1. Here positive direction means the direction is pointing to the transformer instead of generator itself. If the value of this setting is greater than the next one, then the characteristic of distance protection is set as excursive impedance circle; if it is equal to the next one, the characteristic is a whole impedance circle; if the next one is set as ―0‖, the characteristic becomes directional impedance. Generally, low impedance protection is considered as the backup protection of generator in case that voltage-controlled overcurrent protection can‘t satisfy the sensitivity requirement of the generator. 10 NO.10—[Z1_Rev_Gen] Negative direction impedance setting of distance protection stage1. In general, this setting is set as 5-10% of the positive direction impedance setting. 11 NO.11—[t_Z1_Gen] Delay of distance protection stage1. 12 NO.12—[TrpLog_Z1_Gen] Tripping output logic setting of distance protection stage 1. 13 NO.13—[Z2_Fwd_Gen] Positive direction impedance setting of distance protection stage2. 14 NO.14—[Z2_Rev_Gen] Negative direction impedance setting of distance protection stage2 15 NO.15—[t_Z2_Gen] Delay of distance protection stage2 16 NO.16—[TrpLog_Z2_Gen] Tripping output logic setting of distance protection stage1. Please refer to the tripping output logic setting of differential protection of main transformer for details. 17 NO.17—[I_BO_OC_Gen] Current setting of overcurrent element for controlling function of a set of contact. 18 NO.18—[En_VCE_Ctrl_OC1_Gen] Enable controlling function to stage 1 of overcurrent protection by Composite Voltage Element. 19 NO.19—[En_VCE_Ctrl_OC2_Gen]



NR ELECTRIC CO., LTD



165



Chapter7 Settings



Enable controlling function to stage 2 of overcurrent protection by Composite Voltage Element. 20 NO.20—[Opt_VTS_Ctrl_OC_Gen] Protection performance during VT circuit failure. ―1‖: when VT circuit failure at one side is detected, composite voltage element will be disabled if corresponding logic setting is set as ―1‖. ―0‖: when VT circuit failure at one side is detected, the voltage-controlled overcurrent element will become a pure overcurrent relay without composite voltage element controlling. 21 NO.21—[Opt_ExcMode_Gen] That the setting is set as ―1‖ indicates the excitation mode of generator is self shunt excitation mode. In that case, the protection will remember the current value at the initiation of fault, and operates based on it, no matter whether the current will decrease due to the descending excitation voltage result from terminal voltage‘s getting down when external fault occurs. Once this setting is set as ―1‖, the backup overcurrent protection of generator is always controlled by composite voltage element. 22 NO.22—[En_BO_OC_Gen] Enable blocking function of overcurrent element by outputting a set of contact. Note: In the above Table，current used in backup protection of generator comes from the backup current input channel. 7.3.4.3 Setting path Settings of generator phase-to-phase backup protection are accessible in the following path: Main Menu -> SETTINGS -> PROT SETTINGS -> GEN INTTURN PROT --> [setting symbol].



7.3.5 Settings of earth fault protection of stator windings 7.3.5.1 Setting list Table 7.3-5 List of earth fault protection settings of stator No.



Symbol



Range



Step



Default



1



V_SensROV_Sta



0.10 – 50.00 V



0.01 V



2.0



2



V_InsensROV_Sta



0.10 – 50.00 V



0.01 V



10



3



t_ROV_Sta



0.00 – 10.00 S



0.01 S



2



4



k_V3rdHRatio_PreSync_Sta



0.50 – 10.00



0.01



1



5



k_V3rdHRatio_PostSync_Sta



0.50 – 10.00



0.01



1



6



k_V3rdHDiff_Sta



0.10 – 2.00



0.01



1



7



t_V3rdH_Sta



0.00 – 10.00S



0.01 S



3



166



NR ELECTRIC CO., LTD



Chapter7 Settings



0000 – FFFF



8



TrpLog_EF_Sta



9



1



10



Logic setting ―1‖ - enable, ―0‖ – disable En_Alm_ROV_Sta 0，1 En_Trp_ROV_Sta 0，1



11



En_Alm_V3rdHRatio_Sta



0，1



1



12



En_Alm_V3rdHDiff_Sta



0，1



1



13



En_Trp_V3rdHRatio_Sta En_Trp_InsensRov_Sta



0，1



1



0，1



1



14



1



1FFF



1



7.3.5.2 Explanation of the settings 1



No.1-- [V_SensROV_Sta]



Setting of fundamental zero sequence overvoltage protection. Setting of this protection



U op



shall be higher than maximum unbalance voltage



U unb. max



of single



phase VT at neutral point during normal operation.



U op  K relU unb. max



Where



K rel



is reliability factor, 1.2 – 1.3 generally;



（Equation 7.3-15）



U unb. max



is the maximum measured



fundamental unbalanced zero sequence voltage derived from single VT at the neutral point of generator. To assure its security, user should check the transferred zero sequence voltage through coupling capacitance between HV side and LV side of transformer when external earth fault occurs on the HV side of the transformer. Meanwhile, settings, including time delay and operation setting, should be considered to cooperate with that of earth fault protection of the system. Note: The zero sequence voltage used in this protection comes from VT at the neutral point of generator. 2



NO.2—[V_InsensROV_Sta]



Setting of high-setting fundamental zero sequence overvoltage protection. Only zero sequence voltage at neutral point is taken for the high setting zone of fundamental zero sequence voltage protection. Its setting is usually 20 V – 25 V. Zero sequence voltage transferred by coupling capacitance per phase between HV and LV side windings of step-up transformer shall be checked when external fault occurs at HV side of the transformer. Coordinating both on setting and delay between this protection and system earth fault protection could be achieved then. 3



NO.3—[t_ROV_Sta]



Delay of fundamental zero sequence overvoltage protection. NR ELECTRIC CO., LTD



167



Chapter7 Settings



4



NO.4—[k_V3rdHRatio_PreSync_Sta]



Ratio setting of 3rd harmonics before incorporation of generator in power network. 







Let third harmonic voltage at the end and neutral point of generator be U t and U n , ratio setting of third harmonic voltage percentage earth fault protection shall be 



Ut







Un   （Equation 7.3-16）



and



  K rel



3  nTVN during pre-configuration, nTV 0



Where:



K rel



is reliability factor, 1.3 – 1.5 in general;



nTV 0



is ratio of open-delta zero sequence voltage at the terminal of generator;



n TVN



is ratio of zero sequence VT on neutral point.



During incorporation of generator to power system, the ratio



U 3T / U 3N



changes considerably



owing to variation of equivalent capacitive reactance at generator terminal. So two different settings are designed for protection before and after connection of generator with system, and these two settings can be switched over with alternation of contacts‘ position of the terminal breaker. The setting shall be (1.3 – 1.5)× 1 before incorporation and (1.3 – 1.5)× 2 after that. Where  1 and  2 are the maximum real-measured third harmonic voltage ratio before and after incorporation respectively. 5



NO.5—[k_V3rdHRatio_PostSync_Sta]



Ratio setting of 3rd harmonics after incorporation in power network. 6



NO.6—[k_V3rdH_Diff_Sta]



Restraint coefficient of percentage third harmonic voltage earth fault protection. 















U t  k p U n  k zd U n



168



（Equation 7.3-17）



NR ELECTRIC CO., LTD



Chapter7 Settings



Where: 



kp



is vectorial automatic tracing regulation factor;



k zd



is restraint factor [3rdHarm Diff. Ratio], 0.3 is recommended.



U t is 3rd harmonics derived from the terminal of generator.



U n is 3rd harmonics derived from the neutral point of generator. 7



NO.7—[t_V3rdH_Sta]



Delay of percentage third harmonic voltage earth fault protection. It shall be longer than that of backup protection against external fault . 8



NO.8—[TrpLog_EF_Sta]



Tripping output logic setting of stator earth fault protection. 9



NO.9—[En_Alm_ROV_Sta]



Enable alarm function of zero sequence overvoltage. 10 NO.10—[En_Trp_ROV_Sta] Enable zero sequence overvoltage protection. 11 NO.11—[En_Alm_V3rdHRatio_Sta] Enable alarm function of third harmonic voltage ratio element . 12 NO.12—[En_Alm_V3rdHDiff_Sta] Enable alarm function of third harmonics differential voltage. 13 NO.13—[En_Trp_V3rdHRatio_Sta] Enable tripping function of third harmonic voltage ratio element. 14 NO.14—[En_Trp_InsensRov_Sta] Enable tripping function of high-setting zero sequence overvoltage protection 7.3.5.3 Setting path Settings of stator earth fault protection are accessible in the following path: Main Menu -> SETTINGS -> PROT SETTINGS -> STA EF PROT --> [setting symbol].



NR ELECTRIC CO., LTD



169



Chapter7 Settings



7.3.6 Settings of earth fault protection of rotor 7.3.6.1 Setting list Table 7.3-6 List of earth fault protection settings of rotor No.



Symbol



Range



Step



Default



1



R_Sens1PEF_RotWdg



0.10 –100.00 kΩ



0.01 kΩ



20



2



R_1PEF_RotWdg



0.10 –100.00 kΩ



0.01 kΩ



20



3



t_1PEF_RotWdg



0.00 – 10.00 S



0.01 S



1



4



V2ndH_VCE_2PEF_RotWdg



0.10 – 10.00 V



0.01 V



2



5



t_2PEF_RotWdg



0.00 - 10.00 S



0.01 S



1



6



TrpLog_EF_RotWdg



0000 – FFFF



1



0FFF



7



Logic setting ―1‖ - enable, ―0‖ – disable 0，1 En_Alm_Sens_1PEF_RotWdg



8



En_Alm_1PEF_RotWdg



0，1



1



9



En_Trp_1PEF_RotWdg



0，1



1



10



En_2PEF_RotWdg



0，1



1



11



En_VCE_2PEF_RotWdg



0，1



1



1



7.3.6.2 Explanation of setting 1



NO.1—[R_Sens1PEF_RotWdg]



Impedance setting of sensitive stage of one-point earth fault protection of rotor. General specification of generator specifies that insulation resistance of its excitation winding shall be higher than 1 MΩ for air cooled and hydrogen-cooled turbine generator during cooling state, and 2 kΩ for water cooled excitation winding. General specification of hydro-generator specifies that insulation resistance of its excitation winding shall be higher than 0.5 kΩ in any case. Sensitive stage of this protection is used for alarm. Its setting could be 20 kΩ – 80 kΩ generally. 2



NO.2—[R_1PEF_RotWdg]



Impedance setting of one-point earth fault protection of rotor. Setting of one point earth fault protection can be 20 kΩ for air cooled and hydrogen-cooled turbine generator and 2.5 kΩ for water cooled excitation winding. This protection can be used for alarm or generator shutting with delay. Actual measured insulation resistance is used for this protection. 3



NO.3—[t_1PEF_RotWdg]



Delay of one-point earth fault protection of rotor. 4



NO.4--[V2ndH_VCE_2PEF_RotWdg]



Second harmonics voltage setting of two-point earth fault protection of rotor.



170



NR ELECTRIC CO., LTD



Chapter7 Settings



5



NO.5—[t_2PEF_RotWdg]



Delay of two-point earth fault protection of rotor. 6



NO.6—[TrpLog_EF_RotWdg]



Tripping output logic setting of earth fault protection of rotor. 7



NO.7—[En_Alm_Sens_1PEF_RotWdg]



Enable alarm function of sensitive stage of one-point earth fault protection of rotor. 8



NO.8—[En_Alm_1PEF_RotWdg]



Enable alarm function of one-point earth fault protection of rotor. 9



NO.9—[En_Trp_1PEF_RotWdg]



Enable tripping function of one-point earth fault protection of rotor. 10 NO.10—[En_2PEF_RotWdg] Enable two-point earth fault protection of rotor. 11 NO.11—[En_VCE_2PEF_RotWdg] Enable second harmonics used in two-point earth fault protection of rotor. 7.3.6.3 Setting path Settings of rotor earth fault protection are accessible in the following path: Main Menu -> SETTINGS -> PROT SETTINGS -> ROTWDG EF PROT --> [setting symbol].



7.3.7 Settings of thermal overload protection of stator 7.3.7.1 Setting list Table 7.3-7 List of thermal overload protection settings of stator No.



Symbol



Range



Step



Default



1



I_OvLd_Sta



0.10 – 50.00 A



0.01 A



10



2



t_OvLd_Sta



0.00 – 10.00 S



0.01 S



1



3



TrpLog_OvLd_Sta



0000 – FFFF



1



000F



4



I_Alm_OvLd_Sta



0.10 – 50.00 A



0.01 A



7



5



t_Alm_OvLd_Sta



0.00 – 10.00 S



0.01 S



2



6



I_InvOvLd_Sta



0.10 – 100.00 A



0.01 A



6



7



tmin_InvOvLd_Sta



0.10 – 10.00 S



0.01 S



1



8



A_Therm_Sta



1.00 –100.00



0.01



40



9



K_Disspt_Sta



0.00 – 10.00



0.01



1



10



TrpLog_InvOvLd_Sta



0000 – FFFF



1



0FFF



NR ELECTRIC CO., LTD



171



Chapter7 Settings



7.3.7.2 Explanation of setting 1



NO.1—[I_OvLd_Sta]



Setting of definite time overcurrent protection. Setting of this protection is determined by the requirement of reliable release during permissive continuous load current of generator.



I OP  K rel



I gn Kr



（Equation 7.3-18）



Where:



K rel



is reliability factor, 1.05 generally;



K r is release factor, 0.85 – 0.95; I gn



is secondary rated current of generator.



Delay of this protection shall be longer than maximum delay of backup protection. Alarm will be issued or load will be reduced when it operates. 2



NO.2—[t_OvLd_Sta]



Delay of definite time overcurrent protection. 3



NO.3—[TrpLog_OvLd_Sta]



Tripping output logic setting of definite time overcurrent protection. 4



NO.4-- [I_Alm_OvLd_Sta]



Setting of definite time overcurrent alarm. 5



NO.5—[t_Alm_OvLd_Sta]



Delay of alarm issued by definite time overcurrent element. 6



NO.6—[I_InvOvLd_Sta]



Pickup current of inverse time overcurrent protection. Characteristic of this protection is indefinite time relationship between multiple of load current and corresponding permissive duration which is determined by permissive overload capability of stator provided by the factory.



t



172



K tc I *2



 K sr2



（Equation 7.3-19）



NR ELECTRIC CO., LTD



Chapter7 Settings



Where:



K tc



is heat capacity factor of stator winding;



I * is per unit value of load current referred to rated current of stator; K sr



is heat dissipation factor, 1.0 – 1.05 generally.



Minimum delay for upper limit of this protection shall coordinate with the unrestraint protection. Current setting of lower limit of this protection will coordinate with definite time overload protection mentioned above, namely



I OP. min  K c 0 K rel



Where: 7



KC 0



I gn Kr



（Equation 7.3-20）



is coordination factor, 1.05 in general.



NO.7—[tmin_InvOvLd_Sta]



Delay of upper limit of inverse time overcurrent protection. 8



NO.8—[A_Therm_Sta]



Thermal capacity parameter of stator winding. 9



NO.9—[K_Disspt_Sta]



Heat dissipation factor for inverse time overcurrent. 10 NO.10—[TrpLog_InvOvLd_Sta] Tripping output logic setting of inverse time overcurrent protection. 7.3.7.3 Setting path Settings of stator overload protection are accessible in the following path: Main Menu -> SETTINGS -> PROT SETTINGS -> STA OVLD PROT --> [setting symbol].



7.3.8 Settings of negative sequence overload protection 7.3.8.1 Setting list Table 7.3-8 List of negative sequence overload protection No.



Symbol



Range



Step



Default



1



I_NegOC1_Gen



0.10 – 20.00 A



0.01 A



10



2



t_NegOC1_Gen



0.00 – 10.00 S



0.01 S



1



NR ELECTRIC CO., LTD



173



Chapter7 Settings



3



TrpLog_NegOC1_Gen



0000 - FFFF



1



000F



4



I_NegOC2_Gen



0.10 – 20.00 A



0.01 A



10



5



t_NegOC2_Gen



0.00 – 10.00 S



0.01 S



1



6



TrpLog_NegOC2_Gen



0000 - FFFF



1



000F



7



I_Alm_NegOC_Gen



0.05 – 20.00 A



0.01 A



1.0



8



t_Alm_NegOC_Gen



0.00 – 10.00 S



0.01 S



2



9



I_InvNegOC_Gen



0.05 – 5.00 A



0.01 A



0.5



10



I_Neg_Perm_Gen



0.05 – 5.00 A



0.01 A



0.4



11



tmin_InvNegOC_Gen



0.10 – 10.00 S



0.01 S



1



12



A_Therm_RotBody



0.00 – 100.00



0.01



40



13



TrpLog_InvNegOC_Gen



0000 - FFFF



1



1FFF



7.3.8.2 Explanation of setting 1



NO.1—[I_NegOC1_Gen]



Setting of stage 1 of definite time negative sequence overcurrent protection. Setting of this protection is determined by the threshold under which this protection can release reliably, that threshold value is continuously permissive negative sequence current I 2 . So,



I OP  K rel



I 2  I gn Kr



（Equation 7.3-21）



Where:



I OP is the setting [I_OvLd_Sta]. K rel



is reliability factor, 1.05;



K r is release factor, 0.85 – 0.95; I 2 is per unit value of continuously permissive negative sequence current, I gn



is secondary rated current of generator.



2



NO.2—[t_NegOC1_Gen]



Delay of stage 1 of definite time negative sequence overcurrent protection. Delay of this protection shall be longer than maximum delay of backup protection. Alarm will be issued when it operates. 3



174



NO.3—[TrpLog_NegOC1_Gen]



NR ELECTRIC CO., LTD



Chapter7 Settings



Tripping output logic setting of stage 1 of definite time negative sequence overcurrent protection. 4



NO.4—[I_NegOC2_Gen]



Setting of stage 2 of definite time negative sequence overcurrent protection. The setting method is as same as that of stage 1. 5



NO.5—[t_NegOC2_Gen]



Delay of stage 2 of definite time negative sequence overcurrent protection. Delay of this protection shall be longer than maximum delay of backup protection. This stage can be used to trip breakers. 6



NO.6—[TrpLog_NegOC2_Gen]



Tripping output logic setting of stage 2 of definite time negative sequence overcurrent protection. 7



NO.7—[I_Alm_NegOC_Gen]



Setting of alarm issued by negative sequence overcurrent element. 8



NO.8—[t_Alm_NegOC_Gen]



Delay of alarm issued by negative sequence overcurrent element. 9



NO.9—[I_InvNegOC_Gen]



Pickup current of inverse time negative sequence overcurrent protection. Characteristic of this protection is determined by permissive negative sequence overload capability of rotor surface provided by the manufacturer.



t



I 22*



A  I 22



（Equation 7.3-22）



Where:



A is permissive negative sequence current factor of rotor surface;



I 2* is per unit value of negative sequence current of generator; I 2 is per unit value of permissive continues negative sequence current. Minimum delay for upper limit of this protection shall coordinate with unrestraint protection. 10 NO.10—[I_Neg_Perm_Gen] Permitted continuous currents of inverse time negative sequence overcurrent protection for lasting operation. Current setting of lower limit of this protection shall be the operating current corresponding to delay 1000 s, namely NR ELECTRIC CO., LTD



175



Chapter7 Settings



I OP. min 



A  I 22 1000



（Equation 7.3-23）



This protection is used for Islanding or program tripping. 11 NO.11—[tmin_InvNegOC_Gen] Delay of upper limit of inverse negative sequence overcurrent protection. Minimum delay for upper limit of this protection shall coordinate with unrestraint protection. 12 NO.12—[A_Therm_RotBody] Heat dissipation factor for inverse time negative sequence overcurrent. 13 NO.13—[TrpLog_InvNegOC_Gen] Tripping output logic setting of inverse time overcurrent protection. 7.3.8.3 Setting path Settings of stator negative sequence overcurrent protection are accessible in the following path: Main Menu -> SETTINGS -> PROT SETTINGS -> GEN NEGOC PROT --> [setting symbol].



7.3.9 Settings of Loss-of-Excitation protection 7.3.9.1 Setting list No. 1



X1_LossExc_Gen



Range 0.00 -200.00 Ω



2



X2_LossExc_Gen



0.00 -200.00 Ω



0.01 Ω



20



3



Q_RevQ_LossExc_Gen



0.00 – 50.00 %



0.01 %



10



4



V_RotUV_LossExc_Gen



0.1 – 500.00 V



0.01 V



30



5



V_RotNoLoad_LossExc_Gen



0.1 – 500.00 V



0.01 V



50



6



k_RotUV_LossExc_Gen



0.00 – 10.00 (pu)



0.01 (pu)



2



7



V_UV_LossExc_Gen



0.10 – 100.00 V



0.01 V



85



8



P_OvPwr_LossExc_Gen



0.10 – 100.00 %



0.01 %



50.0



9



t_LossExc1_Gen



0.00 – 10.00 S



0.01 S



0.5



t_LossExc2_Gen



0.00 – 10.00 S



0.01 S



1.0



t_LossExc3_Gen



0.00 – 3000.00 S



0.01 S



3.0



TrpLog_LossExc1_Gen



0000 - FFFF



1



1FFF



TrpLog_LossExc2_Gen



0000 - FFFF



1



1FFF



14



TrpLog_LossExc3_Gen



0000 - FFFF



1



1FFF



15



Logic setting ―1‖ - enable, ―0‖ – disable 0，1 En_Z_LossExc1_Gen



10 11 12 13



Symbol



Step 0.01 Ω



Default 5



1



En_RotUV_LossExc1_Gen



0，1



1



En_P_LossExc1_Gen



0，1



1



18



En_UV_LossExc2_Gen



0，1



1



19



En_Z_LossExc2_Gen



0，1



1



16 17



176



NR ELECTRIC CO., LTD



Chapter7 Settings



20



En_RotUV_LossExc2_Gen



0，1



1



21



En_Z_LossExc3_Gen



0，1



1



22



En_RotUV_LossExc3_Gen



0，1



1



23



En_Alm_LossExc1_Gen



0，1



1



24



Opt_Z_LossExc_Gen



0，1



1



25



En_RevQ_LossExc_Gen



0，1



1



26



Opt_UV_LossExc_Gen



0，1



0



7.3.9.2 Explanation of setting 1



NO.1—[X1_LossExc_Gen]



Impedance setting1 of loss-of-excitation protection. In the following figure,



Xc



jx



Xa



R



Xb



Figure 7.3-1 Impedance circle of loss of excitation protection



For asynchronous impedance cycle, this setting represents for



Xb



Xa



, and the next setting (NO.2) is



. Here



2 X d' U gn  na Xa    2 S gn  nv



2 U gn  na X d' X b  ( X d  ) 2 S gn  nv



（Equation 7.3-24）



（Equation 7.3-25）



Where: ' X d and X d are unsaturated per unit value of transient reactance and synchronous reactance of



generator,



U gn



and



S gn



are rated voltage and rated apparent power of generator;



NR ELECTRIC CO., LTD



177



Chapter7 Settings



na



and



nv



are CT ratio and VT ratio.



For steady state stability limit circle, this setting represents for



Xb



XC



, and the next setting (NO.2) is



, here



Xc  Xs 



2 U gn  na



S gn  nv



（Equation 7.3-26）



U gn  na X' X b  ( X d  d )  2 S gn  nv 2



（Equation 7.3-27）



Where:



Xs



is equivalent reactance on system side (including step-up transformer) connected with the



generator (per unit value, reference capacity is apparent power of the generator). Asynchronous impedance circle and steady state stability limit circle can be selected by logic setting [Impedance Circle Option] (No. 24). For practical projects, impedance between asynchronous impedance circle and steady state stability limit circle can be selected for optimal combination of reliability and speed. 2



NO.2—[X2_LossExc_Gen]



Impedance setting2 of loss-of-excitation protection 3



NO.3—[Q_RevQ_LossExc_Gen]



Reverse power setting of reactive power Reverse reactive power criterion:



Q zd  K rel 



Q jx Pgn



（Equation 7.3-28）



Where:



K rel



is reliability factor, 1 - 1.3;



Q jx



is permissive incoming reactive power to the generator;



Pgn



is rated active power of the generator.



178



NR ELECTRIC CO., LTD



Chapter7 Settings



Reverse reactive power criterion can be selected by logic setting [Enable ReactPowRev Criterion] (NO. 25). 4



NO.4—[V_RotUV_LossExc_Gen]



Low voltage setting of rotor. There are two low voltages setting of rotor, they are a) Excitation undervoltage criterion



U fd .op  K rel  U fd 0



（Equation 7.3-29）



Where:



U fd .op



is this setting.



K rel



is reliability factor, 0.20 – 0.50;



U fd 0



is rated excitation voltage of the generator without load, i.e. NO.5 setting.



b) Variable excitation voltage criterion For a generator connecting with power system, there is a necessary excitation voltage



U fd 0



for



keeping steady state stability. Variable excitation voltage criterion is



U fd.op  K xs  U fd 0 



P  Pt Sn



K xs  K rel  ( X d  X S )



（Equation 7.3-30）



（Equation 7.3-31）



Where:



K xs



is rotor voltage criterion coefficient, i.e. NO. 6 setting.



K rel



is reliability factor, 0.70 – 0.85;



Xd



and



Xs



are per unit value of synchronous reactance of generator and equivalent reactance of



system connecting with the generator (referred to rated capacity of the generator);



P is current active power of the generator; Pt is the salient pole power of generator, i.e. NO. 7 setting.



NR ELECTRIC CO., LTD



179



Chapter7 Settings



U fd 0 5



is rated excitation voltage of generator without load; NO.5—[V_RotNoLoad_LossExc_Gen]



Rated excitation voltage of the generator without load. 6



NO.6—[k_RotUV_LossExc_Gen]



Restrained coefficient of low voltage criterion of rotor. 7



NO.7—[V_UV_LossExc_Gen]



Low voltage setting for busbar undervoltage criterion. This criterion is used mainly to prevent voltage collapse due to loss of excitation of generator for a system without enough spare reactive power. Voltage on bus of system side is adopted for this criterion. Under voltage criterion for three phase simultaneously:



U op.3 ph  K rel  U h. min



（Equation 7.3-32）



Where:



K rel



is reliability factor, 0.85 – 0.90;



U h. min



is minimum normal operation voltage of HV side of the system.



This criterion can also be configured as 0.85 – 0.90 times of terminal voltage of generator. 8



NO.8—[P_OvPwr_LossExc_Gen]



Power setting for reducing power output. This criterion is configured as 40% - 50% of rated capacity of the generator. 9



NO.9—[t_LossExc1_Gen]



Delay of loss-of-excitation protection stage 1 10 NO.10—[t_LossExc2_Gen] Delay of loss-of-excitation protection stage 2 11 NO.11—[t_LossExc3_Gen] Delay of loss-of-excitation protection stage 3 12 NO.12—[TrpLog_LossExc1_Gen] Tripping output logic setting of loss-of-excitation protection stage1 13 NO.13—[TrpLog_LossExc2_Gen]



180



NR ELECTRIC CO., LTD



Chapter7 Settings



Tripping output logic setting of loss-of-excitation protection stage2 14 NO.14—[TrpLog_LossExc3_Gen] Tripping output logic setting of loss-of-excitation protection stage3 15 NO.15—[En_Z_LossExc1_Gen] Enable impedance criterion in loss-of-excitation protection stage1 16 NO.16—[En_RotUV_LossExc1_Gen] Enable the criterion of rotor voltage in loss-of-excitation protection stage1 17 NO.17—[En_P_LossExc1_Gen] Enable power-reducing criterion in loss-of-excitation protection stage1 18 NO.18—[En_UV_LossExc2_Gen] Enable the low voltage criterion of busbar or generator terminal in loss-of-excitation protection stage2 19 NO.19—[En_Z_LossExc2_Gen] Enable impedance criterion in loss-of-excitation protection stage2 20 NO.20—[En_RotUV_LossExc2_Gen] Enable the criterion of rotor voltage in loss-of-excitation protection stage2 21 NO.21—[En_Z_LossExc3_Gen] Enable impedance criterion in loss-of-excitation protection stage3. 22 NO.22—[En_RotUV_LossExc3_Gen] Enable the criterion of rotor voltage in loss-of-excitation protection stage3 23 NO.23—[En_Alm_LossExc1_Gen] Enable alarm function of loss-of-excitation protection stage1 24 NO.24—[Opt_Z_LossExc_Gen] Impedance circle option. ―0‖, choose steady state stability circle. ―1‖, choose asynchronous impedance cycle. 25 NO.25—[En_RevQ_LossExc_Gen] Enable reverse power criterion 26 NO.26—[Opt_UV_LossExc_Gen] Enable low voltage criterion.



NR ELECTRIC CO., LTD



181



Chapter7 Settings



―0‖, choose bus voltage. ―1‖, choose generator terminal voltage. Note: Following criterion are recommended for various stages of this protection: Criterion Stator side impedance Under voltage criterion of system Rotor voltage Reducing power output Delay ( s )



Stage 1 √ √ √ 0.0 – 10.0



Stage 2 √ √ √



Stage 3 √



0.0 – 10.0



Long delay



√



7.3.9.3 Setting path Settings of generator loss-of-excitation protection are accessible in the following path: Main Menu -> SETTINGS -> PROT SETTINGS -> GEN LOSSEXC PROT --> [setting symbol].



7.3.10 Settings of out-of-step protection 7.3.10.1 Setting list Table 7.3-9 List of out-of-step protection No.



Symbol



1



Za_OOS_Gen



Range 0.00 –200.00 Ω



Step 0.01 Ω



Default



2



Zb_OOS_Gen



0.00 –200.00 Ω



0.01 Ω



5



3



Zc_OOS_Gen



0.00 –200.00 Ω



0.01 Ω



5



4



φ_Reach_OOS_Gen



0 – 90.00 °



0.1 °



85



5



φ_Inner_OOS_Gen



0 –150.00 °



0.1 °



120



6



n_Slip_Ext_OOS_Gen



0-10000



1



5



7



n_Slip_Int_OOS_Gen



0-10000



1



2



8



Ibrk_GCB



0.10 – 100.00 A



0.01 A



10



9



TrpLog_OOS_Gen



0000 - FFFF



0.01



1FFF



10



Logic setting ―1‖ - enable, ―0‖ – disable 0，1 En_Alm_Ext_OOS_Gen



11



En_Trp_Ext_OOS_Gen



0，1



1



12



En_Alm_Int_OOS_Gen



0，1



1



13



En_Trp_Int_OOS_Gen



0，1



1



10



1



7.3.10.2 Explanation of setting Explanation of the settings Out-of-step protection operates only when out-of-step occurs in the power system. Then, based on the situation at that time, the dispatching center will adopt islanding, generator shutting, 182



NR ELECTRIC CO., LTD



Chapter7 Settings



restraint or any other necessary measures. Only if the center of oscillation is situated within the generator or near the generator, or the oscillation lasts too long, and the phase difference of electro-motive force between the two sides of the breaker is less than 90°, this protection will then trip. Characteristic of this protection comprises three parts: lens part ②, boundary part ① and reactance line part ③. See the following figure.



jx Za



U D



Zc



OL



1







3



IL







IR



0 Zb L R



OR



R



1



2



Figure 7.3-2 Impedance of out-of-step protection 1



NO.1—[Za_OOS_Gen]



Impedance setting A of out-of-step protection. Refer to Figure 7.3-2, this setting can be set by means of the following formula.



Za  ( X S  X C ) 



2 U gn  na



S gn  nv



（Equation 7.3-33）



Where:



X C is per unit value of equivalent reactance of transformer connecting to the generator; X S is equivalent reactance of power system network; U gn



and



S gn



nv



are rated voltage and rated apparent power of generator;



na



and



2



NO.2—[Zb_OOS_Gen]



are CT ratio and VT ratio.



Impedance setting B of out-of-step protection. Refer to figure 7.3.2, this setting can be set by means of the following formula. NR ELECTRIC CO., LTD



183



Chapter7 Settings



Zb   X  ' d



2 U gn  na



S gn  nv



（Equation 7.3-34）



Where:



X d' is transient reactance of generator; 3



NO.3—[Zc_OOS_Gen]



Impedance setting C of out-of-step protection. Reactance line is the dividing line of oscillation center. Refer to Figure 7.3-2, this setting can be set by means of the following formula. In practice, 0.9 times of transformer impedance is recommended.



Z c  0.9  X c  4



2 U gn  na



S gn  nv



（Equation 7.3-35）



NO.4—[φ_Reach_OOS_Gen]



Reach angle of system impedance.



 = 80°- 85°according to the real angle of system. 5



NO.5—[φ_Inner_OOS_Gen]



Internal angle of lens characteristic



  180   2 arctan



Zr 



2Z r Z a  Zb



1 RL. min 1.3



Where 6



 . The following formula is for reference,



RL. min



（Equation 7.3-36）



is minimum load impedance of generator.



NO.6—[n_Slip_Ext_OOS_Gen]



Pole sliding number setting for external fault of generator. When the oscillation center is situated outside the protected section, then the times of pole sliding shall be set as 2 – 15 for alarm and more than 15 for tripping. 7



NO.7—[n_Slip_Int_OOS_Gen]



Pole sliding number setting for internal fault of generator. When the oscillation center is situated within the protected section, the time of pole sliding shall be set as 1-2 in general. 8



184



NO.8—[Ibrk_GCB]



NR ELECTRIC CO., LTD



Chapter7 Settings



Tolerating current of breaker in tripping. This is an auxiliary criterion and is determined by interruption capacity of the circuit breaker. 9



NO.9—[TrpLog_OOS_Gen]



Tripping output logic setting of out-of-step protection. 10 NO.10—[En_Alm_Ext_OOS_Gen] Enable alarm in out-of-step case outside the generator. 11 NO.11—[En_Trp_Ext_OOS_Gen] Enable tripping in out-of-step case outside the generator. 12 NO.12—[En_Alm_Int_OOS_Gen] Enable alarm in out-of-step case inside the generator. 13 NO.13—[En_Trp_Int_OOS_Gen] Enable tripping in out-of-step case inside the generator. 7.3.10.3 Setting path Settings of generator out-of-step protection are accessible in the following path: Main Menu -> SETTINGS -> PROT SETTINGS -> GEN OOS PROT --> [setting symbol].



7.3.11 Settings of voltage protection 7.3.11.1 Setting list Table 7.3-10 List of voltage protection settings No.



Symbol



Range



Step



Default



1



V_OV1_Gen



0.10 –200.00 V



0.01V



150



2



t_OV1_Gen



0.00 – 10.00 S



0.01S



0.3



3



TrpLog_OV1_Gen



0000 – FFFF



1



1FFF



4



V_OV2_Gen



0.10 –200.00 V



0.01V



130



5



t_OV2_Gen



0.00 – 10.00 S



0.01S



0.5



6



TrpLog_OV2_Gen



0000 – FFFF



1



1FFF



7



V_UV_Gen



0.10 –100.00 V



0.01V



80



8



t_UV_Gen



0.00 – 10.00 S



0.01S



1.5



9



TrpLog_UV_Gen



0000 – FFFF



1



1FFF



7.3.11.2 Explanation of setting 1



NO.1—[V_OV1_Gen]



Voltage setting of overvoltage protection stage 1. Setting of overvoltage protection of stator shall base on permissive overvoltage capability provided



NR ELECTRIC CO., LTD



185



Chapter7 Settings



by the factory or insulation condition of the stator. For turbo-generator with capacity more than 200 MW,



U op  1.3U gn



（Equation 7.3-37）



Where:



U gn



is the secondary rated phase-to-phase voltage.



This is used for islanding and excitation shutting with delay 0.5 s. For hydro-generator,



U op  1.5U gn



（Equation 7.3-38）



This is used for islanding and excitation shutting with delay 0.5 s. For hydro-generator with SCR excitation,



U op  1.3U gn



（Equation 7.3-39）



This is used for islanding and excitation shutting with delay 0.3 s. 2



NO.2—[t_OV1_Gen]



Delay of overvoltage protection stage1. 3



NO.3—[TrpLog_OV1_Gen]



Tripping output logic setting of overvoltage protection stage1. 4



NO.4—[V_OV2_Gen]



Voltage setting of overvoltage protection stage 2. 5



NO.5—[t_OV2_Gen]



Delay of overvoltage protection stage2. 6



NO.6—[TrpLog_OV2_Gen]



Tripping output logic setting of overvoltage protection stage2. 7



NO.7—[V_UV_Gen]



Voltage setting of under voltage protection 8



NO.8—[t_UV_Gen]



Delay of under voltage protection 9



186



NO.9—[TrpLog_UV_Gen]



NR ELECTRIC CO., LTD



Chapter7 Settings



Tripping output logic setting of under voltage protection. 7.3.11.3 Setting path Settings of generator voltage protection are accessible in the following path: Main Menu -> SETTINGS -> PROT SETTINGS -> GEN VOLT PROT --> [setting symbol].



7.3.12 Settings of overexcitation protection of generator 7.3.12.1 Setting list Table 7.3-11 List of over excitation protection settings of generator No.



Symbol



Range



Step



Default



1



k_OvExc1_Gen



1.00 – 2.00



0.01



1.4



2



t_OvExc1_Gen



0– 25.0 S



0.1 S



1



3



TrpLog_OvExc1_Gen



0000 - FFFF



1



000F



4



k_OvExc2_Gen



1.00 – 2.00



0.01



1.2



5



t_OvExc2_Gen



0.1 – 3000.0 S



0.1 S



20



6



TrpLog_OvExc2_Gen



0000 - FFFF



1



0F01



7



k_Alm_OvExc_Gen



1.00 – 2.00



0.01



1.1



8



t_Alm_OvExc_Gen



0 – 25.00 S



0.1 S



10



9



k0_InvOvExc_Gen



1.00 – 2.00



0.01



1.5



10



t0_InvOvExc_Gen



1.0 – 3000.0 S



0.1 S



1



11



k1_InvOvExc_Gen



1.00 – 2.00



0.01



1.45



12



t1_InvOvExc_Gen



1.0 – 3000.0 S



0.1 S



2



13



k2_InvOvExc_Gen



1.00 – 2.00



0.01



1.4



14



t2_InvOvExc_Gen



1.0 – 3000.0 S



0.1 S



5



15



k3_InvOvExc_Gen



1.00 – 2.00



0.01



1.3



16



t3_InvOvExc_Gen



1.0 – 3000.0 S



0.1 S



15



17



k4_InvOvExc_Gen



1.00 – 2.00



0.01



1.25



18



t4_InvOvExc_Gen



1.0 – 3000.0 S



0.1 S



30



19



k5_InvOvExc_Gen



1.00 – 2.00



0.01



1.2



20



t5_InvOvExc_Gen



1.0 – 3000.0 S



0.1 S



100



21



k6_InvOvExc_Gen



1.00 – 2.00



0.01



1.15



22



t6_InvOvExc_Gen



1.0 – 3000.0 S



0.1 S



300



23



k7_InvOvExc_Gen



1.00 – 2.00



0.01



1.1



24



t7_InvOvExc_Gen



1.0 – 3000.0 S



0.1 S



1000



25



TrpLog_InvOvExc_Gen



0000 - FFFF



1



1FFF



7.3.12.2 Explanation of setting 1



NO.1—[k_OvExc1_Gen]



Setting of stage 1 of definite time over excitation protection.



NR ELECTRIC CO., LTD



187



Chapter7 Settings



U U gn B N    U  / f  1.3 or data provided by the factory f Bn f gn 2



NO.2—[t_OvExc1_Gen]



Delay of stage 1 of definite time over excitation protection. 3



NO.3—[TrpLog_OvExc1_Gen]



Tripping output logic setting of stage 1 of definite time over excitation protection. The function of this protection is used for islanding, excitation shutting or programming, excitation reducing etc. 4



NO.4—[k_OvExc2_Gen]



Setting of stage 2 of definite time over excitation protection. 5



NO.5—[t_OvExc2_Gen]



Delay of stage 2 of definite time over excitation protection . 6



NO.6—[TrpLog_OvExc2_Gen]



Tripping output logic setting of stage 2 of definite time over excitation protection. 7



NO.7—[k_Alm_OvExc_Gen]



Setting of over excitation alarm. Setting of alarm shall be lower than that of over excitation protection. 1.1 is recommended. 8



NO.8—[t_Alm_OvExc_Gen]



Delay of over excitation alarm. 9



NO.9—[k0_InvOvExc_Gen]



Upper limit of inverse time over excitation protection—n0 10 NO.10—[t0_InvOvExc_Gen] Delay of upper limit of inverse time over excitation protection. 11 NO.11—[k1_InvOvExc_Gen] Inverse time over excitation factor1—n1. Setting range of various inverse times over excitation coefficient is 1.0 – 2.0. However setting of upper limit (NO.9) of over excitation factor n0 shall be higher than that of over excitation factor1 n1, which of factor1 n1 shall be higher than that of factor2 n2, etc. Finally, setting of over excitation factor6 n6 (NO.21) shall be higher than that of the lower limit. 12 NO.12—[t1_InvOvExc_Gen] Delay at the point n1 on inverse time over excitation curve—t1 The range of delay of various inverse time over excitation protection stage is 1s to 3000s, ie.,0--50 188



NR ELECTRIC CO., LTD



Chapter7 Settings



min. Delay of upper limit (NO.10) of over excitation factor shall be shorter than that of over excitation factor1 that the factor1 shall be shorter than that of factor2, etc.. Finally, delay of over excitation factor6 (NO.22) shall be shorter than that of lower limit (NO.24). 13 NO.13—[k2_InvOvExc_Gen] Inverse time over excitation factor n2. 14 NO.14—[t2_InvOvExc_Gen] Delay at the point n2 on inverse time over excitation curve—t2 15 NO.15—[k3_InvOvExc_Gen] Inverse time over excitation Ratio n3. 16 NO.16—[t3_InvOvExc_Gen] Delay at the point n3 on inverse time over excitation curve—t3. 17 NO.17—[k4_InvOvExc_Gen] Inverse time over excitation Ratio n4. 18 NO.18—[t4_InvOvExc_Gen] Delay at the point n4 on inverse time over excitation curve—t4. 19 NO.19—[k5_InvOvExc_Gen] Inverse time over excitation Ratio n5. 20 NO.20—[t5_InvOvExc_Gen] Delay at the point n5 on inverse time over excitation curve—t5. 21 NO.21—[k6_InvOvExc_Gen] Inverse time over excitation Ratio n6. 22 NO.22—[t6_InvOvExc_Gen] Delay at the point n6 on inverse time over excitation curve—t6. 23 NO.23—[k7_InvOvExc_Gen] Inverse time over excitation Ratio n7. 24 NO.24—[t7_InvOvExc_Gen] Delay at the point n7 on inverse time over excitation curve—t7. 25 NO.25—[TrpLog_InvOvExc_Gen] Tripping output logic setting of inverse time over excitation protection.



NR ELECTRIC CO., LTD



189



Chapter7 Settings



7.3.12.3 Setting path Settings of generator overexcitation protection are accessible in the following path: Main Menu -> SETTINGS -> PROT SETTINGS -> GEN OVEXC PROT --> [setting symbol]



7.3.13 Settings of power protection of generator 7.3.13.1 Setting list Table 7.3-12 List of power protection settings of generator No.



Symbol



Range



Step



Default



1



P_RevP_Gen



0.50 – 10.00 %



0.01%



2



2



t_Alm_RevP_Gen



0.10 – 25.00 S



0.1 S



10



3



t_Trp_RevP_Gen



0.10 – 3000.0 S



0.1 S



10



4



TrpLog_RevP_Gen



0000 - FFFF



1



1FFF



5



P_SeqTrpRevP_Gen



0.50 – 10.00 %



0.01 %



2



6



t_SeqTrpRevP_Gen



0.01 – 10.00 S



0.01 S



1



7



TrpLog_SeqTrpRevP_Gen



0000 - FFFF



1



1FFF



7.3.13.2 Explanation of setting 1



NO.1—[P_RevP_Gen]



Power setting of reverse power protection.



Pop  K rel ( P1  P2 )



（Equation 7.3-40）



Where:



K rel



is reliability coefficient, 0.5 – 0.8 generally;



P1 is minimum loss of turbine during reverse power operation, 2% - 4% of rated power generally; P2 is minimum loss of generator during reverse power operation, P2  (1   ) Pgn generally,  is efficiency factor of generator, 98.6% - 98.7%;



Pgn



is rated power of generator.



Pop



is set as 1% - 2% of rated active power generally, and 1% is recommended.



2



NO.2—[t_Alm_RevP_Gen]



Delay of reverse power alarm. For reverse power protection without steam valve contact blocking, delay 15 s for alarm. 190



NR ELECTRIC CO., LTD



Chapter7 Settings



3



NO.3—[t_Trp_RevP_Gen]



Delay of reverse power protection. For reverse power protection without steam valve contact blocking, according to permissive operation time of reverse power, delay 1 min – 3 min is set for islanding in general. For program reverse power protection with steam valve contact blocking, delay 0.5 s – 1.00 s is set for islanding. 4



NO.4—[TrpLog_RevP_Gen]



Tripping output logic setting of reverse power protection. 5



NO.5—[P_SeqTrpRevP_Gen]



Power setting of sequent-tripping reverse power protection. 6



NO.6—[t_SeqTrpRevP_Gen]



Delay of sequent-tripping reverse power protection. For sequent-tripping reverse power protection with steam valve contact blocking, delay 0.5 s – 1.00 s for islanding. 7



NO.7—[TrpLog_SeqTrpRevP_Gen]



Tripping output logic setting of sequent-tripping reverse power protection. 7.3.13.3 Setting path Settings of generator power protection are accessible in the following path: Main Menu -> SETTINGS -> PROT SETTINGS -> GEN PWR PROT --> [setting symbol].



7.3.14 Settings of underfrequency and overfrequency protection 7.3.14.1 Setting list Table 7.3-13 List of frequency protection settings No. 1



f_UF1_Gen



Range 45.00 – 51.00 Hz



2



t_Accu_UF1_Gen



0.00 –300.00 min



0.01min



10



3



f_UF2_Gen



45.00 – 51.00 Hz



0.01 Hz



48



4



t_UF2_Gen



0.00 –300.00 min



0.01min



10



5



f_UF3_Gen



45.00 – 51.00 Hz



0.01 Hz



47.5



6



t_UF3_Gen



0.00 –100.00 S



0.01 S



10



7



TrpLog_UF_Gen



0000 - FFFF



1



1FFF



f_OF1_Gen



50.00 – 60.00 Hz



0.01 Hz



51.5



t_OF1_Gen



0.00 –100.00 min



0.01min



10



f_OF2_Gen



50.00 – 60.00 Hz



0.01 Hz



55



t_OF2_Gen



0.00 –100.00 S



0.01 S



10



8 9 10 11



Symbol



NR ELECTRIC CO., LTD



Step 0.01 Hz



Default 48.5



191



Chapter7 Settings



0000 - FFFF



1



12



TrpLog_OF_Gen



13



Logic setting ―1‖ - enable, ―0‖ – disable 0，1 En_Alm_UF1_Gen 0，1 En_Trp_UF1_Gen



14



1FFF 1 1



En_Alm_UF2_Gen



0，1



1



En_Trp_UF2_Gen



0，1



1



En_Alm_UF3_Gen



0，1



1



En_Trp_UF3_Gen



0，1



1



En_Alm_OF1_Gen



0，1



1



20



En_Trp_OF1_Gen



0，1



1



21



En_Alm_OF2_Gen



0，1



1



22



En_Trp_OF2_Gen



0，1



1



15 16 17 18 19



7.3.14.2 Explanation of setting 1



NO.1—[f_UF1_Gen]



Frequency setting of under frequency protection stage1. Permissive range of frequency during operation for large turbo-generator with capacity more than 300 MW is 48.5 Hz – 50.5 Hz. Recommended permissive operation time of abnormal frequency for large generator is as follows.



Table 7.3-14 Operating time under differential frequency Freq.



Permissive operating time



Freq.



Permissive operating time



Hz



accumulated, min



once, s



Hz



accumulated, min



once, s



51.5



30



30



48.0



300



300



51.0



180



180



47.5



60



60



48.5-50.5



continuous



47.0



10



10



Three stages of under frequency protection are provided in which the function of accumulated operating time is equipped for stage 1(NO.2 setting). Two zones of over frequency protection are provided, in which no function of accumulated operating time is equipped. Each zone can be used for alarm or tripping by configuration of logic setting. 2



NO.2—[t_UF1_Gen]



The sum of delay setting of under frequency protection stage1. 3



NO.3—[f_UF2_Gen]



Frequency setting of under frequency protection stage2. 192



NR ELECTRIC CO., LTD



Chapter7 Settings



4



NO.4-- [t_UF2_Gen]



Delay of under frequency protection stage2. 5



NO.5—[f_UF3_Gen]



Frequency setting of under frequency protection stage3. 6



NO.6—[t_UF3_Gen]



Delay of under frequency protection stage3. 7



NO.7—[TrpLog_UF_Gen]



Tripping output logic setting of under frequency protection. 8



NO.8—[f_OF1_Gen]



Frequency setting of over frequency protection stage1. 9



NO.9—[t_OF1_Gen]



Delay of over frequency protection stage1. 10 NO.10—[f_OF2_Gen] Frequency setting of over frequency protection stage2. 11 NO.11—[t_OF2_Gen] Delay of over frequency protection stage2. 12 NO.12—[TrpLog_OF_Gen] Tripping output logic setting of over frequency protection. 13 NO.13—[En_Alm_UF1_Gen] Enable alarm function of under frequency protection stage1. 14 NO.14—[En_Trp_UF1_Gen] Enable tripping function of under frequency protection stage1. 15 NO.15—[En_Alm_UF2_Gen] Enable alarm function of under frequency protection stage2. 16 NO.16—[En_Trp_UF2_Gen] Enable tripping function of under frequency protection stage2. 17 NO.17—[En_Alm_UF3_Gen] Enable alarm function of under frequency protection stage3. 18 NO.18—[En_Trp_UF3_Gen] Enable tripping function of under frequency protection stage3. NR ELECTRIC CO., LTD



193



Chapter7 Settings



19 NO.19—[En_Alm_OF1_Gen] Enable alarm function of over frequency protection stage1. 20 NO.20—[En_Trp_OF1_Gen] Enable tripping function of over frequency protection stage1. 21 NO.21—[En_Alm_OF2_Gen] Enable alarm function of over frequency protection stage2. 22 NO.22—[En_Trp_OF2_Gen] Enable tripping function of over frequency protection stage2. 7.3.14.3 Setting path Settings of generator frequency protection are accessible in the following path: Main Menu -> SETTINGS -> PROT SETTINGS -> GEN FREQ PROT --> [setting symbol].



7.3.15 Settings of startup and shutdown protection of generator 7.3.15.1 Setting list Table 7.3-15 List of startup and shutdown protection settings of generator No.



Symbol



Range



Step



Default



1



f_UF_Ctrl_StShut_Gen



40.0 – 50.0Hz



0.01 Hz



45



2



I_GenDiff_StShut_Gen



0.1 - 14.0 (Ie)



0.01 (Ie)



1



3



TrpLog_Diff_StShut_Gen



0000 - FFFF



1



1FFF



4



I_UFOC_StShut_Gen



0.10 - 100.00 A



0.01 A



20



5



t_UFOC_StShut_Gen



0.00 – 10.00 S



0.01 S



10



6



TrpLog_OC_StShut_Gen



0000 - FFFF



1



1FFF



7



V_StaROV_StShut_Gen



5 – 25.0 V



0.01 V



10



8



t_StaROV_StShut_Gen



0 – 10.0 S



0.01 S



10



9



TrpLog_StaROV_StShut_Gen



0000 - FFFF



1



1FFF



10



Logic setting ―1‖ - enable, ―0‖ – disable 0，1 En_GenDiff_StShut_Gen



1



11



En_UFOC_StShut_Gen



0，1



12



En_ROV_StShut_Gen



0，1



1



13



En_UF_Ctrl_StShut_Gen



0，1



1



1



7.3.15.2 Explanation of the settings 1



NO.1—[f_UF_Ctrl_StShut_Gen]



Frequency setting for blocking startup and shutdown protection of generator. Startup and shutdown protection is used for earth fault and phase-to-phase fault of stator during low speed operation of the generator. Its algorithm is insensitive to variation of frequency. 194



NR ELECTRIC CO., LTD



Chapter7 Settings



This protection is auxiliary protection of generator during low frequency operation. Blocking setting of this protection is 0.8 – 0.9 times of rated frequency. 2



NO.2—[I_GenDiff_StShut_Gen]



Differential current setting for the differential protection of generator in startup and shutdown condition. Setting of this protection shall be higher than unbalanced differential current in full load and rated frequency condition,



I op  K rel I unb



（Equation 7.3-41）



Where:



K rel



I unb 3



is reliability factor, 1.30 – 1.50 generally;



is the unbalance differential current in full load and rated frequency condition. NO.3—[TrpLog_Diff_StShut_Gen]



Tripping output logic setting of low frequency differential protection of generator in startup and shutdown condition. 4



NO.4—[I_UFOC_StShut_Gen]



Current setting of low frequency overcurrent protection. 5



NO.5—[t_UFOC_StShut_Gen]



Current setting of low frequency overcurrent protection in startup and shutdown condition. 6



NO.6—[TrpLog_Diff_StShut_Gen]



Tripping output logic setting of low frequency overcurrent protection. 7



NO.7—[V_StaROV_StShut_Gen]



Zero sequence voltage setting of stator earth fault protection in startup and shutdown condition. For earth fault, zero sequence voltage derived from neutral point is adopted as criterion with setting 10 V in general and delay not shorter than that of fundamental zero sequence voltage earth fault protection for stator in normal condition. 8



NO.8—[t_StaROV_StShut_Gen]



Delay of stator earth fault protection in startup and shutdown condition. 9



NO.9—[t_StaROV_StShut_Gen]



Tripping output logic setting of stator earth fault protection in startup and shutdown condition. 10 NO.10—[En_GenDiff_StShut_Gen] Enable differential current protective element of generator. NR ELECTRIC CO., LTD



195



Chapter7 Settings



11 NO.11—[En_UFOC_StShut_Gen] Enable underfrequency overcurrent protective element of generator. 12 NO.12—[En_ROV_StShut_Gen] Enable low frequency zero sequence voltage protective element of stator. 13 NO.13—[En_UF_Ctrl_StShut_Gen] Enable low frequency element as blocking criterion in startup&shutup protection logic of generator. 7.3.15.3 Setting path Settings of generator startup and shutdown protection are accessible in the following path: Main Menu -> SETTINGS -> PROT SETTINGS -> GEN STSHUT PROT --> [setting symbol].



7.3.16 Settings of accidental energization protection of generator 7.3.16.1 Setting list Table 7.3-16 List of accidental energaization protection settings of generator No.



Symbol



Range



Step



Default



1



f_UF_AccEnerg_Gen



40 – 50.00 Hz



0.01 Hz



45



2



I_OC_AccEnerg_Gen



0.10 – 50.00 A



0.01 A



3



3



t_AccEnerg_Gen



0.0 – 1.00 S



0.01 A



0.1



4



TrpLog_AccEnerg_Gen



0000 – FFFF



0.01 A



1FFF



5



I_NegOC_Flash_GCB



0.1 – 20.0 A



0.01 A



3



6



t_Flash11_GCB



0.0 – 10.0 S



0.01 A



3



7



TrpLog_Flash11_GCB



0000 – FFFF



0.01 A



1FFF



8



t_Flash12_GCB



0.1 – 10.0 S



0.01 A



3



9



TrpLog_Flash12_GCB



0000 – FFFF



0.01 A



1FFF



10



Logic setting ―1‖ - enable, ―0‖ – disable 0，1 En_UF_Ctrl_AccEnerg_Gen



11



En_CB_Ctrl_AccEnerg_Gen



1



0，1



1



7.3.16.2 Explanation of setting 1



NO.1—[f_UF_AccEnerg_Gen]



Frequency setting for blocking accident energization protection of generator. Frequency blocking setting shall be 80% - 90% of the rated frequency, i.e., 40 Hz – 45 Hz. 2



NO.2—[I_OC_AccEnerg_Gen]



Current setting of accident energization overcurrent protection. Current setting shall be 50% of minimum accidental closing current (generator terminal side) during process of generator starting up but having not been excited. If accidental closing current of 196



NR ELECTRIC CO., LTD



Chapter7 Settings



circuit breaker on auxiliary transformer side shall be taken into account, current setting shall base on minimum accidental closing current during this condition. The current used for this setting is derived from the CT at the terminal of generator. In general, this setting shall be in excess of 1.3 times of the rated current of generator. 3



NO.3—[t_AccEnerg_Gen]



Delay of accident energization overcurrent protection. 4



NO.4—[TrpLog_AccEnerg_Gen]



Tripping output logic setting of accident energization overcurrent protection. 5



NO.5—[I_NegOC_Flash_GCB]



Negative sequence current setting of breaker flashover protection. This setting shall be higher than the possible unbalanced current during normal operation. It must be set according to the secondary current of the CT at the terminal of the generator. 6



NO.6—[t_Flash11_GCB]



Delay 1 of breaker flashover protection. This setting shall be longer than operation time of circuit breaker. 7



NO.7—[TrpLog_Flash11_GCB]



Tripping output logic setting stage 1 of breaker flashover protection. If impulse current may be higher than capacity of circuit breaker during asynchronous closing, the protection shall shut off the excitation firstly. If current passing through circuit breaker is lower than permissive value, the protection can trip the circuit breaker on outlet. Permissive tripping current of circuit breaker shall be configured as that provided by factory. 8



NO.8—[t_Flash12_GCB]



Delay 2 of breaker flashover protection. 9



NO.9—[TrpLog_Flash12_GCB]



Tripping output logic setting stage 2 of breaker flashover protection. 10 NO.10—[En_UF_Ctrl_AccEnerg_Gen] Enable blocking function in under frequency condition. 11 NO.11—[En_CB_Ctrl_AccEnerg_Gen] Enable breaker position auxiliary contact blocking function. If asynchronous unwanted closing is considered, breaker position contact blocking shall be selected.



NR ELECTRIC CO., LTD



197



Chapter7 Settings



7.3.16.3 Setting path Settings of generator accidental energization protection are accessible in the following path: Main Menu -> SETTINGS -> PROT SETTINGS -> GEN ACCENERG PROT --> [setting symbol].



7.3.17 Settings of differential protection of excitation transformer or exciter 7.3.17.1 Setting list Table 7.3-17 List of differential protection settings of excitation transformer or exciter No.



Symbol



Range



Step



Default



1



I_Pkp_PcntDiff_Exc



0.10 –1.50 (Ie)



0.01 (Ie)



0.3



2



I_InstDiff_Exc



2.0 – 14.0 (Ie)



0.01 (Ie)



6



3



Slope1_PcntDiff_Exc



0 – 0.50



0.01



0.1



4



Slope2_PcntDiff_Exc



0.50 – 0.80



0.01



0.7



5



k_Harm_PcntDiff_Exc



0.10 – 0.35



0.01



0.15



6



TrpLog_Diff_Exc



0000 – FFFF



1



1FFF



Logic setting ―1‖ - enable, ―0‖ – disable 0，1



7



En_InstDiff_Exc



1



8



En_PcntDiff_Exc



0，1



1



9



Opt_Inrush_Ident_Exc



0，1



1



10



Opt_CTS_Blk_PcntDiff_Exc



0，1



1



7.3.17.2 Explanation of setting 1



NO.1—[I_Pkp_PcntDiff_Exc]



Setting of pickup value of percentage differential current of excitation transformer or exciter. In practice, for excitation transformer, the characteristics of CT on two sides may differ significantly and the unbalanced differential current may be larger than that of the main transformer. So for pickup setting, 0.5 Ie is recommended. 2



NO.2—[I_InstDiff_Exc]



Setting of unrestrained instantaneous differential protection. 3



NO.3—[Slope1_PcntDiff_Exc]



Restraint coefficient of the first slope of the differential characteristic curve. 4



NO.4—[Slope2_PcntDiff_Exc]



Maximum value of restraint coefficient of the differential characteristic curve. 5



NO.5—[k_Harm_PcntDiff_Exc]



Restraint coefficient of second harmonics.



198



NR ELECTRIC CO., LTD



Chapter7 Settings



6



NO.6—[TrpLog_Diff_Exc]



Tripping output logic setting of differential protection of excitation transformer of exciter. 7



NO.7—[En_InstDiff_Exc]



Enable unrestrained instantaneous differential protection of excitation transformer or exciter. 8



NO.8—[En_PcntDiff_Exc]



Enable percentage differential protection of excitation transformer or exciter. 9



NO.9—[Opt_Inrush_Ident_Exc]



Inrush current blocking mode. Select criterion of Inrush current detection. ―0‖, discrimination by harmonics; ―1‖, waveform distortion criterion is used. 10 NO.10—[Opt_CTS_Blk_PcntDiff_Exc] Enable differential protection blocked by CT circuit failure. Setting ―0‖:



Differential protection is not blocked by CT circuit failure.



Setting ―1‖:



Differential protection is blocked by CT circuit failure



7.3.17.3 Setting path Settings of excitation differential protection are accessible in the following path: Main Menu -> SETTINGS -> PROT SETTINGS -> EXC DIFF PROT --> [setting symbol].



7.3.18 Settings of backup protection of excitation transformer or exciter 7.3.18.1 Setting list Table 7.3-18 List of backup protection settings of excitation transformer or exciter No. 1



I_OC1_Exc



Range 0.10 – 100.00 A



2



t_OC1_Exc



0.00 – 10.00 S



3



TrpLog_OC1_Exc



0000 – FFFF



I_OC2_Exc



0.10 – 100.00 A



0.01 A



20



t_OC2_Exc



0.00 – 25.00 S



0.01 S



1.5



TrpLog_OC2_Exc



0000 – FFFF



1



0081



4 5 6



Symbol



Step 0.01 A



Default



0.01 S



1



1



0081



20



7.3.18.2 Explanation of setting 1



NO.1—[I_OC1_Exc]



Setting of definite time overcurrent protection stage1. 2



NO.2—[t_OC1_Exc]



NR ELECTRIC CO., LTD



199



Chapter7 Settings



Delay of definite time overcurrent protection stage1. 3



NO.3—[TrpLog_OC1_Exc]



Tripping output logic setting of definite time overcurrent protection. 4



NO.4—[I_OC2_Exc]



Setting of definitive time overcurrent protection stage2. 5



NO.5—[t_OC2_Exc]



Delay of definite time overcurrent protection stage2. 6



NO.6—[TrpLog_OC2_Exc]



Tripping output logic setting of definite time overcurrent protection stage2. 7.3.18.3 Setting path Settings of excitation backup protection are accessible in the following path: Main Menu -> SETTINGS -> GEN PROT SETTINGS -> EXC BAK PROT --> [setting symbol]. Note: The current used in the overcurrent protection is derived from the CT at the HV side of excitation transformer or the CT at the neutral point of exciter.



7.3.19 Settings of overload protection of excitation 7.3.19.1 Setting list Table 7.3-19 List of overload protection settings of exciter No. 1 2 3 4 5 6 7 8 9



Symbol



Step 0.01A（kA）



Default



I_OvLd_RotWdg



Range 0.10 –100.00 A（kA）



t_OvLd_RotWdg



0.00 – 25.00 S



0.01S



1



TrpLog_OvLd_RotWdg



0000 - FFFF



1



000F



I_Alm_OvLd_RotWdg



0.10 –100.00 A（kA）



0.01A（kA）



7



t_Alm_OvLd_RotWdg



0.00 – 25.00 S



0.01S



2



0.10 – 50.00 A（kA）



0.01A（kA）



6



tmin_InvOvLd_RotWdg



0.10 – 10.00 S



0.01S



1



A_Therm_RotWdg



1.00 – 100.00



0.01



40



0.10 – 50.00A（kA）



0.01A（kA）



1



0000 - FFFF



1



1FFF



I_InvOvLd_RotWdg



Ib_InvOvLd_RotWdg



10



10



TrpLog_InvOvLd_RotWdg



11



Logic setting ―1‖ - enable, ―0‖ – disable 0，1 Opt_AC_Input_RotWdg



12



Opt_DC_Input_RotWdg



0，1



0



13



Opt_AC_Input_S1_RotWdg



0，1



0



200



1



NR ELECTRIC CO., LTD



Chapter7 Settings



14



Opt_AC_Input_S2_RotWdg



0，1



0



7.3.19.2 Explanation of setting 1



NO.1—[I_OvLd_RotWdg]



Setting of overload protection of rotor winding. If the measured current is inputted by DC type, the unit of the setting is ‗kA‘. Otherwise, ‗A‘ is the unit of AC type current. 2



NO.2—[t_OvLd_RotWdg]



Delay setting of overload protection of rotor winding. 3



NO.3—[TrpLog_OvLd_RotWdg]



Tripping output logic setting of overload protection of rotor winding. 4



NO.4—[I_Alm_OvLd_RotWdg]



Current setting of overload alarm. 5



NO.5—[t_Alm_OvLd_RotWdg]



Delay of overload alarm. 6



NO.6—[I_InvOvLd_RotWdg]



Pickup current of inverse time overload protection. 7



NO.7—[tmin_InvOvLd_RotWdg]



Delay of upper limit of inverse time overload protection. 8



NO.8—[A_Therm_RotWdg]



Thermal capacity parameter of excitation winding. 9



NO.9—[Ib_InvOvLd_RotWdg]



Reference current setting of inverse time overload. 10 NO.10—[TrpLog_InvOvLd_RotWdg] Tripping output logic setting of inverse time overload protection. 11 NO.11—[Opt_AC_Input_RotWdg] Type selection configuration logic setting of current input. ―1‖ is AC current input for overload protection of rotor winding. 12



NO.12—[Opt_DC_Input_RotWdg]



Type selection configuration logic setting of current input. ―1‖ is DC current input for overload protection of rotor winding. 13



NO.13—[Opt_AC_Input_S1_RotWdg]



Type selection configuration logic setting of current input. ―1‖ is the AC current input for overload NR ELECTRIC CO., LTD



201



Chapter7 Settings



protection of rotor winding is derived from HV side of excitation transformer. 14



NO.14—[Opt_AC_Input_S2_RotWdg]



Type selection configuration logic setting of current input. ―1‖ is the AC current input for overload protection of rotor winding is derived from LV side of excitation transformer. 7.3.19.3 Setting path Settings of excitation overload protection are accessible in the following path: Main Menu -> SETTINGS -> PROT SETTINGS -> EXC OVLD PROT --> [setting symbol].



7.3.20 Settings of mechanical protection 7.3.20.1 Setting list Table 7.3-20 List of mechanical protection settings No.



Symbol



Range



Step



Default



0.1S



1



1



0011



0.1S



1



1



0011



0.1S



1



1



0011



0.1S



1



1



0011



1



t_MechRly1



0.00 – 6000.0 S



2



TrpLog_MechRly1



0000 – FFFF



3



t_MechRly2



0.00 – 6000.0 S



4



TrpLog_MechRly2



0000 – FFFF



5



t_MechRly3



0.00 – 6000.0 S



6



TrpLog_MechRly3



0000 – FFFF



7



t_MechRly4



0.00 – 6000.0 S



8



TrpLog_MechRly4



0000 – FFFF



7.3.20.2 Explanation of setting 1



NO.1—[t_MechRly1]



Time delay of output contact of external mechanical contact input1 repeater. 2



NO.2—[TrpLog_MechRly1]



Tripping output logic setting of output contact of mechanical contact input1. 3



NO.3—[t_MechRly2]



Time delay of output contact of external mechanical contact input1 repeater. 4



NO.4—[TrpLog_MechRly2]



Tripping output logic setting of output contact of mechanical contact input2. 5



NO.5—[t_MechRly3]



Time delay of output contact of external mechanical contact input1 repeater. 6



NO.6—[TrpLog_MechRly3]



Tripping output logic setting of output contact of mechanical contact input3. 202



NR ELECTRIC CO., LTD



Chapter7 Settings



7



NO.7—[t_MechRly4]



Time delay of output contact of external mechanical contact input1 repeater. 8



NO.8—[TrpLog_MechRly4]



Tripping output logic setting of output contact of mechanical contact input4. 7.3.20.3 Setting path Settings of mechanical protection are accessible in the following path: Main Menu -> SETTINGS -> PROT SETTINGS -> MECH RLY PROT --> [setting symbol].



7.3.21 Settings of breaker failure protection of generator 7.3.21.1 Setting list Table 7.3-21 List of breaker failure protection settings of generator No.



Symbol



Range



Step



Default



1



I_BFP_GCB



0.10 -- 50.00 A



0.01 A



3



2



I_ROC_BFP_GCB



0.10 -- 20.00 A



0.01 A



3



3



I_NegOC_BFP_GCB



0.10 -- 20.00 A



0.01 A



3



4



t_BFP11_GCB



0.0 - 10.0 S



0.01 S



3



5



TrpLog_BFP11_GCB



0000 – FFFF



1



000F



6



t_BFP12_GCB



0.0 - 10.0 S



0.01 S



3



7



TrpLog_BFP12_GCB



0000 – FFFF



1



001F



Logic setting ―1‖ - enable, ―0‖ – disable 8



En_ROC_BFP_GCB



0，1



1



9



En_NegOC_BFP_GCB



0，1



1



10



En_ExtTrpCtrlBFP_GCB



0，1



1



11



En_CB_Ctrl_BFP_GCB



0，1



1



7.3.21.2 Explanation of setting 1



NO.1—[I_BFP_GCB]



Overcurrent setting of breaker failure protection. 2



NO.2—[I_ROC_BFP_GCB]



Zero sequence overcurrent setting of breaker failure protection 3



NO.3—[I_NegOC_BFP_GCB]



Negative sequence overcurrent setting of breaker failure protection 4



NO.4—[t_BFP11_GCB]



Time delay 1 of breaker failure protection. 5



NO.5—[TrpLog_BFP11_GCB]



NR ELECTRIC CO., LTD



203



Chapter7 Settings



Tripping output logic setting of breaker failure protection stage 1. 6



NO.6—[t_BFP12_GCB]



Time delay 2 of breaker failure protection. 7



NO.7—[TrpLog_BFP12_GCB]



Tripping output logic setting of breaker failure protection stage 2. 8



NO.8—[En_ROC_BFP_GCB]



Logic setting of enabling zero sequence current to block breaker failure protection. 9



NO.9—[En_NegOC_BFP_GCB]



Logic setting of enabling negative sequence current to block breaker failure protection. 10 NO.10—[En_ExtTrpCtrlBFP_GCB] Logic setting of enabling external tripping signal to be a blocking condition of breaker failure protection. 11 NO.11—[En_CB_Ctrl_BFP_GCB] Logic setting of enabling the open position of breaker to be a blocking condition of breaker failure protection. 7.3.21.3 Setting path Settings of breaker failure protection are accessible in the following path: Main Menu -> SETTINGS -> GEN PROT SETTINGS -> GEN BFP PROT --> [setting symbol].



7.4



Calculated parameters



The settings listed in the following tables calculated by the RCS-985G itself automatically, they need not to be set by user. The settings are calculated according to the system parameters that user input, include primary rated currents, secondary rated currents, secondary rated voltages and correction coefficients used in all kinds of differential protection relays. Listing of the calculated settings is only for reference of setting check or commission.



7.4.1 Setting list Table 7.4-1 List of calculated parameters Primary rated current NO.



Signal



Range



1



I1b_CT_Gen



0-60000 A



2



I1b_CT_SP1_Gen



0-60000 A



3



I1b_CT_SP2_Gen



0-60000 A



4



I1b_CT_S1_Exc



0-60000 A



204



Note



NR ELECTRIC CO., LTD



Chapter7 Settings



5



I1b_CT_S2_Exc



0-60000 A Secondary rated current



NO.



Signal



Range



1



I2b_CT_Gen



0-600.00 A



2



I2b_CT_SP1_Gen



0-600.00 A



3



I2b_CT_SP2_Gen



0-600.00 A



4



I2b_CT_S1_Exc



0-600.00 A



5



I2b_CT_S2_Exc



0-600.00 A



Note



Secondary rated voltage NO.



Signal



Range



1



U2b_Term_Gen



0-600.00 A



2



U2b_DeltVT_Term_Gen



0-600.00 A



3



U2b_NP_Gen



0-600.00 A



4



k_RV_Gen



0-60.00



Note



Diff Corr Coef NO.



Signal



Range



1



k_Diff_Gen



0-60.000



2



k_SP1_Diff_Gen



0-60.000



3



k_SP2_Diff_Gen



0-60.000



4



k_S1_Diff_Exc



0-60.000



5



k_S2_Diff_Exc



0-60.000



Note



7.4.2 Explanation of the parameters 1



No.1-- [I1b_CT_Gen]



Primary rated current of generator calculated by RCS-985G according to parameters input. 2



No.2-- [I1b_CT_SP1_Gen]



Primary rated current of the first splitting branch at the neutral point of generator calculated by RCS-985G according to parameters input. 3



No.3-- [I1b_CT_SP2_Gen]



Primary rated current of the second splitting branch at the neutral point of generator calculated by RCS-985G according to parameters input. 4



No.4-- [I1b_CT_S1_Exc]



Primary rated current at HV side of excitation transformer or terminal side of exciter calculated by RCS-985G according to parameters input. 5



No.5-- [I1b_CT_S2_Exc]



Primary rated current at LV side of excitation transformer or neutral point side of exciter calculated by RCS-985G according to parameters input. 6



No.6-- [I2b_CT_Gen]



NR ELECTRIC CO., LTD



205



Chapter7 Settings



Secondary rated current of generator calculated by RCS-985G according to parameters input. 7



No.7-- [I2b_CT_SP1_Gen]



Secondary rated current of the first splitting branch at the neutral point of generator calculated by RCS-985G according to parameters input. 8



No.8-- [I2b_CT_SP2_Gen]



Secondary rated current of the second splitting branch at the neutral point of generator calculated by RCS-985G according to parameters input. 9



No.9-- [I2b_CT_S1_Exc]



Secondary rated current at HV side of excitation transformer or terminal side of exciter calculated by RCS-985G according to parameters input. 10 No.10-- [I2b_CT_S2_Exc] Secondary rated current at LV side of excitation transformer or neutral point side of exciter calculated by RCS-985G according to parameters input. 11 No.11-- [U2b_Term_Gen] Secondary rated current at the terminal of generator calculated by RCS-985G according to parameters input. 12 No.12-- [U2b_DeltVT_Term_Gen] Secondary rated zero sequence voltage derived from open-delta side of VT at the terminal of generator calculated by RCS-985G according to parameters input. 13 No.13-- [U2b_NP_Gen] Secondary rated zero sequence voltage derived from open-delta side of VT at the neutral point of generator calculated by RCS-985G according to parameters input. 14 No.14-- [k_RV_Gen] Balance coefficient of zero sequence voltage of generator. The setting is used to adjust zero sequence of generator terminal to the same base as the one of neutral point. 15 No.15-- [k_Diff_Gen] Correction coefficient for generator differential protection. 16 No.16-- [k_SP1_Diff_Gen] Correction coefficient of current of the first splitting branch at the neutral point side of generator for generator differential protection. 17 No.17-- [k_SP2_Diff_Gen] Correction coefficient of current of the second splitting branch at the neutral point side of generator for generator differential protection.



206



NR ELECTRIC CO., LTD



Chapter7 Settings



18 No.18-- [k_S1_Diff_Exc] Correction coefficient of current of HV side of excitation transformer or terminal side of exciter for excitation differential protection. 19 No.19-- [k_S2_Diff_Exc] Correction coefficient of current of LV side of excitation transformer or neutral point side of exciter for excitation differential protection.



7.4.3 Setting path All settings of generator system parameters are accessible in the following path: Main Menu -> SETTINGS -> CALC SETTINGS -> PRI RATED CURR -> [setting symbol] Main Menu -> SETTINGS -> CALC SETTINGS -> SEC RATED CURR -> [setting symbol] Main Menu -> SETTINGS -> CALC SETTINGS -> SEC RATED VOLT -> [setting symbol] Main Menu -> SETTINGS -> CALC SETTINGS -> DIFF CORR COEF -> [setting symbol]



NR ELECTRIC CO., LTD



207



Chapter7 Settings



208



NR ELECTRIC CO., LTD



Chapter8 Human Machine Interface



Chapter8 Human Machine Interface User can access the relay from the front panel of the device. Local communication with the relay is possible using a computer (PC) with the RCSPC software via an RS232 port on the front panel. Furthermore, remote communication is also possible in switched-in substation automatic system via a RS485 port. This chapter describes human machine interface (HMI), menu tree and LCD display. At the same time how to input settings using keypad is described in detail. Finally, this chapter introduces the RCSPC software and wave analysis software.



8.1



User interfaces and menu structure



The settings and functions of the RCS-985G protection relay can be accessed both from the front panel keypad and LCD, and via the front and rear communication ports. Information on each of these methods is given in this section to describe how to start using the relay.



8.2



Introduction to the relay



8.2.1 Front panel The front panel of the relay is shown in Figure 8.2-1. The human-machine interface consists of a human-machine interface (HMI) module which allows the communication to be as simple as possible for the user.



RCS-985G



5



GENERATOR PROTECTION



2



CT ALM ALARM



1



TRIP



ENT ESC



VT ALM



GRP



HEALTHY



3



4



NARI RELAYS ELECTRIC CO., LD



6



Figure 8.2-1 Front view of the protection



NR ELECTRIC CO., LTD



209



Chapter8 Human Machine Interface



The front panel of the relay includes the following, as indicated in Figure 8.2-1: Table 8.2-1 Description of each part



No.



Brief description



1



A 320*240 dots liquid crystal display (LCD)



2



The relay front panel features control pushbutton switches with LEDs that facilitate local control. Factory default settings associate specific relay functions with these 9 direct-action pushbuttons and LEDs e.g.



3



A 9-key keypad comprising 4 arrow keys (◄,►,▲and ▼), an plus key (+), a minus key (-), a escape key ( ESC) and a active group setting key (GRP)



4



A 9-pin female D-type front port for communication with a PC locally to the relay (up to 15m distance) via an EIA(RS)232 serial data connection, which providing internal signal monitoring and high speed local downloading of software.



5



Name of protection



6



Name of manufacture



8.2.2 LCD A 320*240 dots liquid crystal display (LCD) with LED backlight. The backlight can be switched on automatically whenever the keypad is operated or operation or alarm issued. Backlight will be turned off after a while. 8.2.2.1 Default Display The front panel menu has a default display under normal state after power-up. If there is no keypad activity during the 5 minute timeout period, default display will return again and the LCD backlight will turn off. To provide more information, the default display a typical single-line scheme generator system and relevant quantities in operation condition, as shown below.



210



NR ELECTRIC CO., LTD



Chapter8 Human Machine Interface Version



985G3Q 3.11



2007-3-22 10:28:03 GRP: 0



Real clock



Term voltage



0.00V



Term current



0.00A



NP current NP voltage



0.00A 0.00V



DIF: 0.00Ie DIS: 0.00Ie



Diff Curr. Of Gen Diff Curr. Of Exc



F: 0.00 Hz P: +0.00 % Q: +0.00 % Ur: 0.0 V Rg: .....k



Frequency Power Rotor voltage Earth resistance



Figure 8.2-2 Default display of RCS-985G 8.2.2.2 Fault report Whenever there is an un-eliminated fault record in the relay, the default display will be replaced by a fault report.



NO. of SOE Real Time: hh--mm--ss--ms Relative Time



No. 002



Trip 2006 - 06 - 15



0025ms



Report 14 : 15 : 00 : 003



Op_Diff_Gen



Protection element



Figure 8.2-3 Fault display of RCS-985G All the protection elements listed below may be displayed. Table 8.2-2 List of operation elements NO.



Protection Element



Note



1



Op_InstDiff_Gen



Operation of instantaneous unrestraint differential protection of generator



2



Op_PcntDiff_Gen



Operation of percentage differential protection of generator



3



Op_DPFC_Diff_Gen



Operation of DPFC (Deviation of Power Frequency



NR ELECTRIC CO., LTD



211



Chapter8 Human Machine Interface



Component) differential protection of generator 4



Op_InstSPTDiff_Gen



Operation of instantaneous phase-splitting transverse differential protection of generator



5



Op_PcntSPTDiff_Gen



Operation of percentage phase-splitting differential protection of generator



6



Op_GenDiff_StShut_Gen



Operation of differential current element of startup and shut off protection of generator



7



Op_UFOC_StShut_Gen



Operation of low frequency overcurrent element of startup and shut off protection of generator



8



Op_StaROV_StShut_Gen



Operation of residual over voltage element of startup and shut off protection of generator



9



Op_DPFC_IntTurn_Gen



Operation of DPFC interturn protection of generator



10



Op_SensTrvDiff_Gen



Operation of transverse differential protection of generator



11



Op_InsensTrvDiff_Gen



Operation of insensitive stage of transverse differential protection of generator



12



Op_SensIntTurn_Gen



Operation of any of the interturn protection of generator



13



Op_InsensIntTurn_Gen



Operation of any of the insensitive stage of interturn protection of generator



14



Op_SensROV_Sta



Operation of sensitive stage zero sequence over voltage element of earth fault protection of stator



15



Op_InsensROV_Sta



Operation of insensitive stage zero sequence over voltage element of earth fault protection of stator



16



Op_V3rdHRatio_Sta



Operation of 3rd harmonics ratio earth fault protection of stator



17



Op_V3rdHDiff_Sta



Operation of 3rd harmonics differential earth fault protection of stator



18



Op_1PEF_RotWdg



Operation of 1 point earth fault protection of rotor



19



Op_2PEF_RotWdg



Operation of 2 point earth fault protection of rotor



20



Op_OvLd_Sta



Operation of definitive time overload protection of stator



21



Op_InvOvLd_Sta



Operation of inverse time overload protection of stator



22



Op_NegOC1_Gen



Operation of stage 1 of negative sequence overcurrent protection of rotor



23



Op_NegOC2_Gen



Operation of stage 2 of negative sequence overcurrent protection of rotor



24



Op_InvNegOC_Gen



Operation of inverse time negative sequence overcurrent



212



transverse



NR ELECTRIC CO., LTD



Chapter8 Human Machine Interface



protection of rotor 25



Op_OvLd_RotWdg



Operation of definitive time overload protection of rotor winding



26



Op_InvOvLd_RotWdg



Operation of inverse time overload protection of rotor winding



27



Op_OC1_Gen



Operation of stage 1 of overcurrent protection of generator



28



Op_OC2_Gen



Operation of stage 2 of overcurrent protection of generator



29



Op_OV1_Gen



Operation of stage 1 of overvoltage protection of generator



30



Op_OV2_Gen



Operation of stage 2 of overvoltage protection of generator



31



Op_UV_Gen



Operation of undervoltage protection of generator



32



Op_OvExc1_Gen



Operation of stage 1 of overexcitation protection of generator



33



Op_OvExc2_Gen



Operation of stage 2 of overexcitation protection of generator



34



Op_InvOvExc_Gen



Operation of inverse time stage of overexcitation protection of generator



35



Op_UF1_Gen



Operation of stage 1 of underfrequency protection of generator



36



Op_UF2_Gen



Operation of stage 2 of underfrequency protection of generator



37



Op_UF3_Gen



Operation of stage 3 of underfrequency protection of generator



38



Op_OF1_Gen



Operation of stage 1 of overfrequency protection of generator



39



Op_OF2_Gen



Operation of stage 2 of overfrequency protection of generator



40



Op_Z1_Gen



Operation of stage 1 of distance protection of generator



41



Op_Z2_Gen



Operation of stage 2 of distance protection of generator



42



Op_LossExc1_Gen



Operation of stage 1 of loss-of-excitation protection of generator



43



Op_LossExc2_Gen



Operation of stage 2 of loss-of-excitation protection of generator



44



Op_LossExc3_Gen



Operation of stage 3 of loss-of-excitation protection of generator



45



Op_Ext_OOS_Gen



Operation of out-of-step protection outside zone of



NR ELECTRIC CO., LTD



213



Chapter8 Human Machine Interface



generator 46



Op_Int_OOS_Gen



Operation of out-of-step protection inside zone of generator



47



Op_BFP11_Gen



Operation of break failure protection of generator with time delay 1



48



Op_BFP12_Gen



Operation of break failure protection of generator time delay 2



49



Op_RevP_Gen



Operation of reverse power protection of generator



50



Op_SeqTrpRevP_Gen



Operation of under power protection of generator



51



Op_AccEnerg_Gen



Operation of accidental energization protection of generator



52



Op_Flash11_GCB



Operation of stage 1 of flashover protection of generator



53



Op_Flash12_GCB



Operation of stage 2 of flashover protection of generator



54



Op_InstDiff_Exciter



Operation of instantaneous differential protection of exciter



55



Op_PcntDiff_Exciter



Operation of percentage differential protection of exciter



56



Op_InstDiff_ET



Operation of instantaneous excitation transformer



57



Op_PcntDiff_ET



Operation of percentage differential protection of excitation transformer



58



Op_OC1_ET



Operation of stage 1 of overcurrent protection of excitation transformer



59



Op_OC2_ET



Operation of stage 2 of overcurrent protection of excitation transformer



60



Op_MechRly1



Operation of repeater of external mechanical input 1(Manual emergency tripping)



61



Op_MechRly2



Operation of repeater of external mechanical input 2(Failure of condenser vacuum)



62



Op_MechRly3



Operation of repeater of external mechanical input 3(Stage 1 of 1PEF of rotor)



63



Op_MechRly4



Operation of repeater of external mechanical input 4(Stage 2 of 1PEF of rotor)



differential



protection



of



8.2.2.3 Alarm report Whenever there is an un-eliminated internal failure record in the relay, the default display will be replaced by an alarm report.



214



NR ELECTRIC CO., LTD



Chapter8 Human Machine Interface



NO. of SOE



No. 002



Real Time: hh--mm--ss--ms



Alarm Report 2006 - 06 - 15



14 : 15 : 00 : 003



Alm_BlkV3rdHDiff_VTS



Relative Time Alarm element



Figure 8.2-4 Alarm display of RCS-985G All the alarm elements listed below may be displayed. Table 8.2-3 List of alarm elements N O.



Alarm Element



Brief description



1.



Alm_RAM_CPUBrd



CPU module RAM damaged.



2.



Alm_ROM_CPUBrd



CPU module flash memory damaged.



3.



Alm_EEPROM_CPUBrd



CPU module EEPROM damaged judged by the mismatch of summation of all the settings with the CRC code .



4.



Alm_InvalidSetting



Without modifying protection setting after modification of rated secondary current of CT.



5.



Alm_ModifiedSetting



In the proceeding of setting parameters.



6.



Alm_PwrLoss_Opto



Loss of power supply of the optical couplers for binary inputs.



7.



Alm_TripOutput



Driving transistor of binary output damaged.



8.



Alm_DSP_CPUBrd



The DSP chip in CPU board damaged.



9.



Alm_DSP_MONBrd



The DSP chip in MON board damaged.



10.



Alm_Sample_CPUBrd



Failure of sampled data in CPU board.



11.



Alm_Sample_MONBrd



Failure of sampled data in MON board.



12.



Alm_RAM_MONBrd



MON module RAM damaged.



13.



Alm_ROM_MONBrd



MON module flash memory damaged.



14.



Alm_EEPROM_MONBrd



MON module EEPROM damaged.



15.



Alm_MONBrd



MON module damaged.



16.



Alm_PM_DSP2_CPUBrd



The DSP2 chip on CPU board damaged.



17.



Alm_PM_DSP1_CPUBrd



The DSP1 chip on CPU board damaged.



18.



Alm_Inconsist_MechRly



Alarm of the power supply of mechanical protection, such as falling down or be in other abnormal



NR ELECTRIC CO., LTD



215



Chapter8 Human Machine Interface



conditions. 19.



The power supply of mechanical protection is lost.



20.



Alm_PwrLoss_MechRly Alm_InconsistFD



21.



Alm_PersistFD_CPUBrd



Duration of pickup of any fault detector in CPU board is in excess of 10s.



22.



Alm_PersistFD_MONBrd



Duration of pickup of any fault detector in MON board is in excess of 10s.



23.



Alm_BI_CPUBrd



Any one of binary input sampled directly doesn‘t match with that of recognition of protection itself.



24.



Alm_InnerComm



Alarm indicating that the communication between MON and CPU interrupts.



25.



Alm_Pos_GCB



The sampled status of auxiliary contact of generator terminal breaker‘s don‘t match with that of operation condition identified from calculation of voltage and currents.



26.



Alm_SwOv_VTS1_Gen



Alarm indicating VT1 circuit failure and start to switch over voltage circuit.



27.



Alm_SwOv_VTS2_Gen



Alarm indicating VT2 circuit failure and start to switch over voltage circuit.



28.



Alm_BlkV3rdHDiff_VTS1



Alarm indicating VT1 circuit failure and blocking 3rd harmonics voltage differential protection.



29.



Alm_BlkIntTurn_VTS2



Alarm indicating VT2 circuit failure and blocking interturn protection.



30.



Alm_VTS_HVS_Tr



Alarm indicating secondary circuit failure of VT at HV side of main transformer.



31.



Alm_VTS1_Term_Gen



Alarm indicating secondary circuit failure of VT1 at generator terminal.



32.



Alm_VTS2_Term_Gen



Alarm indicating secondary circuit failure of VT2 at generator terminal.



33.



Alm_VTS_NP_Gen



Alarm indicating secondary circuit failure of VT at the neutral point of generator.



34.



Alm_DeltVTS1_Term_Gen



Alarm indicating secondary circuit failure at open-delta side of VT1 at generator terminal.



35.



Alm_DeltVTS2_Term_Gen



Alarm indicating secondary circuit failure at open-delta side of VT2 at generator terminal.



36.



Alm_VTS_LossExc_RotWdg



Alarm indicating rotor voltage circuit failure which used by loss-of-excitation protection.



37.



Alm_CTS_BakCT_Gen



Alarm indicating secondary circuit abnormality of backup CT at generator terminal.



38.



Alm_CTS_Term_Gen



Alarm indicating secondary circuit abnormality of CT at generator terminal.



39.



Alm_CTS_NP_Gen



Alarm indicating secondary circuit abnormality of CT at the neutral point of generator.



216



Mismatch of pickup of same type fault detectors in CPU and MON.



NR ELECTRIC CO., LTD



Chapter8 Human Machine Interface



40.



Alm_CTS_SP1_Gen



Alarm indicating secondary circuit abnormality of CT installed in splitting-phase branch1 at the neutral point of generator .



41.



Alm_CTS_SP2_Gen



Alarm indicating secondary circuit abnormality of CT installed in splitting-phase branch2 at the neutral point of generator.



42.



Alm_Diff_Gen



Alarm indicating differential current of generator is in excess of normally endurable level.



43.



Alm_SPTDiff_Gen



Alarm indicating splitting-phase transverse differential current of generator is in excess of normally endurable level.



44.



Alm_CTS_Diff_Gen



Alarm indicating secondary circuit failure of CTs used for differential protection.



45.



Alm_CTS_SPTDiff_Gen



Alarm indicating secondary circuit failure of CTs used for splitting-phase transverse differential protection.



46.



Alm_CTS_S1_Exc



Alarm indicating secondary circuit failure of CT at side1 of excitation set used in differential protection of excitation.



47.



Alm_CTS_S2_Exc



Alarm indicating secondary circuit failure of CT at side2 of excitation set used in differential protection of excitation.



48.



Alm_Diff_ET



Alarm indicating differential current of excitation transformer is in excess of normally endurable level.



49.



Alm_Diff_Exciter



Alarm indicating differential current of exciter is in excess of normally endurable level.



50.



Alm_CTS_Diff_ET



Alarm indicating secondary circuit failure of CT used in excitation transformer differential protection.



51.



Alm_CTS_Diff_Exciter



Alarm indicating secondary circuit failure of CT used in exciter differential protection.



52.



Alm_VTS_Exc



Alarm indicating secondary circuit failure of VT installed for excitation set.



53.



Alm_DPFC_IntTurn_Gen



Alarm indicating operation protective element.



54.



Alm_BO_OC_Term_Gen



Alarm indicating operation of overcurrent element used for driving a set of contact to block other circuit.



55.



Alm_On_2PEF_RotWdg



Alarm indicating 2 points earth fault protection has been put input operation after operation of 1 point earth fault protection of rotor.



56.



Alm_Ext_OOS_Gen



Alarm indicating out-of-step of system occurs while its oscillating center is outside protective zone.



57.



Alm_Int_OOS_Gen



Alarm indicating out-of-step of system occurs and its oscillating center is inside protective zone.



58.



Alm_Accel_OOS_Gen



Alarm indicating accelerate out-of-step occurs.



59.



Alm_Decel_OOS_Gen



Alarm indicating decelerate out-of-step occurs.



NR ELECTRIC CO., LTD



of



DPFC



interturn



217



Chapter8 Human Machine Interface



60.



Alm_LossExc_Gen



Alarm indicating operation protective element.



of



loss-of-excitation



61.



Alm_OvExc_Gen



Alarm indicating operation of over excitation protective element.



62.



Alm_OvLd_Sta



Alarm indicating operation of overload element of stator.



63.



Alm_NegOC_Gen



Alarm indicating operation of negative overcurrent protective element of stator.



64.



Alm_OvLd_RotWdg



65.



Alm_ROV_Sta



Alarm indicating operation of negative overcurrent protective element of stator. Alarm indicating operation of fundamental zero-sequence overvoltage earth fault protective element of stator



66.



Alm_V3rdHRatio_Sta



Alarm indicating operation of 3rd harmonics ratio earth fault protective element of stator.



67.



Alm_V3rdHDiff_Sta



Alarm indicating operation of 3rd harmonics differential earth fault protective element of stator.



68.



Alm_Sens1PEF_RotWdg



Alarm indicating operation of sensitive stage of 1 point earth fault protective element of rotor.



69.



Alm_1PEF_RotWdg



Alarm indicating operation of normal stage of 1 point earth fault protective element of rotor.



70.



Alm_UF1_Gen



Alarm indicating operation of stage 1 of under frequency protective element of generator.



71.



Alm_UF2_Gen



Alarm indicating operation of stage 2 of under frequency protective element of generator.



72.



Alm_UF3_Gen



Alarm indicating operation of stage 3 of under frequency protective element of generator.



73.



Alm_OF1_Gen



Alarm indicating operation of stage 1 of over frequency protective element of generator.



74.



Alm_OF2_Gen



Alarm indicating operation of stage 2 of over frequency protective element of generator.



75.



Alm_RevP_Gen



Alarm indicating operation of reverse power protective element of generator.



76.



Alm_MechRly4



Alarm indicating operation of mechanical repeater 4



77.



Alm_MechRly3



Alarm indicating operation of mechanical repeater 3



78.



Alm_MechRly2



Alarm indicating operation of mechanical repeater 2



79.



Alm_MechRly1



Alarm indicating operation of mechanical repeater 1



8.2.2.4 Change of Binary inputs Whenever there is change of state of any binary input, the default display will be replaced by change report of binary input as shown as below.



218



NR ELECTRIC CO., LTD



Chapter8 Human Machine Interface



NO. of SOE



No. 002



Real Time: hh--mm--ss--ms



BI Chang Report 2006 - 06 - 15



14 : 15 : 00 : 003



EBI_Diff_Gen



Binary input name



1à0



Change maner



Figure 8.2-5 Binary input state changing display of RCS-985G All the binary inputs listed below may be displayed. Table 8.2-4 List of binary input change elements NO.



BI_Chg Element



Brief description



1



EBI_Diff_Gen



Enabling binary input of differential protection of generator



2



EBI_SPTDiff_Gen



Enabling binary input of phase-splitting transverse differential protection of generator



3



EBI_IntTurn_Gen



Enabling binary input of turn-to-turn protection of generator



4



EBI_ROV_Sta



Enabling binary input of residual overvoltage stator earth fault protection of generator



5



EBI_V3rdH_Sta



Enabling binary input of 3rd harmonics stator earth fault protection of generator



6



EBI_1PEF_RotWdg



Enabling binary input of 1 point rotor earth fault protection of generator



7



EBI_2PEF_RotWdg



Enabling binary input of 2 point rotor earth fault protection of generator



8



EBI_OvLd_Sta



Enabling binary input of stator overload protection of generator



9



EBI_NegOC_Gen



Enabling binary input of stator negative sequence overcurrent protection of generator



10



EBI_LossExc_Gen



Enabling binary input of loss-of-excitation protection of generator



11



EBI_OOS_Gen



Enabling binary input of loss-of-step protection of generator



12



EBI_VoltProt_Gen



Enabling binary input of overvoltage protection of generator



13



EBI_OvExc_Gen



Enabling binary input of overexcitation protection of



NR ELECTRIC CO., LTD



219



Chapter8 Human Machine Interface



generator 14



EBI_PwrProt_Gen



Enabling binary input of reverse power protection of generator



15



EBI_FreqProt_Gen



Enabling binary input of frequency protection of generator



16



EBI_AccEnerg_Gen



Enabling binary input of accidental energization protection of generator



17



EBI_StShut_Gen



Enabling binary input of startup and shutdown protection of generator



18



EBI_Diff_Exc



Enabling binary input of differential protection of excitation set



19



EBI_Bak_Exc



Enabling binary input of backup protection of excitation set



20



EBI_Trp_MechRly3



Enabling binary input of tripping function of repeater of mechanical input 3(Stage 1 of 1PEF of rotor)



21



EBI_Trp_MechRly4



Enabling binary input of tripping function of repeater of mechanical input 4(Stage 2 of 1PEF of rotor)



22



EBI_Trp_MechRly2



Enabling binary input of tripping function of repeater of mechanical input 2(Failure of condenser vacuum)



23



EBI_Trp_MechRly1



Enabling binary input of tripping function of repeater of mechanical input 1(Manual emergency tripping)



24



EBI_PPF_Gen



Enabling binary input of backup protection of generator



25



BI_SyncCondenser



Binary input indicating synchronism condenser is put into operation



26



BI_ExtProtTrp



Binary input indicating the external contact state of other operation element operates.



27



BI_Pwr_Superv



Binary input indicating working condition of all other binary inputs



28



EBI_OvLd_RotWdg



Enabling binary input of overload protection of excitation



29



EBI_SeqTrpRevP_Gen



Enabling binary input of sequence tripping function of generator



30



EBI_BFP_Gen



Enabling binary input of breaker failure protection of generator.



31



BI_Print



Binary input representing the position of printing button



32



BI_Pulse_GPS



Binary input representing the state of GPS pulse



33



BI_RstTarg



Binary input representing the position of signal reset button



34



BI_Pwr_Opto



Binary input indicating the working state of power supply of optical isolators



35



BI_MechRly2



Binary input indicating the position of mechanical input 2(Failure of condenser vacuum)



36



BI_MechRly4



Binary input indicating the position of mechanical input 4(Stage 2 of 1PEF of rotor)



37



BI_MechRly3



Binary input indicating the position of mechanical input



220



NR ELECTRIC CO., LTD



Chapter8 Human Machine Interface



3(Stage 1 of 1PEF of rotor) 38



BI_MechRly1



Binary input indicating the position of mechanical input 1(Manual emergency tripping)



39



BI_Pwr_MechRly



Binary input indicating the working state of power supply of mechanical input circuit



40



BI_52b_GCB



Binary input indicating the position of breaker at generator terminal



41



BI_Value_Turbine



Binary input indicating the position of valve of turbine



42



FD_Diff_Gen



Internally generated virtual binary input in MON indicating operation of the fault detector of differential protection



43



FD_EF_Sta



Internally generated virtual binary input in MON indicating operation of the fault detector of stator earth fault protection



44



FD_EF_RotWdg



Internally generated virtual binary input in MON indicating operation of the fault detector of rotor earth fault protection



45



FD_OvLd_Sta



Internally generated virtual binary input in MON indicating operation of the fault detector of stator overload element



46



FD_PPF_Gen



Internally generated virtual binary input in MON indicating operation of the fault detector of backup protection of generator



47



FD_Volt&OvExc_Gen



Internally generated virtual binary input in MON indicating operation of the fault detector of overexcitation protection or voltage protection of generator



48



FD_FreqProt_Gen



Internally generated virtual binary input in MON indicating operation of the fault detector of frequency protection of generator



49



FD_LossExc&OOS_Gen



Internally generated virtual binary input in MON indicating operation of the fault detector of loss-of-excitation protection of generator



50



FD_Pwr&AccEnerg_Gen



Internally generated virtual binary input in MON indicating operation of the fault detector of power protection or accidental energization protection of generator



51



FD_StShut_Gen



Internally generated virtual binary input in MON indicating operation of the fault detector of startup and shutdown protection of generator



52



FD_Prot_Exc



Internally generated virtual binary input in MON indicating operation of the fault detector of any protection of excitation



53



FD_MechRly



Internally generated virtual binary input in MON indicating operation of the fault detector of mechanical protection



8.2.3 LED indications LED indicators include：‖HEALTHY‖,‖ VT ALARM‖,‖ CT ALARM‖ ,‖ ALARM‖,‖ TRIP‖. NR ELECTRIC CO., LTD



221



Chapter8 Human Machine Interface



HEALTHY VT ALARM CT ALARM ALARM TRIP



TARGET RESET



Figure 8.2-6 LEDs on faceplate of RCS-985G ―Healthy‖ (Green) indicates that the relay is in correct working order, and should be on at all times. It will be extinguished when some internal error in hardware or software has been detected by the self-diagnosing facilities, such as setting error, RAM or ROM error, power source failure, output circuit failure and so on. The state of the healthy LED is reflected by the watchdog contact at the rear terminals of the relay. The healthy LED cannot come on again automatically even if the failure is eliminated except through resetting the relay or through power up by manual. ―VT Alarm‖ (Yellow) indicates that the relay has found any failure of VT circuit. ―CT Alarm‖ (Yellow) indicates that the relay has found any failure of CT circuit. ―Alarm‖ (Yellow) indicates that the relay has registered an alarm. This may be triggered by one of the following failures: defective pickup, failure of analog or digital input circuit, optical isolator power loss and so on. The LED will constantly illuminate, and will extinguish, when the alarms have been cleared. The LED ―TRIP‖ (RED) will be lit up once the corresponding relays operate and remain lit even after the trip commands go off. It can be turned off by pressing ―TAEGET RESET‖ button on faceplate, or by pressing the RESET button on the protection panel to energized binary input [BI_RstTarg], or by remote resetting command.



222



NR ELECTRIC CO., LTD



Chapter8 Human Machine Interface



GR P ESC



8.2.4 Keypad operation



+ ENT



-



Figure 8.2-7 Keypad buttons No.



Item



Function



1



―▲‖ and ―▼‖



move cursor left-fight among selectable target



2



―◄‖ and ―►‖



move cursor up-down among selectable target



3



―+‖ and ―-‖



4 5



ENT GRP



add or subtract in the digit provide Enter/Execute function



5



ESC



setting Group selection exit the present menu or return to the upper menu



Note! Any setting change operation should start by simply pressing ―+‖, ―◄‖, ―▲‖,and ―-‖ in sequence, as a password. Without the operation, modifying settings is invalid. Report delete operation should executed by pressing ―+‖, ―-‖, ―+‖, ―-‖, ―ENT‖ in sequence after exiting the main menu.



8.2.5 Menu 8.2.5.1 Menu tree This part presents the main layout of the menu tree for the local human-machine interface (HMI). The menu tree includes menus for: 



VALUES







REPORT







PRINT







SETTINGS







CLOCK







VERSION







DEBUG



NR ELECTRIC CO., LTD



223



N A R I - R E L A Y S



Chapter8 Human Machine Interface



VALUES



CPU METERING



GEN DIFF CURR



REPORT



CPU BI STATE



GEN TRVDIFF CURR



PRINT



MON METERING



GEN MON VOLTAGE METERING



MON BI STATE



GEN MISC VALUES



PHASE ANGLE



RotWdg METERING



SETTINGS CLOCK VERSION



INJ METERING EXC AC METERING



DEBUG



Figure 8.2-8 View diagram of menu The default display can be replaced by the menu when press―▲‖ or ―ESC‖. The menu of this relay is arranged as a tree-shaped cascade structure. See Figure 8.2-9. The menu can be browsed using the keypad. Starting at the default display, to enter into main menu, press ―▲‖. To select the required item, use the ―▲‖ ―▼‖keys. To enter the lower level menu, select the required item and press ―ENT‖. To return to the upper level menu, press ―ESC‖ or select ―0. Exit‖ and push ―ENT‖. The menu can be browsed using the four arrow keys, following the structure shown in Figure 8.2-8. Thus, starting at the default display the ―▲‖ key will display the first column heading. To select the required column heading use the ―▲‖and ―▼‖ keys. To return to the default display, press the clear key ―ESC‖ from any of the column headings.



224



NR ELECTRIC CO., LTD



Chapter8 Human Machine Interface MENU



GEN DIFF CURR



VALUES



CPU METERING



REPORT



CPU BI STATE



GEN PROT EBI



GEN TRVDIFF CURR



PRINT



MON METERING



EXC PROT EBI



GEN VOLTAGE



SETTINGS



MON BI STATE



MECH RLY EBI



GEN MISC VALUES



CLOCK



PHASE ANGLE



AUX BI



RotWdg METERING



VERSION



PROT FD



INJ METERING



DEBUG



PS SUPERV BI



EXC AC METERING



SAME TO CPU METERING SAME TO CPU BI STATE TRIP REPORT ALARM REPORT



GEN PH ANG EXC PH ANG



BI CHG REPORT GEN DIFF PROT GEN SPTDIFF PROT SETTINGS GEN INTTURN PROT



ACTIVE SETTINGS



TRIP RECORD EQUIP SETTINGS



GEN PPF BAK PROT



ALARM REPORT TRIGGER



SYSTEM SETTINGS



BI STATE



PROT SETTINGS



ROTWDG EF PROT



PHASE ANGLE



CALC SETTINGS



STA OVLD PROT



GEN DIFF WAVE



TRIP LOGIC



GEN TRVDIFF WAVE



MODIFIED SETTINGS



GEN VOLT WAVE



OTHER GRP SETTINGS



STA EF PROT



BI CHG REPORT



INJ STA EF PROT



PRESENT WAVE



STA NEGOC PROT



EQUIP SETTINGS



GEN LOSSEXC PROT



SYSTEM SETTINGS



GEN OOS PROT



PROT SETTINGS



GEN VOLT PROT



SETTINGS COPY



GEN OVEXC PROT



CALC SETTINGS



GEN MISC WAVE EXC CURR WAVE STA EF WAVE



GEN PWR PROT



TRIP REPORT GEN DIFF WAVE



GEN FREQ PROT



GEN TRVDIFF WAVE



GEN STSHUT PROT



COMM STATUS



GEN ACCENERG PROT



MEMORY IMAGE



EXC DIFF PROT



PROT CONFIG



GEN VOLT WAVE



GEN SYS SETTINGS



GEN MISC WAVE



EXC SYS SETTINGS



EXC CURR WAVE



EXC BAK PROT



STA EF WAVE



EXC OVLD PROT



PRI RATED CURR



MECH RLY PROT



SEC RATED CURR SEC RATED VOLT DIFF CORR COEF



Figure 8.2-9 Relay menu map of RCS-985G 8.2.5.2 Password protection The menu structure contains two levels of access. The level of access is enabled determines what users can do by entry of password. The levels of access are summarized in the following table: NR ELECTRIC CO., LTD



225



Chapter8 Human Machine Interface



Table 8.2-5 Password level Access level



Operations enabled



Level 0 No password required



Read access to all settings, alarms, event records and fault records



Level 1 Password required



All settings modified



The password is 4 digits. The factory default passwords is sequent pressing of the keys ―+‖, ―◄‖, ―▲‖, ―-‖ and ―ENT‖.



8.2.6 Operation instruction of Menu The following contents are to tell users how to make use of each submenu in detail. 8.2.6.1 View CPU and MON metering values Metering data consists of AC sampled data and phase angle in the submenu VALUES. Take viewing data relevant to differential protection of CPU metering as an example. Users can view data of MON in the same way by entering ―MON METERING‖ submenu. Navigate the menu through the following path and you will see the interface of LCD as shown in Figure 8.2-10. Main menu -> VALUES -> CPU METERING-> GEN CURRENT



GEN DIFF CURR Id_Diff_Gen:



000.00 000.00 000.00 Ie



Ir_Diff_Gen:



000.00 000.00 000.00 Ie



I_Term_Gen:



000.00 000.00 000.00 A



I1_Term_Gen:



000.00 A



I2_Term_Gen:



000.00 A



I0_Term_Gen:



000.00 A



I_NP_Gen:



000.00 000.00 000.00 A



I1_NP_Gen:



000.00 A



Figure 8.2-10 LCD display of metering data A scroll bar appears on the right means there are more rows needed to be displayed. Please press key ―▼‖to see the next page and press key ―ESC‖ to exit to the upper level submenu. 8.2.6.2 View state of all binary inputs in CPU and MON The status of binary input comprises of enabling binary inputs and other binary inputs of auxiliary contacts. 226



NR ELECTRIC CO., LTD



Chapter8 Human Machine Interface



For instance, navigate the menu through the following path and you will see the interface of LCD to see binary inputs related to generator‘s protection sampled by the CPU. Main menu -> CPU BI STATE-> -> GEN PROT EBI -> [symbols]



GEN PROT EBI EBI_Diff_Gen:



0



EBI_CoastProt_Gen:



0



EBI_PPF_Gen:



0



EBI_IntTurn_Gen:



0



EBI_BFP_Gen:



0



EBI_ROV_Sta: :



0



EBI_V3rd_Sta:



0



EBI_1PEF_RotWdg:



0



Figure 8.2-11 LCD display of status of binary inputs Press key ―ESC‖ to exit to the submenu. 8.2.6.3 View phase angle Entering into ―PHASE ANGLE‖ submenu, the calculated angles between sampled voltages or between sampled voltages and currents by CPU system will be displayed on LCD as shown below, which can be used to check the correctness of secondary circuit wiring. The angles displayed is that the former value leading to the later one, which varies from -180～＋ 180, as shown as figure below for example.



GEN PH ANG φ_Term_&_NP_Gen:



000 000 000



o



φ_SP1_&_SP2_Gen:



000 000 000



o



φipp_Term_Gen:



000 000 000



o



φipp_NP_Gen:



000 000 000



o



φipp_PwrProt_Gen:



000 000 000



o



φipp_SP1_Gen:



000 000 000



o



φipp_SP2_GenTV1:



000 000 000



o



φvpp_VT1_Term_Gen:



000 000 000



o



Figure 8.2-12 Phase angle displayed on LCD NR ELECTRIC CO., LTD



227



Chapter8 Human Machine Interface



Push ―▼‖ key to show the other information. Push ―ESC‖ key to return to upper level menu. 8.2.6.4 Operation Instruction of Report menu REPORTTRIP REPORT Scroll the cursor to this submenu and press ―ENT‖ key, the LCD will display the latest trip report if it exists, otherwise ―NO TRIP REPORT‖ will appear. If there are several trip reports stored in memory, user can look up historical record one by one by pushing ―▲‖ key. RCS-985G can store up to 24 latest trip reports. When the available space is exhausted, the oldest report is automatically overwritten by the new one. Push either ―ENT‖ or ―ESC‖ key to return to upper level menu. REPORT—ALARM REPORT Scroll the cursor to this submenu and press ―ENT‖ key, the LCD will display the latest alarm report if it exists, otherwise a ―NO ALARM REPORT‖ will appear. If there are several alarm reports stored in memory, user can look up historical record one by one by pushing ―▲‖ key. RCS-985G can store up to 64 latest alarm reports. When the available space is exhausted, the oldest report is automatically overwritten by the new one. Push either ―ENT‖ or ―ESC‖ key to revert to upper level menu. REPORT BI CHG REPORT Scroll the cursor to this submenu and press ―ENT‖ key, the LCD will display the last BI CHG report if it exists, otherwise ―NO BI CHG REPORT‖ will appear. If there are several BI CHG reports stored in memory, user can look up historical record one by one by pushing ―▲‖ key. RCS-985G can store up to 64 latest signaling reports at a resolution of 2ms. When the available space is exhausted, the oldest report is automatically overwritten by the new one. Push either ―ENT‖ or ―ESC‖ key to return to upper level menu. Delete fault records and event records If you want to delete the contents of fault records or event records, you can follow the operating steps. Note you cannot select which kind of records or which one record is to be deleted but only delete all records. Operating steps: Press key ―▲‖ to enter the main menu at first.



228



NR ELECTRIC CO., LTD



N A RI- R EL A Y S



Chapter8 Human Machine Interface



VALUES REPORT PRINT SETTINGS CLOCK VERSION DEBUG



Figure 8.2-13 LCD display of deleting report step 1 Press keys ―+‖, ―-‖, ―+‖, ―-‖, ―ENT‖ in sequence in the main menu to make LCD display Figure 8.2-14.



Confirm to clear all reports? “ENT” to confirm, “ESC”to cancel.



Figure 8.2-14 LCD display of deleting report step 2 Press key ―ENT‖ to delete all records or press key ―ESC‖ to exit to main menu. If key ―ENT‖ is pressed, LCD will display Figure 8.2-15 when equipment is in the process of deleting all records. If key ―ESC‖ is pressed, Figure 8.2-13 will be displayed. LCD will automatically return to Figure 8.2-13 in 3 seconds without pressing any key.



NR ELECTRIC CO., LTD



229



Chapter8 Human Machine Interface



Clearing reports...



Figure 8.2-15 LCD display of deleting report step 3 8.2.6.5 Operation Instruction of PRINT menu PRINTSETTINGS [submenu] Used for printing of settings. The following figure gives an example of the first submenu [ACTIVE SETTINGS].



230



NR ELECTRIC CO., LTD



Chapter8 Human Machine Interface



Figure 8.2-16 Example of settings printing PRINTTRIP REPORT



NR ELECTRIC CO., LTD



231



Chapter8 Human Machine Interface



Used for printing of trip report of protection. User can select the report that he wants to print by pushing ―▲‖ and ―▼‖ keys to select the SOE number. Here is an example.



Figure 8.2-17 Example of tripping report printing



232



NR ELECTRIC CO., LTD



Chapter8 Human Machine Interface



PRINTALARM REPORT Used for printing of alarm. User can select the report that he wants to print by pushing ―▲‖ and ―▼‖ keys. Here is an example.



Figure 8.2-18 Example of alarm report printing PRINT—BI CHG REPORT Used for printing of signaling report. User can select the report that he wants to print by pushing ―▲‖ and ―▼‖ keys. Here is an example.



NR ELECTRIC CO., LTD



233



Chapter8 Human Machine Interface



Figure 8.2-19 Example of BI CHG report printing PRINTPRESENT VALUES Used for printing of present values of relay, including sampled binary inputs, analog quantities and so on. If you want to see the normal recording waveform, please follow the operating steps. Operating steps: First, please go in to the main menu by pressing key ―▲‖. Press key ―▲‖ or ―▼‖to select ―PRINT‖ item by scrolling the cursor upward or downward and then press the ―ENT‖ to the lower level submenu. Then press key ―▲‖ or ―▼‖to select ―PRESENT WAVE‖ by scrolling the cursor upward or downward. Press key ―ENT‖ to enter the lower level submenu. Press ―TRIGGER‖ submenu to start recording. The equipment will record 5-cycle waveform after pressing the key. Please select the other items in the submenu ―PRESENT WAVE‖ by scrolling cursor to print the waveform. Here is an example.



234



NR ELECTRIC CO., LTD



Chapter8 Human Machine Interface



Figure 8.2-20 Example of present values printing 8.2.6.6 Instruction of Settings Manu SettingsEquip Settings To change one of the values of the equipment settings, first navigate the ―SETTING‖ menu to display the relevant cell. Press ―ENT‖ to enter the submenu and then proceed to ―Equip Settings‖ submenu. Keys ―▲‖ and ―▼‖are used to select which kind of the settings to be modified by scrolling the cursor upward or downward. Press key ―◄‖ or ―►‖ to move the cursor to the digit to be modified. Press key ―+‖ and ―–‖ to modify data. Press key ―ESC‖ to return back without modification. By pressing key ―ENT‖, the LCD will prompt user to input password, user should enter password as mentioned in section 8.2.5.2 and quit to default display by pressing ―ESC‖ key. After a time period where the ―HEALTHY‖ LED is extinguished and blocking of relay, the RCS-985G is ready to perform any new operation against faults set according to the new settings, the modification is completed. The following figure shows the path to access this submenu. SettingsProtection settings To change the value of a setting, first navigate the menu to ―SETTING‖ then corresponding submenu to display the relevant cell. Please locate the setting you want to change after entering the right submenu by operating the keypad as described before. Then go on to operate as NR ELECTRIC CO., LTD



235



Chapter8 Human Machine Interface



following steps. Press key ―◄‖ or ―►‖ to move the cursor to the digit to be modified. Pressing key ―+‖ and ―–‖ to change the digit. Press key ―+‖ once to add 1 to the digit and press key ―–‖ once to subtract 1 from the digit. Press key ―ESC‖ to cancel the modification and return to upper level submenu. Press key ―ENT‖ to confirm the modification and the LCD will prompt you to input confirm code.



Password :



Figure 8.2-21 LCD display of inputting password Press keys ―+‖,‖ ―◄‖, ―▲‖ and ―–‖ in sequence to complete the modification. If the password input is wrong, prompt for password will appear again. If there is no operation for 3 seconds, the LCD will return to last display. If the password inputted is right, then the equipment will check setting and Figure 8.2-22 will be displayed temporarily. If there is no error in checking setting, Equipment will modify setting with Figure 8.2-23 displayed temporarily. Then LCD will return to upper level submenu automatically.



Checking settings...



Figure 8.2-22 LCD display of equipment checking setting 236



NR ELECTRIC CO., LTD



Chapter8 Human Machine Interface



Modifying settings...



Figure 8.2-23 LCD display of equipment modifying setting If errors in settings are detected, the LCD will display wrong setting warning for 3 s.



Settings error in I_Pkp_Pcnt_Gen



Figure 8.2-24 LCD display of wrong setting warning Then LCD will display the setting list for the operator to modify the wrong setting. The cursor will stay at the first wrong setting needed to be modified. Note: If the group number or protection system parameter is changed, all protection settings will be invalid and have to be configured again. Attention: Before modifying the protection settings, the active group number in ―Equip Settings‖ should modified first, otherwise what is modified will be applied to the current active group. SettingsSettings Copy NR ELECTRIC CO., LTD



237



Chapter8 Human Machine Interface



The relay stores 2 setting groups from No.0 through No.1. Only present setting group is active, the others are provided for different operating conditions. The equipment settings are shared for the two setting groups, but the protection settings are independent. Generally the equipment is delivered with default settings stored in active setting group ―0‖. The contents of other setting groups may be invalid. Therefore after application-specific settings for group No.0 have been ready, it is necessary to copy settings of group No.0 to No. 1 setting groups, and make some modification afterwards when necessary, so as to avoid entering all settings one by one. Please copy settings through the following steps.



N A RI- R EL A Y S



Press key ―▲‖ to enter the main menu at first.



VALUES REPORT PRINT SETTINGS CLOCK VERSION DEBUG



Figure 8.2-25 LCD display step 1 of copying setting



N A RI- REL AY S



Move cursor to ―SETTINGS‖ item and press key ―ENT‖ or key―►‖ to enter submenu.



VALUES REPORT EQUP SETTINGS PRINT SYSTEM SETTINGS SETTINGS



PROT SETTINGS



CLOCK



SETTINGS COPY



VERSION



CALC SETTINGS



DEBUG



Figure 8.2-26 LCD display step 2 of copying setting Move cursor to ―SETTINGS COPY‖ item and press ―ENT‖ to display following interface.



238



NR ELECTRIC CO., LTD



Chapter8 Human Machine Interface



Copying



Settings



Active Group : 00 Target Group : 00



Warning: Target group will become active automatically after copying!



Figure 8.2-27 LCD display step 3 of copying setting Press key ―+‖ and ―–‖ to change digit where the cursor stays. Pressing key ―+‖ once will add 1 to the digit and pressing key ―–―once will subtract 1 from the digit. (For example: input 01) Press ―ENT‖ the LCD will prompt to input confirm code. Please see the figure below.



Password :



Figure 8.2-28 Password input interface Please press keys ―+‖, ―◄‖, ―▲‖ and ―–‖ in sequence, and then the equipment will copy setting and display following interface.



NR ELECTRIC CO., LTD



239



Chapter8 Human Machine Interface



Copying settings...



Figure 8.2-29 LCD display of equipment copying setting Then the contents of setting group 0 will be totally copied to setting group 1 and present active setting group will be switched to Group1. Note: Press ―ENT‖ to confirm, then settings group 0 will be completely copied to settings group 1 and present active group will be switched to group 01. 8.2.6.7 Clock set Please set the equipment clock as following steps. Navigate the menu: Main menu -> CLOCK After you press key ―ENT‖, the following will be displayed on the LCD.



CLOCK



07-02-05



(YY-MM-DD)



09:08:39



(hh : mm : ss)



Figure 8.2-30 LCD display of device clock 240



NR ELECTRIC CO., LTD



Chapter8 Human Machine Interface



2007 – 02 – 05: shows the date February 5th 2007. 09: 08: 39: shows the time 09:08:39 Press keys ―▲‖, ―▼‖, ―◄‖ and ―►‖ to select the digit to be modified. Press key ―+‖ and ―–‖ to modify data. Pressing key ―+‖ once will add 1 to the digit and pressing key ―–‖ once will subtract 1 from the digit. Press key ―ESC‖ to return to main menu without modification. Press key ―ENT‖ to confirm the modification and return to the main menu. 8.2.6.8 View software version The equipment program has following parts. One is CPU module program, one is MON module program, and another is HMI module program. There are totally independent. Navigate the menu: Main menu -> VERSION After you press key ―ENT‖, the follow will be displayed on the LCD.



VERSION CPUBrd:



RCS-985G310



3.10



2006 - 12 - 12 MONBrd: RCS-985G310



RCS-985G310



10:20



3.10



2006 - 12 - 12 HMI:



2A058F1B 97012006 10:20



3.10



2006 - 12 - 11



08:15



7170 T - 060816



SUBQ_ID: 00026816



Figure 8.2-31 LCD display of software information CPUBrd/MONBrd/HMI: shows CPU/MON/HMI module program information. RCS-985G310: shows the program name of CPU/MON/HMI 3.10: shows the software version number of CPU/MON/HMI. 2A058F1B: shows the CRC (check code) of CPU module program. 97012006: shows the CRC (check code) of MON module program. 7170: shows the CRC (check code) of HMI module program. 2006-12-12 10:20: shows that CPU software creating time is 10:20 Dec 12th 2006.



NR ELECTRIC CO., LTD



241



Chapter8 Human Machine Interface



2006-12-12 10:20: shows that MON software creating time is 10:20 Dec 12th 2006. 2006-12-11 08:15: shows that HMI software creating time is 08:15 Dec 11th 2006. T-060816: shows the project number. SUBQ_ID: 00026816: shows management sequential number of the software Note: What Figure 8.2-31 shows is just an example to introduce the meaning of VERSION, the actual program VERSION is application-specific. Press key ―ESC‖ to return to upper level submenu. 8.2.6.9 DEBUG menu COMM STATUS This submenu is used to monitor communication condition of the equipment with external system. Display of this submenu is as follows:



485A



485B



Data_Received



NO



YES



Frame_Valid



NO



YES



Address_Valid



NO



YES



Data_Sent



NO



YES



Figure 8.2-32 Display of communication status Columns 485A and 485B display communication condition of RS-485 port1 and RS-485 port2 respectively. If communication condition is normal, ―Y‖ will flash in the related position. If there is flashing ―N‖ in the position, it mean there are problems. Please check communication. Table 8.2-6 Items of DEBUG MENU item



status



problem



Data_Received



N



Communication circuit is open or no data is sent from external system.



Frame_Valid



N



Baud rate or protocol is wrong.



242



NR ELECTRIC CO., LTD



Chapter8 Human Machine Interface



Address_Valid



N



Communication address is wrong.



Data_Sent



N



There is problem in the sent message.



―Data_Received‖ means the equipment has received data from external system. If ―N‖ flashes, it means the circuit is open or no data is sent from the external system. ―Frame_Valid‖ means the equipment has received complete frame from the external system. If ―N‖ flashes, it means the configuration of the baud rate or protocol is wrong. ―Address_Valid‖ means the equipment has received related message from external system. If ―N‖ flashes, it means Configuration of the address is wrong. ―Data_Sent‖ means the equipment has sent data to external system. If ―N‖ flashes, it means there is a problem with the message. Communication condition is normal if ―Y‖ of all items flashes. MEMPRY DEBUG The LCD displays real time value in memory of CPU, DSP1 and DSP2. These datas are used mainly for program debugging.



NR ELECTRIC CO., LTD



243



Chapter8 Human Machine Interface



244



NR ELECTRIC CO., LTD



Chapter9 Communications



Chapter9 Communications 9.1



Introduction



This section outlines the remote communications interfaces of the RCS-985G. The protection supports a choice of one of three protocols via the rear communication interface, selected via the model number by setting. The rear EIA (RS) 485 interface is isolated and is suitable for permanent connection of whichever protocol is selected. The advantage of this type of connection is that up to 32 relays can be ‗daisy chained‘ together using a simple twisted pair electrical connection. It should be noted that the descriptions contained within this section do not aim to fully detail the protocol itself. The relevant documentation for the protocol should be referred to for this information. This section serves to describe the specific implementation of the protocol in the relay.



EIA RS-485



The following figure shows typical scheme of communication via RS-485 port of RCS-985G used in substation automation system.



SAS



120Ω



GND



120Ω



RCS-9xx device



RCS-9xx device



RCS-9xx device



Figure 9.1-1 Typical scheme in substation automation system



9.2



Rear communication port of EIA(RS)485



9.2.1 Rear communication port EIA(RS)485 interface The rear EIA(RS)485 communication port is provided by a 3-terminal screw connector located on the back of the relay. See relevant sections for details of the connection terminals. The rear port provides EIA(RS)485 serial data communication and is intended for use with a permanently wired connection to a remote control center.



NR ELECTRIC CO., LTD



245



Chapter9 Communications



1



3



5



7



9



11



A



B



A



B



A



B



13



15



17



19



21



23



TX



RX



4



6



8



10



12



27



29



Earth



Printer PORT



485PORT 485PORT 485PORT



2



25



14



16



18



20



22



24



26



28



30 G



Figure 9.2-1 RS485 port interface The protocol provided by the relay is indicated in the relay menu in the ‗SETTINGS‘ column. Using the keypad and LCD, check the communication protocol being used by the rear port according to the definition of relevant settings described in section 7.



9.2.2 EIA(RS)485 bus The EIA(RS)485 two-wire connection provides a half-duplex fully isolated serial connection to the product. The connection is polarized and whilst the product‘s connection diagrams indicate the polarization of the connection terminals it should be noted that there is no agreed definition of which terminal is which. If the master is unable to communicate with the product, and the communication parameters match, then it is possible that the two-wire connection is reversed.



9.2.3 Bus termination The EIA(RS)485 bus must have 120Ω (Ohm) ½ Watt terminating resistors fitted at either end across the signal wires – see Figure 9.1-1. Some devices may be able to provide the bus terminating resistors by different connection or configuration arrangements, in which case separate external components will not be required. However, this product does not provide such a facility, so if it is located at the bus terminus then an external termination resistor will be required.



9.2.4 Bus connections & topologies The EIA(RS)485 standard requires that each device be directly connected to the physical cable that is the communications bus. Stubs and tees are expressly forbidden, as are star topologies. Loop bus topologies are not part of the EIA(RS)485 standard and are forbidden by it. Two-core screened cable is recommended. The specification of the cable will be dependent on the application, although a multi-strand 0.5mm2 per core is normally adequate. Total cable length must not exceed 1000m. The screen must be continuous and connected to ground at one end, normally at the master connection point; it is important to avoid circulating currents, especially when the cable runs between buildings, for both safety and noise reasons. This product does not provide a signal ground connection. If a signal ground connection is present in the bus cable then it must be ignored, although it must have continuity for the benefit of other devices connected to the bus. At no stage must the signal ground be connected to the cables screen or to the product‘s chassis. This is for both safety and noise reasons.



246



NR ELECTRIC CO., LTD



Chapter9 Communications



Note the following warnings apply: • It is extremely important that the 120Ω termination resistors are fitted. Failure to do so will result in an excessive bias voltage that may damage the devices connected to the bus. • As the field voltage is much higher than that required, NR cannot assume responsibility for any damage that may occur to a device connected to the network as a result of incorrect application of this voltage.



9.3



IEC60870-5-103 communication



9.3.1 Overview of IEC60870-5-103 The IEC specification IEC60870-5-103: Telecontrol Equipment and Systems, Part 5: Transmission Protocols Section 103 defines the use of standards IEC60870-5-1 to IEC60870-5-5 to perform communication with protection equipment. The standard configuration for the IEC60870-5-103 protocol is to use a twisted pair EIA(RS)485 connection over distances up to 1000m. The relay operates as a slave in the system, responding to commands from a master station. To use the rear port with IEC60870-5-103 communication, the relay‘s communication settings must be configured. To do this use the keypad and LCD user interface. Please refer to section 8.2.5 for detail instructions. Three settings apply to the rear port using IEC60870-5-103 that is described below. [Protocol] indicates the communication protocol. [Equip_ID] controls the IEC60870-5-103 address of the relay. Up to 32 relays can be connected to one IEC60870-5-103 spur, and therefore it is necessary for each relay to have a unique address so that messages from the master control station are accepted by one relay only. IEC60870-5-103 uses an integer number between 0 and 254 for the relay address. It is important that no two relays have the same IEC60870-5-103 address. The IEC60870-5-103 address is then used by the master station to communicate with the relay. [Com1_Baud (COM2_Baud)]: controls the baud rate to be used. IEC60870-5-103 communication is asynchronous. It is important that whatever baud rate is selected on the relay is the same as that set on the IEC60870-5-103 master station.



9.3.2 Messages description in IEC60870-5-103 protocol type Messages sent to substation automation system are grouped according to IEC60870-5-103 protocol. Operation elements are sent by ASDU2 (time-tagged message with relative time), and status of Binary Input and Self-Supervision are sent by ASDU1 (time-tagged message). 9.3.2.1 Settings Settings are transferred via Generic Service. Note:



NR ELECTRIC CO., LTD



247



Chapter9 Communications



If the item ―[En_Remote_Cfg]‖ in Equipment Settings is set as 0, to modify settings remotely will not be allowed. Moreover, Equipment Settings & System Settings are not allowed to be modified remotely whether the item ―[En_Remote_Cfg]‖ is true (=1) or not. 9.3.2.2 Trip Reports FUN



INF



227



163



227



FUN



INF



Op_InstDiff_Gen



227



207



Op_OF2_Gen



164



Op_PcntDiff_Gen



229



234



Op_Z1_Gen



227



165



Op_DPFC_Diff_Gen



229



235



Op_Z2_Gen



227



166



Op_InstSPTDiff_Gen



227



210



Op_LossExc1_Gen



227



167



Op_PcntSPTDiff_Gen



227



212



Op_LossExc2_Gen



227



228



Op_Diff_StShut_Gen



227



213



Op_LossExc3_Gen



231



144



Op_UFOC_StShut_Gen



227



219



Op_Ext_OOS_Gen



231



35



Op_StaROV_StShut_Gen



227



220



Op_Int_OOS_Gen



227



172



Op_DPFC_IntTurn_Gen



231



186



Op_BFP11_GCB



227



173



Op_SensTrvDiff_Gen



231



200



Op_BFP12_GCB



227



174



Op_InsensTrvDiff_Gen



227



221



Op_RevP_Gen



227



175



Op_SensIntTurn_Gen



227



224



Op_SeqTrpRevP_Gen



227



176



Op_InsensIntTurn_Gen



231



152



Op_AccEnerg_Gen



227



177



Op_SensROV_Sta



233



149



Op_Flash11_GCB



227



178



Op_InsensROV_Sta



233



150



Op_Flash12_GCB



227



179



Op_V3rdHRatio_Sta



227



168



Op_InstDiff_Exciter



227



180



Op_V3rdHDiff_Sta



227



169



Op_PcntDiff_Exciter



227



181



Op_1PEF_RotWdg



227



170



Op_InstDiff_ET



227



182



Op_2PEF_RotWdg



227



171



Op_PcntDiff_ET



227



183



Op_OvLd_Sta



231



119



Op_OC1_Exc



227



184



Op_InvOvLd_Sta



231



120



Op_OC2_Exc



231



148



Op_NegOC1_Gen



231



108



Op_MechRly1



231



149



Op_NegOC2_Gen



231



109



Op_MechRly2



227



186



Op_InvNegOC_Gen



231



153



Op_MechRly3



227



187



Op_OvLd_RotWdg



231



154



Op_MechRly4



227



188



Op_InvOvLd_RotWdg



231



84



TrpOutp1



227



189



Op_OC1_Gen



231



85



TrpOutp2



227



190



Op_OC2_Gen



231



86



TrpOutp3



237



191



Op_OV1_Gen



231



87



TrpOutp4



235



192



Op_OV2_Sta



231



88



TrpOutp5



227



193



Op_UV_Gen



231



89



TrpOutp6



227



197



Op_OvExc1_Gen



231



90



TrpOutp7



227



198



Op_OvExc2_Gen



231



91



TrpOutp8



227



199



Op_InvOvExc_Gen



231



92



TrpOutp9



227



201



Op_UF1_Gen



231



93



TrpOutp10



227



203



Op_UF2_Gen



231



94



TrpOutp11



227



204



Op_UF3_Gen



231



95



TrpOutp12



248



Item Name



Item Name



NR ELECTRIC CO., LTD



Chapter9 Communications



227



206



Op_OF1_Gen



9.3.2.3 Alarm Reports Sent by ASDU1 (time-tagged message); FUN



INF



227



64



227



Item Name



FUN



INF



Alm_SwOv_VTS1_Gen



227



115



Alm_UF1_Gen



65



Alm_SwOv_VTS2_Gen



227



116



Alm_UF2_Gen



227



66



Alm_BlkV3rdHDiff_VTS1



227



117



Alm_UF3_Gen



227



67



Alm_BlkIntTurn_VTS2



227



119



Alm_OF1_Gen



227



68



Alm_VTS_HVS_Tr



227



120



Alm_OF2_Gen



227



69



Alm_VTS1_Term_Gen



227



121



Alm_RevP_Gen



227



70



Alm_VTS2_Term_Gen



227



86



Alm_CTS_S1_Exc



227



71



Alm_VTS_NP_Gen



227



87



Alm_CTS_S2_Exc



227



72



Alm_DeltVTS1_Term_G en



227



91



Alm_Diff_ET



227



73



Alm_DeltVTS2_Term_G en



227



92



Alm_Diff_Exciter



227



77



Alm_VTS_LossExc_Rot Wdg



227



95



Alm_CTS_Diff_ET



229



112



Alm_Pos_GCB



227



96



Alm_CTS_Diff_Exciter



227



79



Alm_PM_DSP1_CPUBrd



231



104



Alm_MechRly2



231



137



Alm_CTS_BakCT_Gen



231



143



Alm_MechRly4



227



80



Alm_CTS_Term_Gen



231



142



Alm_MechRly3



227



83



Alm_CTS_NP_Gen



231



105



Alm_MechRly1



227



84



Alm_CTS_SP1_Gen



229



215



Alm_Inconsist_MechRly



227



85



Alm_CTS_SP2_Gen



227



135



Alm_PwrLoss_MechRly



227



89



Alm_Diff_Gen



227



137



Alm_PM_DSP2_CPUBrd



227



90



Alm_SPTDiff_Gen



227



194



Alm_RAM_CPUBrd



229



253



Alm_DPFC_IntTurn_Gen



227



195



Alm_ROM_CPUBrd



227



93



Alm_CTS_Diff_Gen



227



196



Alm_EEPROM_CPUBrd



227



94



Alm_CTS_SPTDiff_Gen



227



223



Alm_InvalidSetting



229



213



Alm_BO_OC_Term_Gen



227



81



Alm_ModifiedSetting



231



145



Alm_On_2PEF_RotWdg



227



202



Alm_PwrLoss_Opto



227



100



Alm_Ext_OOS_Gen



229



142



Alm_TripOutput



227



101



Alm_Int_OOS_Gen



227



211



Alm_InnerComm



227



102



Alm_Accel_OOS_Gen



227



82



Alm_DSP_CPUBrd



227



103



Alm_Decel_OOS_Gen



227



214



Alm_PersistFD_CPUBrd



227



105



Alm_LossExc_Gen



227



215



Alm_InconsistFD



227



106



Alm_OvExc_Gen



227



217



Alm_Sample_CPUBrd



227



107



Alm_OvLd_Sta



229



246



Alm_BI_CPUBrd



227



108



Alm_NegOC_Gen



229



205



Alm_RAM_MONBrd



227



109



Alm_OvLd_RotWdg



229



206



Alm_ROM_MONBrd



NR ELECTRIC CO., LTD



Item Name



249



Chapter9 Communications



227



110



Alm_ROV_Sta



229



207



Alm_EEPROM_MONBrd



227



111



Alm_V3rdHRatio_Sta



229



202



Alm_DSP_MONBrd



227



112



Alm_V3rdHDiff_Sta



229



203



Alm_PersistFD_MONBrd



227



113



Alm_Sens1PEF_RotWdg



227



216



Alm_MONBrd



227



114



Alm_1PEF_RotWdg



229



204



Alm_Sample_MONBrd



9.3.2.4 Disturbance ACC(Actual Channel) ACC No.



250



Name



ACC No.



Name



64



Ida_Diff_Gen



98



U0_3rdH_VT1_Term_Gen



65



Idb_Diff_Gen



99



U0_3rdH_NP_Gen



66



Idc_Diff_Gen



100



Ud_3rdH_Sta



67



Ia_Term_Gen



101



U(+)_RotWdg



68



Ib_Term_Gen



102



U(-)_RotWdg



69



Ic_Term_Gen



103



U_RotWdg



70



Ia_NP_Gen



104



I_RotWdg



71



Ib_NP_Gen



105



Reserved



72



Ic_NP_Gen



106



f_Gen



73



Ida_SPTDiff_Gen



107



U_Busbar



74



Idb_SPTDiff_Gen



108



Reserved



75



Idc_SPTDiff_Gen



109



Reserved



76



Ia_SP1_Gen



110



Reserved



77



Ib_SP1_Gen



111



Reserved



78



Ic_SP1_Gen



112



Ida_Diff_Exc



79



Ia_SP2_Gen



113



Idb_Diff_Exc



80



Ib_SP2_Gen



114



Idc_Diff_Exc



81



Ic_SP2_Gen



115



Ia_Corr_S1_Exc



82



Id_TrvDiff_Gen



116



Ib_Corr_S1_Exc



83



P_Gen



117



Ic_Corr_S1_Exc



84



Q_Gen



118



Ia_Corr_S2_Exc



85



Ia_PwrProt_Gen



119



Ib_Corr_S2_Exc



86



Ib_PwrProt_Gen



120



Ic_Corr_S2_Exc



87



Ic_PwrProt_Gen



121



Ia_S1_Exc



88



Ua_VT1_Term_Gen



122



Ib_S1_Exc



89



Ub_VT1_Term_Gen



123



Ic_S1_Exc



90



Uc_VT1_Term_Gen



124



Ia_S2_Exc



91



Ua_VT2_Term_Gen



125



Ib_S2_Exc



92



Ub_VT2_Term_Gen



126



Ic_S2_Exc



93



Uc_VT2_Term_Gen



127



Rg_RotWdg



94



U/F_OvExc_Gen



128



Ia_BakCT_Gen



95



U0_DeltVT1_Term_Gen



129



Ib_BakCT_Gen



96



U0_NP_Gen



130



Ic_BakCT_Gen



97



U0_Longl_Gen



NR ELECTRIC CO., LTD



Chapter9 Communications



9.3.2.5 Metering Sent via Generic Service. The metering values were format as IEEE STD754 R32.23. 9.3.2.6 BinaryInput Sent by ASDU1. (time-tagged message). FUN



INF



227



16



227



Name



231



100



EBI_Trp_MechRly1



EBI_Diff_Gen



227



39



EBI_PPF_Gen



17



EBI_IntTurn_Gen



227



40



EBI_SPTDiff_Gen



227



18



EBI_ROV_Sta



227



41



BI_UrgBrake



227



19



EBI_V3rdH_Sta



227



42



BI_SyncCondenser



227



21



EBI_1PEF_RotWdg



229



249



BI_Reserved3



227



22



EBI_2PEF_RotWdg



229



239



BI_Reserved2



227



23



EBI_OvLd_Sta



227



44



BI_Pwr_Superv



227



24



EBI_NegOC_Gen



229



240



EBI_OvLd_RotWdg



227



25



EBI_LossExc_Gen



231



189



EBI_BFP_GCB



227



26



EBI_OOS_Gen



231



155



EBI_SeqTrpRevP_Gen



227



27



EBI_VoltProt_Gen



231



102



BI_MechRly2



227



28



EBI_OvExc_Gen



231



134



BI_MechRly4



227



29



EBI_PwrProt_Gen



231



133



BI_MechRly3



227



30



EBI_FreqProt_Gen



231



103



BI_MechRly1



227



31



EBI_AccEnerg_Gen



227



58



BI_Pwr_MechRly



227



32



EBI_StShut_Gen



227



59



BI_52b_GCB



231



98



EBI_Diff_Exc



233



32



BI_Reserved4



231



99



EBI_Bak_Exc



231



195



BI_ExtProtTrp



231



129



EBI_Trp_MechRly3



229



236



BI_Reserved1



231



130



EBI_Trp_MechRly4



227



63



BI_Valve_Turbine



231 101 EBI_Trp_MechRly2 9.3.2.7 Blocking of monitoring direction FUN = 227; INF = 20 9.3.2.8 Generic service Group No.



Group Name(English)



9



Gen PPF Bak Prot Settings



1



Setting_Group.



10



Sta EF Prot Settings



2



Equipment Settings



11



RotWdg EF Prot Settings



3



Protection Config



12



Sta OvLd Prot Settings



4



Gen Sys Settings



13



Sta NegOC Prot Settings



5



Exc System Settings



14



Gen LossExc Prot Settings



6



Gen Diff Prot Settings



15



Gen OOS Prot Settings



7



Gen SPTDiff Prot Settings



16



Gen Volt Prot Settings



8



Gen IntTurn Prot Settings



17



Gen OvExc Prot Settings



NR ELECTRIC CO., LTD



251



Chapter9 Communications



9.4



18



Gen Pwr Prot Settings



25



RotWdg OvLd Prot Settings



19



Gen Freq Prot Settings



26



MechRly Prot Settings



20



Gen StShut Prot Settings



65



Gen Metering



21



Gen AccEnerg Prot Settings



66



Exc Metering



22



GCB BFP Settings



23



Exc Diff Prot Settings



24



Exc Bak Prot Settings



MODBUS protocol



9.4.1 Overview The RCS-985G relay support several communications protocols to allow the connection to the equipment such as personal computers, RTUs, SCADA masters, and programmable logic controllers. The Modicon Modbus RTU protocol is the most basic protocol supported by the RCS-985G. Modbus is available via RS485 serial links or via Ethernet (using the Modbus/TCP specification). The following information is provided primarily for users who wish to develop their own master communication drivers and applies to the serial Modbus RTU protocol. The characteristics are listed below: 



Standard: Modicon Modbus Protocol Reference Guide, PI-MBUS-300 Rev.E







Physical Layer Setup：RS485, 1 start bit,8 data bits, no bit for parity,1 stop bit







Link Layer Setup：Only RTU Mode Supported







Frame Length Up limit：256 Bytes







Baud Rate: Configurable







Device Address: Configurable







Parity: no



The following modbus function codes are supported but re-defined by the relay: 02 Read Input Status-Get real-time status (binary) 03 Read Holding Registers- Get Settings 04 Read Input Registers- Get metering values of equipment



9.4.2 Fetch real time status (Binary) Function Code: 02H This function reads the ON/OFF status of discrete inputs in the slave. The status in the response message is packed as one input per bit of the data field. Status is indicated as: 1 = ON; 0 = OFF. The LSB of the first data byte contains the input addressed in the query. The other inputs follow toward the high order end of this byte, and from ‗low order to high order‘ in subsequent bytes.



252



NR ELECTRIC CO., LTD



Chapter9 Communications



Example 1: If the master wants to fetch Trip Information (0000H~0003H), the query frame would be as follows(Suppose the slave address was 1):



01



02



00



00



00



04



79



C9 CRC Hi CRC Lo



Num of Status Lo Num of Status Hi Start Register Addr Lo Start Register Addr Hi Function Code Slave Addr The response fame would be as follows (Suppose the value of 0000H~0003H equal to 1,1,0,1 respectively):



01



02



01



0B



4F



E0



CRC Hi CRC Lo Status Length Function Code Slave Addr Example 2: If the master wants to fetch Trip Information (0002H~000DH), the query frame would be as follows (Suppose the slave address was 1):



NR ELECTRIC CO., LTD



253



Chapter9 Communications



01



02



0C



00



02



00



CF



D9



CRC Hi CRC Lo Num of Status Lo Num of Status Hi Start Register Addr Lo Start Register Addr Hi Function Code Slave Addr The response fame would be as follows (Suppose the value of 0002H~000DH equal to 1,1,0,1,0,0,1,0,1,1,1,0 respectively):



01



02



07



02



4B



FB



BF CRC Hi CRC Lo Status Lo Status Hi



Length Function Code Slave Addr 9.4.2.1 Trip information：―1‖ means trip,‖0‖ for no trip or draw off. Address



254



Item Name



0000H



Op_InstDiff_Gen



0001H



Op_PcntDiff_Gen



0002H



Op_DPFC_Diff_Gen



0003H



Op_InstSPTDiff_Gen



0004H



Op_PcntSPTDiff_Gen



0005H



Op_Diff_StShut_Gen



0006H



Op_UFOC_StShut_Gen



0007H



Op_StaROV_StShut_Gen



0008H



Op_DPFC_IntTurn_Gen



0009H



Op_SensTrvDiff_Gen



000AH



Op_InsensTrvDiff_Gen



000BH



Op_SensIntTurn_Gen NR ELECTRIC CO., LTD



Chapter9 Communications



000CH



Op_InsensIntTurn_Gen



000DH



Op_SensROV_Sta



000EH



Op_InsensROV_Sta



000FH



Op_V3rdHRatio_Sta



0010H



Op_V3rdHDiff_Sta



0011H



Op_1PEF_RotWdg



0012H



Op_2PEF_RotWdg



0013H



Op_OvLd_Sta



0014H



Op_InvOvLd_Sta



0015H



Op_NegOC1_Gen



0016H



Op_NegOC2_Gen



0017H



Op_InvNegOC_Gen



0018H



Op_OvLd_RotWdg



0019H



Op_InvOvLd_RotWdg



001AH



Op_OC1_Gen



001BH



Op_OC2_Gen



001CH



Op_OV1_Gen



001DH



Op_OV2_Gen



001EH



Op_UV_Gen



001FH



Op_OvExc1_Gen



0020H



Op_OvExc2_Gen



0021H



Op_InvOvExc_Gen



0022H



Op_UF1_Gen



0023H



Op_UF2_Gen



0024H



Op_UF3_Gen



0025H



Op_OF1_Gen



0026H



Op_OF2_Gen



0027H



Op_Z1_Gen



0028H



Op_Z2_Gen



0029H



Op_LossExc1_Gen



002AH



Op_LossExc2_Gen



002BH



Op_LossExc3_Gen



002CH



Op_Ext_OOS_Gen



002DH



Op_Int_OOS_Gen



002EH



Op_BFP11_GCB



002FH



Op_BFP12_GCB



0030H



Op_RevP_Gen



0031H



Op_SeqTrpRevP_Gen



0032H



Op_AccEnerg_Gen



0033H



Op_Flash11_GCB



0034H



Op_Flash12_GCB



0035H



Op_InstDiff_Exciter



0036H



Op_PcntDiff_Exciter



NR ELECTRIC CO., LTD



255



Chapter9 Communications



0037H



Op_InstDiff_ET



0038H



Op_PcntDiff_ET



0039H



Op_OC1_Exc



003AH



Op_OC2_Exc



003BH



Op_MechRly1



003CH



Op_MechRly2



003DH



Op_MechRly3



003EH



Op_MechRly4



003FH



TrpOutp1



0040H



TrpOutp2



0041H



TrpOutp3



0042H



TrpOutp4



0043H



TrpOutp5



0044H



TrpOutp6



0045H



TrpOutp7



0046H



TrpOutp8



0047H



TrpOutp9



0048H



TrpOutp10



0049H



TrpOutp11



004AH



TrpOutp12



9.4.2.2 Alarm information：―1‖ means alarm,‖0‖ for no alarm or draw off. Address



256



Item Name



1000H



Alm_SwOv_VTS1_Gen



1001H



Alm_SwOv_VTS2_Gen



1002H



Alm_BlkV3rdHDiff_VTS1



1003H



Alm_BlkIntTurn_VTS2



1004H



Alm_VTS_HVS_Tr



1005H



Alm_VTS1_Term_Gen



1006H



Alm_VTS2_Term_Gen



1007H



Alm_VTS_NP_Gen



1008H



Alm_DeltVTS1_Term_Gen



1009H



Alm_DeltVTS2_Term_Gen



100AH



Alm_VTS_LossExc_RotWdg



100BH



Alm_Pos_GCB



100CH



Alm_PM_DSP1_CPUBrd



100DH



Alm_CTS_BakCT_Gen



100EH



Alm_CTS_Term_Gen



100FH



Alm_CTS_NP_Gen



1010H



Alm_CTS_SP1_Gen



1011H



Alm_CTS_SP2_Gen



1012H



Alm_Diff_Gen



1013H



Alm_SPTDiff_Gen NR ELECTRIC CO., LTD



Chapter9 Communications



1014H



Alm_DPFC_IntTurn_Gen



1015H



Alm_CTS_Diff_Gen



1016H



Alm_CTS_SPTDiff_Gen



1017H



Alm_BO_OC_Term_Gen



1018H



Alm_On_2PEF_RotWdg



1019H



Alm_Ext_OOS_Gen



101AH



Alm_Int_OOS_Gen



101BH



Alm_Accel_OOS_Gen



101CH



Alm_Decel_OOS_Gen



101DH



Alm_LossExc_Gen



101EH



Alm_OvExc_Gen



101FH



Alm_OvLd_Sta



1020H



Alm_NegOC_Gen



1021H



Alm_OvLd_RotWdg



1022H



Alm_ROV_Sta



1023H



Alm_V3rdHRatio_Sta



1024H



Alm_V3rdHDiff_Sta



1025H



Alm_Sens1PEF_RotWdg



1026H



Alm_1PEF_RotWdg



1027H



Alm_UF1_Gen



1028H



Alm_UF2_Gen



1029H



Alm_UF3_Gen



102AH



Alm_OF1_Gen



102BH



Alm_OF2_Gen



102CH



Alm_RevP_Gen



102DH



Alm_CTS_S1_Exc



102EH



Alm_CTS_S2_Exc



102FH



Alm_Diff_ET



1030H



Alm_Diff_Exciter



1031H



Alm_CTS_Diff_ET



1032H



Alm_CTS_Diff_Exciter



1033H



Alm_MechRly2



1034H



Alm_MechRly4



1035H



Alm_MechRly3



1036H



Alm_MechRly1



1037H



Alm_Inconsist_MechRly



1038H



Alm_PwrLoss_MechRly



1039H



Alm_PM_DSP2_CPUBrd



103AH



Alm_RAM_CPUBrd



103BH



Alm_ROM_CPUBrd



103CH



Alm_EEPROM_CPUBrd



103DH



Alm_InvalidSetting



103EH



Alm_ModifiedSetting



NR ELECTRIC CO., LTD



257



Chapter9 Communications



103FH



Alm_PwrLoss_Opto



1040H



Alm_TripOutput



1041H



Alm_InnerComm



1042H



Alm_DSP_CPUBrd



1043H



Alm_PersistFD_CPUBrd



1044H



Alm_InconsistFD



1045H



Alm_Sample_CPUBrd



1046H



Alm_BI_CPUBrd



1047H



Alm_RAM_MONBrd



1048H



Alm_ROM_MONBrd



1049H



Alm_EEPROM_MONBrd



104AH



Alm_DSP_MONBrd



104BH



Alm_PersistFD_MONBrd



104CH



Alm_MONBrd



104DH



Alm_Sample_MONBrd



9.4.2.3 BinaryInput Change Information. 9.4.2.4 ―1‖ means binary change,‖0‖ for no change or draw off. Address



258



Item Name



2000H



EBI_Diff_Gen



2001H



EBI_IntTurn_Gen



2002H



EBI_ROV_Sta



2003H



EBI_V3rdH_Sta



2004H



EBI_1PEF_RotWdg



2005H



EBI_2PEF_RotWdg



2006H



EBI_OvLd_Sta



2007H



EBI_NegOC_Gen



2008H



EBI_LossExc_Gen



2009H



EBI_OOS_Gen



200AH



EBI_VoltProt_Gen



200BH



EBI_OvExc_Gen



200CH



EBI_PwrProt_Gen



200DH



EBI_FreqProt_Gen



200EH



EBI_AccEnerg_Gen



200FH



EBI_StShut_Gen



2010H



EBI_Diff_Exc



2011H



EBI_Bak_Exc



2012H



EBI_Trp_MechRly3



2013H



EBI_Trp_MechRly4



2014H



EBI_Trp_MechRly2



2015H



EBI_Trp_MechRly1



2016H



EBI_PPF_Gen



NR ELECTRIC CO., LTD



Chapter9 Communications



2017H



EBI_SPTDiff_Gen



2018H



BI_UrgBrake



2019H



BI_SyncCondenser



201AH



BI_Reserved3



201BH



BI_Reserved2



201CH



BI_Pwr_Superv



201DH



EBI_OvLd_RotWdg



201EH



EBI_BFP_GCB



201FH



EBI_SeqTrpRevP_Gen



2020H



BI_MechRly2



2021H



BI_MechRly4



2022H



BI_MechRly3



2023H



BI_MechRly1



2024H



BI_Pwr_MechRly



2025H



BI_52b_GCB



2026H



BI_Reserved4



2027H



BI_ExtProtTrp



2028H



BI_Reserved1



2029H



BI_Valve_Turbine



9.4.3 Fetch metering values of equipment Function Code: 04H The metering values in the response message are packed as two bytes per register. For each register, the first byte contains the high order bits and the second contains the low order bits. 9.4.3.1 Gen Metering Address



Analog Name



Unit



0000H



Ida_Diff_Gen (2 decimal places)



Ie



0001H



Idb_Diff_Gen (2 decimal places)



Ie



0002H



Idc_Diff_Gen (2 decimal places)



Ie



0003H



Ira_Diff_Gen (2 decimal places)



Ie



0004H



Irb_Diff_Gen (2 decimal places)



Ie



0005H



Irc_Diff_Gen (2 decimal places)



Ie



0006H



Ia_Term_Gen (2 decimal places)



A



0007H



Ib_Term_Gen (2 decimal places)



A



0008H



Ic_Term_Gen (2 decimal places)



A



0009H



I1_Term_Gen (2 decimal places)



A



000AH



I2_Term_Gen (2 decimal places)



A



000BH



I0_Term_Gen (2 decimal places)



A



000CH



Ia_NP_Gen (2 decimal places)



A



000DH



Ib_NP_Gen (2 decimal places)



A



000EH



Ic_NP_Gen (2 decimal places)



A



NR ELECTRIC CO., LTD



259



Chapter9 Communications



260



000FH



I1_NP_Gen (2 decimal places)



A



0010H



I2_NP_Gen (2 decimal places)



A



0011H



I0_NP_Gen (2 decimal places)



A



0012H



Ia_BakCT_Gen (2 decimal places)



A



0013H



Ib_BakCT_Gen (2 decimal places)



A



0014H



Ic_BakCT_Gen (2 decimal places)



A



0015H



I1_BakCT_Gen (2 decimal places)



A



0016H



I2_BakCT_Gen (2 decimal places)



A



0017H



I0_BakCT_Gen (2 decimal places)



A



0018H



Ia_PwrProt_Gen (2 decimal places)



A



0019H



Ib_PwrProt_Gen (2 decimal places)



A



001AH



Ic_PwrProt_Gen (2 decimal places)



A



001BH



I1_PwrProt_Gen (2 decimal places)



A



001CH



I2_PwrProt_Gen (2 decimal places)



A



001DH



I0_PwrProt_Gen (2 decimal places)



A



001EH



Id_TrvDiff_Gen (2 decimal places)



A



001FH



Id_3rdH_TrvDiff_Gen (2 decimal places)



A



0020H



Ida_SPTDiff_Gen (2 decimal places)



Ie



0021H



Idb_SPTDiff_Gen (2 decimal places)



Ie



0022H



Idc_SPTDiff_Gen (2 decimal places)



Ie



0023H



Ira_SPTDiff_Gen (2 decimal places)



Ie



0024H



Irb_SPTDiff_Gen (2 decimal places)



Ie



0025H



Irc_SPTDiff_Gen (2 decimal places)



Ie



0026H



Ia_Corr_SP1_Gen (2 decimal places)



Ie



0027H



Ib_Corr_SP1_Gen (2 decimal places)



Ie



0028H



Ic_Corr_SP1_Gen (2 decimal places)



Ie



0029H



Ia_Corr_SP2_Gen (2 decimal places)



Ie



002AH



Ib_Corr_SP2_Gen (2 decimal places)



Ie



002BH



Ic_Corr_SP2_Gen (2 decimal places)



Ie



002CH



Ia_SP1_Gen (2 decimal places)



A



002DH



Ib_SP1_Gen (2 decimal places)



A



002EH



Ic_SP1_Gen (2 decimal places)



A



002FH



I1_SP1_Gen (2 decimal places)



A



0030H



I2_SP1_Gen (2 decimal places)



A



0031H



I0_SP1_Gen (2 decimal places)



A



0032H



Ia_SP2_Gen (2 decimal places)



A



0033H



Ib_SP2_Gen (2 decimal places)



A



0034H



Ic_SP2_Gen (2 decimal places)



A



0035H



I1_SP2_Gen (2 decimal places)



A



0036H



I2_SP2_Gen (2 decimal places)



A



0037H



I0_SP2_Gen (2 decimal places)



A



0038H



Ua_VT1_Term_Gen (2 decimal places)



V



0039H



Ub_VT1_Term_Gen (2 decimal places)



V NR ELECTRIC CO., LTD



Chapter9 Communications



003AH



Uc_VT1_Term_Gen (2 decimal places)



V



003BH



U1_VT1_Term_Gen (2 decimal places)



V



003CH



U2_VT1_Term_Gen (2 decimal places)



V



003DH



U0_VT1_Term_Gen (2 decimal places)



V



003EH



Ua_VT2_Term_Gen (2 decimal places)



V



003FH



Ub_VT2_Term_Gen (2 decimal places)



V



0040H



Uc_VT2_Term_Gen (2 decimal places)



V



0041H



U1_VT2_Term_Gen (2 decimal places)



V



0042H



U2_VT2_Term_Gen (2 decimal places)



V



0043H



U0_VT2_Term_Gen (2 decimal places)



V



0044H



Uab_VT1_Term_Gen (2 decimal places)



V



0045H



Ubc_VT1_Term_Gen (2 decimal places)



V



0046H



Uca_VT1_Term_Gen (2 decimal places)



V



0047H



Uab_VT2_Term_Gen (2 decimal places)



V



0048H



Ubc_VT2_Term_Gen (2 decimal places)



V



0049H



Uca_VT2_Term_Gen (2 decimal places)



V



004AH



U0_DeltVT1_Term_Gen (2 decimal places)



V



004BH



U0_ NP_Gen (2 decimal places)



V



004CH



U0_3rdH_VT1_Term_Gen (2 decimal places)



V



004DH



U0_3rdH_NP_Gen (2 decimal places)



V



004EH



Ud_3rdH_Sta (2 decimal places)



V



004FH



U0_Longl_Gen (2 decimal places)



V



0050H



U0_3rdH_Longl_Gen (2 decimal places)



V



0051H



U_Busbar (2 decimal places)



V



0052H



P_Gen (signed/2 decimal places)



%



0053H



Q_Gen (signed/2 decimal places)



%



0054H



Accu_InvOvLd_Sta (2 decimal places)



%



0055H



Accu_InvNegOC_Gen (2 decimal places)



%



0056H



U/F_OvExc_Gen (3 decimal places)



0057H



Accu_InvOvExc_Gen (2 decimal places)



%



0058H



f_Gen (2 decimal places)



Hz



0059H



Accu_UF1_Gen (2 decimal places)



Min



005AH



Accu_UF2_Gen (2 decimal places)



Min



005BH



U1_2ndH_VT1_Term_Gen (2 decimal places)



V



005CH



U2_2ndH_VT1_Term_Gen (2 decimal places)



V



005DH



U(+)_RotWdg (signed/1 decimal place)



V



005EH



U(-)_RotWdg (signed/1 decimal place)



V



005FH



U_RotWdg (signed/1 decimal place)



V



0060H



Rg_RotWdg (2 decimal places)



kΩ



0061H



Location_EF_RotWdg (2 decimal places)



%



0062H



I_RotWdg (signed/integer)



A



0063H



I_Exc (2 decimal places)



A



0064H



Accu_InvOvLd_RotWdg (2 decimal places)



%



NR ELECTRIC CO., LTD



261



Chapter9 Communications



9.4.3.2 Exc Metering Address



Analog Name



Unit



1000H



Ida_Diff_Exc (2 decimal places)



Ie



1001H



Idb_Diff_Exc (2 decimal places)



Ie



1002H



Idc_Diff_Exc (2 decimal places)



Ie



1003H



Ira_Diff_Exc (2 decimal places)



Ie



1004H



Irb_Diff_Exc (2 decimal places)



Ie



1005H



Irc_Diff_Exc (2 decimal places)



Ie



1006H



Ida_2ndH_Exc (2 decimal places)



Ie



1007H



Idb_2ndH_Exc (2 decimal places)



Ie



1008H



Idc_2ndH _Exc (2 decimal places)



Ie



1009H



Ia_Corr_S1_Exc (2 decimal places)



Ie



100AH



Ib_Corr_S1_Exc (2 decimal places)



Ie



100BH



Ic_Corr_S1_Exc (2 decimal places)



Ie



100CH



Ia_Corr_S2_Exc (2 decimal places)



Ie



100DH



Ib_Corr_S2_Exc (2 decimal places)



Ie



100EH



Ic_Corr_S2_Exc (2 decimal places)



Ie



100FH



Ia_S1_Exc (2 decimal places)



A



1010H



Ib_S1_Exc (2 decimal places)



A



1011H



Ic_S1_Exc (2 decimal places)



A



1012H



I1_S1_Exc (2 decimal places)



A



1013H



I2_S1_Exc (2 decimal places)



A



1014H



I0_S1_Exc (2 decimal places)



A



1015H



Ia_S2_Exc (2 decimal places)



A



1016H



Ib_S2_Exc (2 decimal places)



A



1017H



Ic_S2_Exc (2 decimal places)



A



1018H



I1_S2_Exc (2 decimal places)



A



1019H



I2_S2_Exc (2 decimal places)



A



101AH



I0_S2_Exc (2 decimal places)



A



9.4.4 Fetch settings value of equipment Function Code: 03H 9.4.4.1 Equipment Settings Address



262



Setting Name



Unit



0000H



Setting_Group



0001H



Equip_ID(ASCII Hi Word)



0002H



Equip_ID(ASCII Mi Word)



0003H



Equip_ID(ASCII Lo Word)



0004H



Comm_Addr(integer)



0005H



COM1_Baud(integer)



bps



0006H



COM2_Baud(integer)



bps



NR ELECTRIC CO., LTD



Chapter9 Communications



0007H



Printer_Baud(integer)



0008H



Protocol



bps



Bit0: COM1 870-5-103 Protocal Bit1: COM1 LFP Protocal Bit2: COM1 Modbus Protocal Bit4: COM2 870-5-103 Protocal Bit5: COM2 LFP Protocal Bit6: COM2 Modbus Protocal



0009H



Logic settings



Bit0: En_Auto_Print Bit1: En_Net_Print Bit3: En_Remote_Cfg Bit4: GPS_Pulse



9.4.4.2 System Settings 9.4.4.2.1 Protection Configuration Address 1000H



Setting Name Protection Config Word 1



Unit



Bit0:En_Diff_Gen Bit1:En_SPTDiff_Gen Bit2:En_IntTurn_Gen Bit3:En_PPF_Gen Bit4:En_EF_Sta Bit5:Unused_Bit Bit6:En_EF_RotWdg Bit7:En_OvLd_Sta Bit8:En_NegOC_Gen Bit9:En_LossExc_Gen Bit10:En_OOS_Gen Bit11:En_VoltProt_Gen Bit12:En_OvExc_Gen Bit13:En_PwrProt_Gen Bit14:En_FreqProt_Gen Bit15:En_StShut_Gen



1001H



Protection Config Word 2



Bit0:En_AccEnerg_Gen Bit1:En_BFP_GCB Bit2:En_Diff_Exc Bit3:En_Bak_Exc Bit4:En_OvLd_RotWdg Bit5:En_MechRly Bit6:En_VTComp_Term_Gen



9.4.4.2.2 Gen System Settings Address



Setting Name



Unit



1002H



fn_Gen (integer)



Hz



1003H



Pn_Gen (1 decimal place)



MW



NR ELECTRIC CO., LTD



263



Chapter9 Communications



1004H



PF_Gen (2 decimal places)



1005H



U1n_Gen (2 decimal places)



kV



1006H



U1n_VT_Term_Gen (2 decimal places)



kV



1007H



U2n_VT_Term_Gen (integer)



V



1008H



U2n_DeltVT_Term_Gen (integer)



V



1009H



U1n_VT_NP_Gen (2 decimal places)



kV



100AH



U2n_VT_NP_Gen (2 decimal places)



V



100BH



I1n_CT_Term_Gen (integer)



A



100CH



I2n_CT_Term_Gen (integer)



A



100DH



k_SP1_Gen (2 decimal places)



%



100EH



k_SP2_Gen (2 decimal places)



%



100FH



I1n_CT_SP1_Gen (integer)



A



1010H



I2n_CT_SP1_Gen (integer)



A



1011H



I1n_CT_SP2_Gen (integer)



A



1012H



I2n_CT_SP2_Gen (integer)



A



1013H



I1n_CT_TrvDiff_Gen (integer)



A



1014H



I2n_CT_TrvDiff_Gen (integer)



A



1015H



I1n_RotWdg (integer)



A



1016H U2n_Shunt_RotWdg (2 decimal places) 9.4.4.2.3 Exc System Settings Address



mV



Setting Name



Unit



1017H



fn_Exc (integer)



Hz



1018H



Sn_Exc (2 decimal places)



MVA



1019H



U1n_S1_Exc (2 decimal places)



kV



101AH



U1n_S2_Exc (2 decimal places)



kV



101BH



I1n_CT_S1_Exc (integer)



A



101CH



I2n_CT_S1_Exc (integer)



A



101DH



I1n_CT_S2_Exc (integer)



A



101EH



I2n_CT_S2_Exc (integer)



A



101FH



Logic settings



Bit0:Opt_Exc Bit1:Yy12_Conn_ET Bit2:Dd12_Conn_ET Bit3:Dy11_Conn_ET Bit4:Yd11_Conn_ET Bit5:Dy1_Conn_ET



9.4.4.3 Prot Settings 9.4.4.3.1 Gen Diff Prot Settings Address



264



Setting Name



Unit



2000H



I_Pkp_PcntDiff_Gen (2 decimal places)



Ie



2001H



I_InstDiff_Gen (2 decimal places)



Ie



2002H



Slope1_PcntDiff_Gen (2 decimal places)



NR ELECTRIC CO., LTD



Chapter9 Communications



2003H



Slope2_PcntDiff_Gen (2 decimal places)



2004H



TrpLog_Diff_Gen



2005H



Logic settings



Bit0:En_InstDiff_Gen Bit1:En_PcntDiff_Gen Bit2:En_DPFC_Diff_Gen Bit3:Opt_CTS_Blk_PcntDiff_Gen



9.4.4.3.2 Gen SPTDiff Prot Settings Address



Setting Name



Unit



2006H



I_Pkp_PcntSPTDiff_Gen (2 decimal places)



Ie



2007H



I_InstSPTDiff_Gen (2 decimal places)



Ie



2008H



Slope1_PcntSPTDiff_Gen (2 decimal places)



2009H



Slope2_PcntSPTDiff_Gen (2 decimal places)



200AH



TrpLog_SPTDiff_Gen



200BH



Logic settings



Bit0:En_InstSPTDiff_Gen Bit1:En_PcntSPTDiff_Gen Bit2:Opt_CTS_PcntSPTDiff_Gen



9.4.4.3.3 Gen IntTurn Prot Settings Address



Setting Name



Unit



200CH



I_SensTrvDiff_Gen (2 decimal places)



A



200DH



I_InsensTrvDiff_Gen (2 decimal places)



A



200EH



t_TrvDiff_Gen (2 decimal places)



S



200FH



V_SensROV_Longl_Gen (2 decimal places)



V



2010H



V_InsensROV_Longl_Gen (2 decimal places)



V



2011H



t_ROV_Longl_Gen (2 decimal places)



S



2012H



TrpLog_IntTurn_Gen



2013H



Logic settings



Bit0:En_SensTrvDiff_Gen Bit1:En_InsensTrvDiff_Gen Bit2:En_SensROV_Longl_Gen Bit3:En_InsensROV_Longl_Gen Bit4:En_DPFC_IntTurn_Gen



9.4.4.3.4 Gen PPF Bak Prot Settings Address



Setting Name



Unit



2014H



V_NegOV_VCE_Gen (2 decimal places)



V



2015H



Vpp_UV_VCE_Gen (2 decimal places)



V



2016H



I_OC1_Gen (2 decimal places)



A



2017H



t_OC1_Gen (2 decimal places)



S



2018H



TrpLog_OC1_Gen



2019H



I_OC2_Gen (2 decimal places)



A



201AH



t_OC2_Gen (2 decimal places)



S



201BH



TrpLog_OC2_Gen



NR ELECTRIC CO., LTD



265



Chapter9 Communications



201CH



Z1_Fwd_Gen (2 decimal places)



Ω



201DH



Z1_Rev_Gen (2 decimal places)



Ω



201EH



t_Z1_Gen (2 decimal places)



S



201FH



TrpLog_Z1_Gen



2020H



Z2_Fwd_Gen (2 decimal places)



Ω



2021H



Z2_Rev_Gen (2 decimal places)



Ω



2022H



t_Z2_Gen (2 decimal places)



S



2023H



TrpLog_Z2_Gen



2024H



I_BO_OC_Gen (2 decimal places)



2025H



Logic settings



A



Bit0:En_VCE_Ctrl_OC1_Gen Bit1:En_VCE_Ctrl_OC2_Gen Bit2:Opt_VTS_Ctrl_OC_Gen Bit3:Opt_ExcMode_Gen Bit4:En_BO_OC_Gen



9.4.4.3.5 Sta EF Prot Settings Address



Setting Name



Unit



2026H



V_SensROV_Sta (2 decimal places)



V



2027H



V_InsensROV_Sta (2 decimal places)



V



2028H



t_ROV_Sta (2 decimal places)



S



2029H



k_V3rdHRatio_PreSync_Sta (2 decimal places)



202AH



k_V3rdHRatio_PostSync_Sta (2 decimal places)



202BH



k_V3rdHDiff_Sta (2 decimal places)



202CH



t_V3rdH_Sta (2 decimal places)



202DH



TrpLog_EF_Sta



202EH



Logic settings



S



Bit0:En_Alm_ROV_Sta Bit1:En_Trp_ROV_Sta Bit2:En_Alm_V3rdHRatio_Sta Bit3:En_Alm_V3rdHDiff_Sta Bit4:En_Trp_V3rdHRatio_Sta Bit5:En_Trp_InsensRov_Sta



9.4.4.3.6 RotWdg EF Prot Settings Address



Setting Name



Unit



202FH



R_Sens1PEF_RotWdg (2 decimal places)



kΩ



2030H



R_1PEF_RotWdg (2 decimal places)



kΩ



2031H



t_1PEF_RotWdg (2 decimal places)



S



2032H



V2ndH_VCE_2PEF_RotWdg (2 decimal places)



v



2033H



t_2PEF_RotWdg (2 decimal places)



S



2034H



TrpLog_EF_RotWdg



2035H



Logic settings



Bit0:En_Alm_Sens1PEF_RotWdg Bit1:En_Alm_1PEF_RotWdg Bit2:En_Trp_1PEF_RotWdg



266



NR ELECTRIC CO., LTD



Chapter9 Communications



Bit3:En_2PEF_RotWdg Bit4:En_VCE_2PEF_RotWdg 9.4.4.3.7 Sta OvLd Prot Settings Address



Setting Name



Unit



2036H



I_OvLd_Sta (2 decimal places)



A



2037H



t_OvLd_Sta (2 decimal places)



S



2038H



TrpLog_OvLd_Sta



2039H



I_Alm_OvLd_Sta (2 decimal places)



A



203AH



t_Alm_OvLd_Sta (2 decimal places)



S



203BH



I_InvOvLd_Sta (2 decimal places)



A



203CH



tmin_InvOvLd_Sta (2 decimal places)



S



203DH



A_Therm_Sta (2 decimal places)



203EH



K_Disspt_Sta (2 decimal places)



203FH



TrpLog_InvOvLd_Sta



9.4.4.3.8 Gen NegOC Prot Settings Address



Setting Name



Unit



2040H



I_NegOC1_Gen (2 decimal places)



A



2041H



t_NegOC1_Gen (2 decimal places)



S



2042H



TrpLog_NegOC1_Gen



2043H



I_NegOC2_Gen (2 decimal places)



A



2044H



t_NegOC2_Gen (2 decimal places)



S



2045H



TrpLog_NegOC2_Gen



2046H



I_Alm_NegOC_Gen (2 decimal places)



A



2047H



t_Alm_NegOC_Gen (2 decimal places)



S



2048H



I_InvNegOC_Gen (2 decimal places)



A



2049H



I_Neg_Perm_Gen (2 decimal places)



A



204AH



tmin_InvNegOC_Gen (2 decimal places)



S



204BH



A_Therm_RotBody (2 decimal places)



204CH



TrpLog_InvNegOC_Gen



9.4.4.3.9 Gen LossExc Prot Settings Address



Setting Name



Unit



204DH



X1_LossExc_Gen (2 decimal places)



Ω



204EH



X2_LossExc_Gen (2 decimal places)



Ω



204FH



Q_RevQ_LossExc_Gen (2 decimal places)



%



2050H



V_RotUV_LossExc_Gen (2 decimal places)



V



2051H



Un_RotNoLoad_LossExc_Gen (2 decimal places)



V



2052H



k_RotUV_LossExc_Gen (2 decimal places)



2053H



V_UV_LossExc_Gen (2 decimal places)



V



2054H



P_OvPwr_LossExc_Gen (2 decimal places)



%



2055H



t_LossExc1_Gen (2 decimal places)



S



NR ELECTRIC CO., LTD



267



Chapter9 Communications



2056H



t_LossExc2_Gen (2 decimal places)



S



2057H



t_LossExc3_Gen (1 decimal place)



S



2058H



TrpLog_LossExc1_Gen



2059H



TrpLog_LossExc2_Gen



205AH



TrpLog_LossExc3_Gen



205BH



Logic settings



Bit0:En_Z_LossExc1_Gen Bit1:En_RotUV_LossExc1_Gen Bit2:En_P_LossExc1_Gen Bit3:En_UV_LossExc2_Gen Bit4:En_Z_LossExc2_Gen Bit5:En_RotUV_LossExc2_Gen Bit6:En_Z_LossExc3_Gen Bit7:En_RotUV_LossExc3_Gen Bit8:En_Alm_LossExc1_Gen Bit9:Opt_Z_LossExc_Gen Bit10:En_RevQ_LossExc_Gen Bit11:Opt_UV_LossExc_Gen



9.4.4.3.10 Gen OOS Prot Settings Address



Setting Name



Unit



205CH



Za_OOS_Gen (2 decimal places)



Ω



205DH



Zb_OOS_Gen (2 decimal places)



Ω



205EH



Zc_OOS_Gen (2 decimal places)



Ω



205FH



φ_Reach_OOS_Gen (2 decimal places)



°



2060H



φ_Inner_OOS_Gen (2 decimal places)



°



2061H



n_Slip_Ext_OOS_Gen (integer)



2062H



n_Slip_Int_OOS_Gen (integer)



2063H



Ibrk_GCB (2 decimal places)



2064H



TrpLog_OOS_Gen



2065H



Logic settings



A



Bit0:En_Alm_Ext_OOS_Gen Bit1:En_Trp_Ext_OOS_Gen Bit2:En_Alm_Int_OOS_Gen Bit3:En_Trp_Int_OOS_Gen



9.4.4.3.11 Gen Volt Prot Settings Address



268



Setting Name



Unit



2066H



V_OV1_Gen (2 decimal places)



V



2067H



t_OV1_Gen (2 decimal places)



S



2068H



TrpLog_OV1_Gen



2069H



V_OV2_Gen (2 decimal places)



V



206AH



t_OV2_Gen (2 decimal places)



S



206BH



TrpLog_OV2_Gen



206CH



V_UV_Gen (2 decimal places)



V NR ELECTRIC CO., LTD



Chapter9 Communications



206DH



t_UV_Gen (2 decimal places)



206EH



TrpLog_UV_Gen



S



9.4.4.3.12 Gen OvExc Prot Settings Address



Setting Name



206FH



k_OvExc1_Gen (2 decimal places)



2070H



t_OvExc1_Gen (1 decimal place)



2071H



TrpLog_OvExc1_Gen



2072H



k_OvExc2_Gen (2 decimal places)



2073H



t_OvExc2_Gen (1 decimal place)



2074H



TrpLog_OvExc2_Gen



2075H



k_Alm_OvExc_Gen (2 decimal places)



2076H



t_Alm_OvExc_Gen (1 decimal place)



2077H



k0_InvOvExc_Gen (2 decimal places)



2078H



t0_InvOvExc_Gen (1 decimal place)



2079H



k1_InvOvExc_Gen (2 decimal places)



207AH



t1_InvOvExc_Gen (1 decimal place)



207BH



k2_InvOvExc_Gen (2 decimal places)



207CH



t2_InvOvExc_Gen (1 decimal place)



207DH



k3_InvOvExc_Gen (2 decimal places)



207EH



t3_InvOvExc_Gen (1 decimal place)



207FH



k4_InvOvExc_Gen (2 decimal places)



2080H



t4_InvOvExc_Gen (1 decimal place)



2081H



k5_InvOvExc_Gen (2 decimal places)



2082H



t5_InvOvExc_Gen (1 decimal place)



2083H



k6_InvOvExc_Gen (2 decimal places)



2084H



t6_InvOvExc_Gen (1 decimal place)



2085H



k7_InvOvExc_Gen (2 decimal places)



2086H



t7_InvOvExc_Gen (1 decimal place)



2087H



TrpLog_InvOvExc_Gen



Unit S



S



S S S S S S S S S



9.4.4.3.13 Gen Pwr Prot Settings Address



Setting Name



Unit



2088H



P_RevP_Gen (2 decimal places)



%



2089H



t_Alm_RevP_Gen (1 decimal place)



S



208AH



t_Trp_RevP_Gen (1 decimal place)



S



208BH



TrpLog_RevP_Gen



208CH



P_SeqTrpRevP_Gen (2 decimal places)



%



208DH



t_SeqTrpRevP_Gen (2 decimal places)



S



208EH



TrpLog_SeqTrp_RevP_Gen



9.4.4.3.14 Gen Freq Prot Settings Address NR ELECTRIC CO., LTD



Setting Name



Unit 269



Chapter9 Communications



208FH



f_UF1_Gen (2 decimal places)



Hz



2090H



t_Accu_UF1_Gen (2 decimal places)



M



2091H



f_UF2_Gen (2 decimal places)



Hz



2092H



t_UF2_Gen (2 decimal places)



M



2093H



f_UF3_Gen (2 decimal places)



Hz



2094H



t_UF3_Gen (2 decimal places)



S



2095H



TrpLog_UF_Gen



2096H



f_OF1_Gen (2 decimal places)



Hz



2097H



t_OF1_Gen (2 decimal places)



M



2098H



f_OF2_Gen (2 decimal places)



Hz



2099H



t_OF2_Gen (2 decimal places)



S



209AH



TrpLog_OF_Gen



209BH



Logic settings



Bit0:En_Alm_UF1_Gen Bit1:Unused_Bit Bit2:En_Trp_UF1_Gen Bit3:Unused_Bit Bit4:En_Alm_UF2_Gen Bit5:En_Trp_UF2_Gen Bit6:En_Alm_UF3_Gen Bit7:En_Trp_UF3_Gen Bit8:En_Alm_OF1_Gen Bit9:En_Trp_OF1_Gen Bit10:En_Alm_OF2_Gen Bit11:En_Trp_OF2_Gen



9.4.4.3.15 Gen StShut Prot Settings Address



Setting Name



Unit



209CH



f_UF_StShut_Gen (2 decimal places)



Hz



209DH



I_GenDiff_StShut_Gen (2 decimal places)



Ie



209EH



TrpLog_Diff_StShut_Gen



209FH



I_UFOC_StShut_Gen (2 decimal places)



A



20A0H



t_UFOC_StShut_Gen (2 decimal places)



S



20A1H



TrpLog_OC_StShut_Gen



20A2H



V_StaROV_StShut_Gen (2 decimal places)



V



20A3H



t_StaROV_StShut_Gen (2 decimal places)



S



20A4H



TrpLog_StaROV_StShut_Gen



20A5H



Logic settings



Bit0:En_GenDiff_StShut_Gen Bit1:En_UFOC_StShut_Gen Bit2:En_StaROV_StShut_Gen



9.4.4.3.16 Gen AccEnerg Prot Settings Address 20A6H 270



Setting Name f_UF_AccEnerg_Gen (2 decimal places)



Unit Hz NR ELECTRIC CO., LTD



Chapter9 Communications



20A7H



I_OC_AccEnerg_Gen (2 decimal places)



A



20A8H



t_AccEnerg_Gen (2 decimal places)



S



20A9H



TrpLog_AccEnerg_Gen



20AAH



I_NegOC_Flash_GCB (2 decimal places)



A



20ABH



t_Flash11_GCB (2 decimal places)



S



20ACH



TrpLog_Flash11_GCB



20ADH



t_Flash12_GCB (2 decimal places)



20AEH



TrpLog_Flash12_GCB



20AFH



Logic settings



S



Bit0:En_UF_Ctrl_AccEnerg_Gen Bit1:En_CB_Ctrl_AccEnerg_Gen



9.4.4.3.17 GCB BFP Settings Address



Setting Name



Unit



20B0H



I_BFP_GCB (2 decimal places)



A



20B1H



I_ROC_BFP_GCB (2 decimal places)



A



20B2H



I_NegOC_BFP_GCB (2 decimal places)



A



20B3H



t_BFP11_GCB (2 decimal places)



S



20B4H



TrpLog_BFP11_GCB



20B5H



t_BFP12_GCB (2 decimal places)



20B6H



TrpLog_BFP12_GCB



20B7H



Logic settings



S



Bit0:En_ROC_BFP_GCB Bit1:En_NegOC_BFP_GCB Bit2:En_ExtTrpCtrlBFP_GCB Bit3:En_CB_Ctrl_BFP_GCB



9.4.4.3.18 Exc Diff Prot Settings Address



Setting Name



Unit



20B8H



I_Pkp_PcntDiff_Exc (2 decimal places)



Ie



20B9H



I_InstDiff_Exc (2 decimal places)



Ie



20BAH



Slope1_PcntDiff_Exc (2 decimal places)



20BBH



Slope2_PcntDiff_Exc (2 decimal places)



20BCH



k_Harm_PcntDiff_Exc (2 decimal places)



20BDH



TrpLog_Diff_Exc



20BEH



Logic settings



Bit0:En_InstDiff_Exc Bit1:En_PcntDiff_Exc Bit2:Opt_Inrush_Ident_Exc Bit3:Opt_CTS_Blk_PcntDiff_Exc



9.4.4.3.19 Exc Bak Prot Settings Address



Setting Name



Unit



20BFH



I_OC1_Exc (2 decimal places)



A



20C0H



t_OC1_Exc (2 decimal places)



S



20C1H



TrpLog_OC1_Exc



NR ELECTRIC CO., LTD



271



Chapter9 Communications



20C2H



I_OC2_Exc (2 decimal places)



A



20C3H



t_OC2_Exc (2 decimal places)



S



20C4H



TrpLog_OC2_Exc



9.4.4.3.20 RotWdg OvLd Prot Settings Address



Setting Name



Unit



20C5H



I_OvLd_RotWdg (2 decimal places)



A



20C6H



t_OvLd_RotWdg (2 decimal places)



S



20C7H



TrpLog_OvLd_RotWdg



20C8H



I_Alm_OvLd_RotWdg (2 decimal places)



A



20C9H



t_Alm_OvLd_RotWdg (2 decimal places)



S



20CAH



I_InvOvLd_RotWdg (2 decimal places)



A



20CBH



tmin_InvOvLd_RotWdg (2 decimal places)



S



20CCH



A_Therm_RotWdg (2 decimal places)



20CDH



Ib_InvOvLd_RotWdg (2 decimal places)



20CEH



TrpLog_InvOvLd_RotWdg



20CFH



Logic settings



A



Bit0:Opt_AC_Input_RotWdg Bit1:Opt_DC_Input_RotWdg Bit2:Opt_AC_Input_S1_RotWdg Bit3:Opt_AC_Input_S2_RotWdg



9.4.4.3.21 MechRly Prot Settings Address



Setting Name



20D0H



t_MechRly1 (1 decimal place)



20D1H



TrpLog_MechRly1



20D2H



t_MechRly2 (1 decimal place)



20D3H



TrpLog_MechRly2



20D4H



t_MechRly3 (1 decimal place)



20D5H



TrpLog_MechRly3



20D6H



t_MechRly4 (1 decimal place)



20D7H



TrpLog_MechRly4



Unit S S S S



9.4.5 Diagnostics (Function Code: 08H) Modbus function 08 provides a series of tests for checking the communication system between the master and slave, or for checking various internal error conditions within the slave. The function uses a two–byte subfunction code field in the query to define the type of test to be performed. The slave echoes both the function code and subfunction code in a normal response. The listing below shows the subfunction codes supported by the equipment. Code



Name



04H



Force Listen Only Mode



00H



Return Query Data



0BH



Return Bus Message Count



01H



Restart Comm Option



0CH



Return Bus Comm. Error Count



272



NR ELECTRIC CO., LTD



Chapter9 Communications



0DH



Return Bus Exception Error Cnt



0EH



Return Slave Message Count



0FH



Return Slave No Response Cnt



9.4.6 Exception Responses Except for broadcast messages, when a master device sends a query to a slave device it expects a normal response but If the slave receives the query without a communication error, but cannot handle it (for example, if the request is to read a non–existent coil or register), the slave will return an exception response informing the master of the nature of the error. The listing below shows the exception codes supported by the equipment. Code



Description



01H



Illegal Function



02H



Illegal Data Address



9.5



03H



Illegal Data Value



07H



Negative Acknowledge



EIA(RS)232 Interface



The front communication port is provided by a DB9 female D-type connector located under the small hinged cover on the front panel. It provides RS232 serial data communication and is intended for use with a PC locally to the relay (up to 15m distance). This port supports the courier communication protocol only. Courier is the communication language developed by NR to allow communication with its range of protection relays. The front port is particularly designed for use with relays settings program RCSPC which is a Windows-based software package. The pin connections of relay‘s DB9 front port are as follows: Pin No.2



Tx Transmit data



Pin No.3



Rx Receive data



Pin No.5



common



None of the other pins are connected in the relays. The relays should be connected to the serial port of a PC, usually called as COM1 or COM2. The serial port pin connections, which is DB9 male, is described below (if in doubt check you PC manual): Pin No.2



Rx Transmit data



Pin No.3



Tx Receive data



Pin No.5



common



For successful data communication, the Tx pin on the relays must be connected to the Rx pin on the PC, and Rx pin on the relay must be connected to Tx pin on the PC as shown in Figure 9.5-1. Note: The baud rate for this port is fixed at 9600 bps.



NR ELECTRIC CO., LTD



273



Chapter9 Communications



9 pin front communication port 1



3



2



5



4



1



6



3



2



7



5



4



9



8



7



6



9



8



serial communication port (COM1 or COM2) of local PC



Figure 9.5-1 Rs232 Faceplate Port Connection



9.6



Communication with printer



When communicating locally with a printer using the rear series port, a special connection cable is necessary which is provided by manufacturer of the equipment. There are no parameters needed to be set in RCS-985G for communication with the printer. The printer‘s port used for communication with RCS-985G is a serial port of which the pin definition is a little different with normal RS232 port as shown as below: 9 pin front communication port 1



2



6



1



3



7



2



6



4



9



8



5



4



3



7



5



8



9



serial communication port ( COM1 or COM2) of local PC



Figure 9.6-1 Rs232 Faceplate Port Connection



9.7



Communication with External GPS pulse Source



The clock function (Calendar clock) is used for time-tagging for the following purposes: 274



NR ELECTRIC CO., LTD



Chapter9 Communications



---Event recording ---Fault recording ---Present recording ---Self-supervision When the relays are connected to the GPS clock, all the relay clocks are synchronized with the external time standard. There are two way to adjust the relay clock. ---Time synchronization via RS-485 serial port ---Time synchronization via binary input



NR ELECTRIC CO., LTD



275



Chapter9 Communications



276



NR ELECTRIC CO., LTD



Chapter10 Installation



Chapter10 Installation 10.1



Receipt of Relays



Upon receipt, relays should be examined immediately to ensure no external damage has been sustained in transit. If damage has been sustained, a claim should be made to the transport contractor and NR should be promptly notified. Relays that are supplied unmounted and not intended for immediate installation should be returned to their protective bags and delivery carton. Section 10.3 of this chapter gives more information about the storage of relays.



10.2



Handling of Electronic Equipment



A person‘s normal movements can easily generate electrostatic potentials of several thousand volts. Discharge of these voltages into semiconductor devices when handling electronic circuits can cause serious damage that although not always immediately apparent will reduce the reliability of the circuit. The relay‘s electronic circuits are protected from electrostatic discharge when housed in the case. Do not expose them to risk by removing the front panel or printed circuit boards unnecessarily. Each printed circuit board incorporates the highest practicable protection for its semiconductor devices. However, if it becomes necessary to remove a printed circuit board, the following precautions should be taken to preserve the high reliability and long life for which the relay has been designed and manufactured. Before removing a printed circuit board, ensure that you are at the same electrostatic potential as the equipment by touching the case. Handle analog input modules by the front panel, frame or edges of the circuit boards. Printed circuit boards should only be handled by their edges. Avoid touching the electronic components, printed circuit tracks or connectors. Do not pass the module to another person without first ensuring you are both at the same electrostatic potential. Shaking hands achieves equipotential. Place the module on an anti-static surface, or on a conducting surface that is at the same potential as you. If it is necessary to store or transport printed circuit boards removed from the case, place them individually in electrically conducting anti-static bags. In the unlikely event that you are making measurements on the internal electronic circuitry of a relay in service, it is preferable that you are earthed to the case with a conductive wrist strap. Wrist straps should have a resistance to ground between 500kΩ to 10MΩ. If a wrist strap is not available you should maintain regular contact with the case to prevent a build-up of electrostatic potential. Instrumentation which may be used for making measurements should also be earthed to the case whenever possible. More information on safe working procedures for all electronic equipment can be found in BS EN NR ELECTRIC CO., LTD



277



Chapter10 Installation



100015: Part 1:1992. It is strongly recommended that detailed investigations on electronic circuitry or modification work should be carried out in a special handling area such as described in the British Standard document.



10.3



Storage



If relays are not to be installed immediately upon receipt, they should be stored in a place free from dust and moisture in their original cartons. Where de-humidifier bags have been included in the packing they should be retained. To prevent battery drain during transportation and storage, a battery isolation strip is fitted during manufacture. With the lower access cover open, presence of the battery isolation strip can be checked by a red tab protruding from the positive polarity side. Care should be taken on subsequent unpacking that any dust, which has collected on the carton, does not fall inside. In locations of high humidity the carton and packing may become impregnated with moisture and the de-humidifier crystals will lose their efficiency. Prior to installation, relays should be stored at a temperature of between –25°C to +70°C (-13°F to +158°F).



10.4



Unpacking



Care must be taken when unpacking and installing the relays so that none of the parts are damaged and additional components are not accidentally left in the packing or lost. Ensure that any User‘s CDROM or technique documentation is NOT discarded – this should accompany the relay to its destination substation. Note: With the lower access cover open, the red tab of the battery isolation strip will be seen protruding from the positive (―+‖) side of the battery compartment. Do not remove this strip because it prevents battery drain during transportation and storage and will be removed as part of the commissioning tests. Relays must only be handled by skilled persons. The site should be well lit to facilitate inspection, clean, dry and reasonably free from dust and excessive vibration.



10.5



Relay Mounting



RCS-985G is dispatched either individually or as part of a panel/rack assembly. Individual relays are normally supplied accompanied with this manual showing the dimensions for panel cutouts and whole centers. This information can also be found in the product publication.



10.5.1 Rack Mounting RCS-985G may be rack mounted using single tier rack frames, as illustrated in Figure 10.5-1 and Figure 10.5-2. The frames must have been designed to have dimensions in accordance with



278



NR ELECTRIC CO., LTD



Chapter10 Installation



IEC60297 and are supplied pre-assembled ready to use. On a standard 483mm rack system this enables combinations of widths of case up to a total equivalent of size 80TE to be mounted side by side. Once the tier is complete, the frames are fastened into the racks using mounting angles at each end of the tier. 482



285



465



RCS-985G GENERATOR PROTECTION



ALARM



76.2



279.4



354.8



CT ALARM



TRIP



ESC



VT ALARM



GRP



HEALTHY



ENT



NARI RELAYS ELECTRIC CO., LD



Figure 10.5-1 Rack mounting of relays—front face 465



355



76.2



279.4



450



8- ￠6.8



Figure 10.5-2 Rack mounting of relays—rear face NR ELECTRIC CO., LTD



279



Chapter10 Installation



Relays can be mechanically grouped into single tier (8U) or multi-tier arrangements by means of the rack frame.



10.5.2 Panel mounting The relays can be flush mounted into panels using M4 self-tapping screws with captive 3mm thick washers. For applications where relays need to be semi-projection or projection mounted, a range of collars are available. Where several relays are mounted in a single cutout in the panel, it is advised that they are mechanically grouped together horizontally and/or vertically to form rigid assemblies prior to mounting in the panel. Note: It is not advised that RCS-985G be fastened using pop rivets as this will not allow the relay to be easily removed from the panel in future if repair is necessary. If it is required to mount a relay assembly on a panel complying to IEC 60529 IP51 enclosure protection, it will be necessary to fit a metallic sealing strip between adjoining relays and a sealing ring around the complete assembly.



10.6



RELAY WIRING



This section serves as a guide to selecting the appropriate cable and connector type for each terminal on the RCS-985G.



10.6.1 Medium and heavy duty terminal block connections Heavy duty terminal block: CT and VT circuits. Medium duty: All other terminal blocks. Loose relays are supplied with sufficient M4 screws for making connections to the rear mounted terminal blocks using ring terminals, with a recommended maximum of two ring terminals per relay terminal. If required, NR can supply M4 90°crimp ring terminals in three different sizes depending on wire size (see Table 10.6-1). Table 10.6-1 M4 90°crimp ring terminals Part Number



Wire Size



Insulation Color



ZB9124 901



0.25 -1.65mm2 (22 - 16AWG)



Red



ZB9124 900



1.04 -2.63mm2 (16 - 14AWG)



Blue



ZB9124 904



2.53 -6.64mm2 (12 - 10AWG)



Un-insulated*



*To maintain the terminal block insulation requirements for safety, an insulating sleeve should be



280



NR ELECTRIC CO., LTD



Chapter10 Installation



fitted over the ring terminal after crimping. The following minimum wire sizes are recommended: Current transformers



2.5mm2



Auxiliary Supply, Vx



1.5mm2



EIA(RS)485 Port



See separate section



Other Circuits



1.0mm2



Due to the limitations of the ring terminal, the maximum wire size that can be used for any of the medium or heavy duty terminals is 6.0mm2 using ring terminals that are not pre-insulated. Where it is required to only use pre-insulated ring terminals, the maximum wire size that can be used is reduced to 2.63mm2 per ring terminal. If a larger wire size is required, two wires should be used in parallel, each terminated in a separate ring terminal at the relay. The wire used for all connections to the medium and heavy duty terminal blocks, except the EIA(RS)485 port, should have a minimum voltage rating of 300Vrms. It is recommended that the auxiliary supply wiring should be protected by a 16A high rupture capacity (HRC) fuse of type NIT or TIA. For safety reasons, current transformer circuits must never be fused. Other circuits should be appropriately fused to protect the wire used.



10.6.2 EIA(RS)485 port Connections to the EIA(RS)485 port are made using ring terminals. It is recommended that a 2 core screened cable be used with a maximum total length of 1000m or 200nF total cable capacitance. A typical cable specification would be: Each core:



16/0.2mm copper conductors，PVC insulated



Nominal conductor area:



0.5mm2 per core



Screen:



Overall braid, PVC sheathed



10.6.3 IRIG-B connections (if applicable) The IRIG-B input and BNC connector have a characteristic impedance of 50Ω. It is recommended that connections between the IRIG-B equipment and the relay are made using coaxial cable of type RG59LSF with a halogen free, fire retardant sheath.



10.6.4 EIA(RS)232 front port of downloading/monitoring Short term connections to the EIA(RS)232 port, located at the bottom of face cover, can be made using a screened multi-core communication cable up to 15m long, or of a total capacitance of 2500pF. The cable should be terminated at the relay end with a 9-way, metal shelled, D-type male plug. The pin allocations are detailed in section 5.4 about connectors.



10.6.5 Ethernet port (if applicable) Fiber Optic Port



NR ELECTRIC CO., LTD



281



Chapter10 Installation



The relays can have an optional 10 or 100 Mbps Ethernet port. FO connection is recommended for use in permanent connections in a substation environment. The 10Mbit port uses type ST connector and the 100Mbit port uses type SC connector, both compatible with 850nm multi-mode fiber-optic cable. RJ-45 Metallic Port The user can connect to either a 10Base-T or a 100Base-TX Ethernet hub; the port will automatically sense which type of hub is connected. Due to possibility of noise and interference on this part, it is recommended that this connection type be used for short-term connections and over short distance, ideally where the relays and hubs are located in the same cubicle. The connector for the Ethernet port is a shielded RJ-45. The table shows the signals and pins on the connector. Table 10.6-2 Signals on the Ethernet connector Pin



Signal Name



Signal Definition



1



TXP



Transmit (positive)



2



TXN



Transmit (negative)



3



RXP



Receive (positive)



4



-



Not used



5



-



Not used



6



RXN



7



-



Not used



8



-



Not used



Receive (negative)



10.6.6 Test port Short term connections to the download/monitor port, located on the front access cover, can be made using a screened 9-core communication cable up to 4m long. The cable should be terminated at the relay end with a 9-way, metal shelled, D-type male plug and linked as a serial data connection.



10.6.7 Earth connection Every relay must be connected to the cubicle earth bar using the M4 earth studs in the rear faceplate of the relay case. The minimum recommended wire size is 2.5mm2 and should have a ring terminal at the relay end.



282



NR ELECTRIC CO., LTD



Chapter11 Commission



Chapter11 Commission 11.1



Introduction



This relay is fully numerical in their design, implementing all protection and non-protection functions in software. The relay employs a high degree of self-checking and in the event of a failure, will give an alarm. As a result of this, the commissioning test does not need to be as extensive as with non-numeric electronic or electro-mechanical relays. To commission numerical relays, it is only necessary to verify that the hardware is functioning correctly and the application-specific software settings have been applied to the relay. It is considered unnecessary to test every function of the relay if the settings have been verified by one of the following methods: - extracting the settings applied to the relay using appropriate setting software (preferred method) - via the operator interface Blank commissioning test and setting records are provided at the end of this manual for completion as required. WARNING! Before carrying out any work on the equipment, the user should be familiar with the contents of the safety and technical data sections and the ratings on the equipment‘s rating label.



11.2



Precautions WARNING!



Hazardous voltages are present in this electrical equipment during operation. Non - observance of the safety rules can result in severe personal injury or property damage. Only qualified personnel shall work on and around this equipment after becoming thoroughly familiar with all warnings and safety notices in this manual as well as with the applicable safety regulations. Particular attention must be drawn to the following: The earthing screw of the device must be connected solidly to the protective earth conductor before any other electrical connection is made. Hazardous voltages can be present on all circuits and components connected to the supply voltage or to the measuring and test quantities. Hazardous voltages can be present in the device even after disconnection of the supply voltage (storage capacitors!).



NR ELECTRIC CO., LTD



283



Chapter11 Commission



The limit values stated in the technical data (Chapter 2) must not be exceeded at all, not even during testing and commissioning. When testing the device with secondary test equipment, make sure that no other measurement quantities are connected. Take also into consideration that the trip circuits and maybe also close commands to the circuit breakers and other primary switches are disconnected from the device unless expressly stated.



DANGER!



Current transformer secondary circuits must have been short-circuited before the current leads to the device are disconnected. WARNING! Primary test may only be carried out by qualified personnel, who are familiar with the commissioning of protection system, the operation of the plant and safety rules and regulations (switching, earthing, etc.)



11.3



Relay commission tools



Minimum equipment required --Multifunctional dynamic current and voltage injection test set with interval timer --Multimeter with suitable AC current range and AC/DC voltage ranges of 0-200V and 0-250V respectively. --Continuity tester (if not included in the multimeter) --Phase angle meter --Phase rotation meter Note: Modern test set may contain many of the above features in one unit. Optional equipment --An electronic or brushless insulation tester with a DC output not exceeding 500 V (for insulation resistance test when required); --A portable PC, with appropriate software (this enables the rear communications port to be tested, if this is to be used, and will also save considerable time during commissioning). --RCSPC software. --EIA(RS)485 to EIA(RS)232 converter (if EIA(RS)485 IEC60870 port is being tested).



284



NR ELECTRIC CO., LTD



Chapter11 Commission



-- A printer. - RCS-900 serials dedicated protection tester TEST or HELP-90.



11.4



Setting Familiarization



When commissioning a RCS-985G relay for the first time, sufficient time should be given to become familiar with the method by which the settings are applied. The Chapter 8 contains a detailed description of the menu structure of RCS-985G relays. With the front cover in place all keys are accessible. All menu cells can be read. LEDs and alarms can be reset. Protection or configuration settings can be changed, or fault and event records cleared. However, menu cells will require the appropriate password to be entered before changes can be made. Alternatively, if a portable PC is available together with suitable setting software (such as RCSPC), the menu can be viewed a page at a time to display a full column of data and text. This PC software also allows settings to be entered more easily, saved to a file on disk for future reference or printed to produce a setting record. Refer to the PC software user manual for details. If the software is being used for the first time, allow sufficient time to become familiar with its operation.



11.5



Product checks



These product checks cover all aspects of the relay which should be checked to ensure that it has not been physically damaged prior to commissioning, is functioning correctly and all input quantity measurements are within the stated tolerances. If the application-specific settings have been applied to the relay prior to commissioning, it is advisable to make a copy of the settings so as to allow restoration later. This can be done by extracting the settings from the relay itself via printer or manually creating a setting record.



11.5.1 With the relay de-energized The RCS-985 serial plant transformer protection is fully numerical and the hardware is continuously monitored. Commissioning tests can be kept to a minimum and need only include hardware tests and conjunctive tests. The function tests are carried out according to user‘s correlative regulations. The following tests are necessary to ensure the normal operation of the equipment before it is first put into use. 



Hardware tests These tests are performed for the following hardware to ensure that there are no hardware defects. Defects of hardware circuits other than the following can be detected by self-monitoring when the DC power is supplied.







User interfaces test







Binary input circuits and output circuits test



NR ELECTRIC CO., LTD



285



Chapter11 Commission







AC input circuits test







Function tests These tests are performed for the following functions that are fully software-based. Tests of the protection schemes and fault locator require a dynamic test set.







Measuring elements test







Timers test







Metering and recording test







Conjunctive tests The tests are performed after the relay is connected with the primary equipment and other external equipment.







On-load test







Phase sequence check and polarity check.



11.5.1.1 Visual inspection After unpacking the product, check for any damage to the relay case. If there is any damage, the internal module might also have been affected, contact the vendor. Following items listed is necessary. 1.



Protection panel Carefully examine the protection panel, protection equipment inside and other parts inside to see that no physical damage has occurred since installation. The rated information of other auxiliary protections should be checked to ensure it is correct for the particular installation.



2.



Panel wiring Check the conducting wire used in the panel to assure that their cross section meets the requirement. Carefully examine the wiring to see that they are no connection failure exists.



3.



Label Check all the isolator binary inputs, terminal blocks, indicators, switches and push buttons to make sure that their labels meet the requirements of this project.



4.



Equipment plug-in modules Check each plug-in module of the equipments on the panel to make sure that they are well installed into the equipment without any screw loosened.



286



NR ELECTRIC CO., LTD



Chapter11 Commission



1 A



1 A



1 B



1 B



2 A



2 A



2 B



2 B



3 A



3 A



3 B



3 B



4 A



4 A



4 B 5 B



4 B 5 B



6 B



6 B



7 B



7 B



8 B



8 B



9 B



9 B



8 C



8 C



9 C



9 C



Figure 11.5-1 RCS-985G rear plug-in connector locations(viewed from rear) 5.



Earthing cable Check whether the earthing cable from the panel terminal block is safely screwed to the panel steel sheet.



6.



Switch, keypad, isolator binary inputs and push button: Check whether all the switches, equipment keypad, isolator binary inputs and push buttons work normally and smoothly.



11.5.1.2 Insulation Insulation resistances tests are only necessary during commission if it is required for them to be done and they have not been performed during installation. Isolate all wiring from the earth and test the insulation with an electronic or brushless insulation tester at a DC voltage not exceeding 500V, terminals of the same circuits should be temporarily connected together. The main groups of the relay terminals are: -Voltage transformer circuits -Current transformer circuits -Field voltage output and opto-isolated control inputs



NR ELECTRIC CO., LTD



287



Chapter11 Commission



-Relay contacts -EIA(RS)485 communication port -Case earth The insulation resistance should be greater than 100MΩ at 500V. On completion of the insulation resistance tests, ensure all external wiring is correctly reconnected to the relay. 11.5.1.3 External wiring Check that the external wiring is correct to the relevant relay diagram and scheme diagram. Ensure as far as practical that phasing/phase rotation appears to be as expected. Check the wiring against the schematic diagram for the installation to ensure compliance with the customer‘s normal practice. 11.5.1.4 Auxiliary supply The relay can be operated from either 110/125Vdc or 220/250Vdc auxiliary supply depending on the relay‘s nominal supply rating. The incoming voltage must be within the operating range specified in the following table, before energizing the relay, measure the auxiliary supply to ensure it is within the operating range. Rated Voltage



110/125VDC



220/250VDC



Variation



88 - 144 VDC



176 - 288 VDC



It should be noted that the relay can withstand an AC ripple of up to 15% of the upper rated voltage on the DC auxiliary supply. Energize the relay only if the auxiliary supply is within the specified operating ranges.



11.5.2 With the relay energized The following groups of tests verify that the protection hardware and software is functioning correctly and should be carried out with the auxiliary supply applied to the protection. The current and voltage transformer connections must remain isolated from the protection for these checks. The trip circuit should also remain isolated to prevent accidental operation of the associated circuit breaker. 11.5.2.1 User interface This test ensures that the LCD, LEDs and keys function correctly. ◆ LCD display Only apply the rated DC voltage and check whether the LCD displays normal operation status report as mentioned earlier. If there is a failure, for example, if the VT circuit fails because of not applying the voltage, the LCD displays failure report. On pressing the ECS key for 1 second and the LCD will return to normal operation status report.



288



NR ELECTRIC CO., LTD



Chapter11 Commission



◆ LED display Apply the rated DC voltage and check that the "HEALTHY" LED is lit in green. We need to emphasize that the "HEALTHY" LED is always lit in operation course except when the equipment finds serious problems listed in chapter 4. ◆ Keypad Press key ―ESC‖ or ―▲‖and enter the command menu. Do some jobs to ensure that all buttons are in good condition. 11.5.2.2 Watchdog contacts (Equipment being blocked, BSJ) Using a continuity tester, check the watchdog contacts (equipment being blocked, BSJ) are in the states given in Table 11.5-1 below. Table 11.5-1 Watchdog contact status Terminals 3A1-3A3



Contacts Relay de-energized



Relay energized



Closed



Open



3A2-3A4 3B4-3B26 11.5.2.3 Date and time The method of setting will depend on whether accuracy is being maintained via the RS-485 port (from GPS in the substation) on the rear of the protection or via the front panel user interface manually. Turn on the DC power supply of the equipment and check the software version and time through the LCD Manual. 11.5.2.4 Binary input check This test checks that all the binary inputs on the protection are functioning correctly. The binary inputs should be energized one at a time. Ensuring correct polarity, connect the field supply voltage to the appropriate terminals for the input being tested. There two voltage levels of opto-couple for binary inputs, one is 24V DC and the other is 250/220/125/110V DC. The negative pole of DC 24V and negative pole of DC 250/220/125/110V have been connected with the corresponding negative pole of opto-couplers through the inner rear board in equipment. The positive pole terminals of opto-couplers have been connected to the rear connectors for binary input connecting, and common positive pole has also be connected to the rear connector. Please see the panel diagram carefully and find the right connector terminal numbers of common positive pole of DC 24V and DC 250/220/125/110V. Note: NR ELECTRIC CO., LTD



289



Chapter11 Commission



The binary inputs may be energized from an external DC auxiliary supply (e.g. the station battery) in some installations. Check that this is not the case before connecting the field voltage otherwise damage to the protection may result. The status of each binary input can be viewed using either RCSPC software installed in a portable PC or by checking the front human-machine interface LCD. When each binary input is energized the display will change to indicate the new status of the inputs. Please check binary input both on CPU module and MON module and ensure they are consistent. Please note only the positive pole of opto-coupler for binary inputs are listed in following tables. 1) Generator protection contacts(24V opto-couplers) Path: Main Menu -> VALUES-> CPU(MON) BI STATE ->GEN PROT EBI No.



Signal name



Equipment terminal number



1



EBI_Diff_Gen



4B29-4B3



2 3



EBI_SPTDiff_Gen



4B29-4B26



EBI_PPF_Gen



4B29-4B25



4



EBI_IntTurn_Gen



4B29-4B4



5



EBI_BFP_Gen



5B17-5B2



6



EBI_ROV_Sta



4B29-4B5



7



EBI_V3rdH_Sta



4B29-4B6



8



EBI_1PEF_RotWdg



4B29-4B7



9



EBI_2PEF_RotWdg



4B29-4B8



10



EBI_OvLd_Sta



4B29-4B9



11



EBI_NegOC_Gen



4B29-4B10



12



EBI_LossExc_Gen



4B29-4B11



13



EBI_OOS_Gen



4B29-4B12



14



EBI_VoltProt_Gen



4B29-4B13



15



EBI_OvExc_Gen



4B29-4B14



16



EBI_PwrProt_Gen



4B29-4B15



17



EBI_FreqProt_Gen



4B29-4B16



18



EBI_AccEnerg_Gen



4B29-4B17



19



EBI_SeqTrpRevP_Gen



5B17-5B3



20



EBI_StShut_Gen



4B29-4B18



Wiring connector number



CPU status



MON status



CPU status



MON status



2) Exciter protection contacts(24V opto-couplers) Path: Main Menu -> VALUES-> CPU(MON) BI STATE ->EXC PROT EBI No.



Signal name



Equipment terminal number



1



EBI_Diff_Exc



4B29-4B19



2



EBI_Bak_Exc



4B29-4B20



290



Wiring connector number



NR ELECTRIC CO., LTD



Chapter11 Commission



3



EBI_OvLd_Exc



5B17-5B1



3) Mechanical protection contacts(220/110V opto-couplers) Path: Main Menu -> VALUES-> CPU(MON) BI STATE ->MECH RLY EBI No.



Signal name



Equipment terminal number



1



EBI_Trp_MechRly3



4B29-4B21



2 3



EBI_Trp_MechRly4



4B29-4B22



EBI_Trp_MechRly2



4B29-4B23



4



EBI_Trp_MechRly1



4B29-4B24



5



BI_MechRly 3



4A27-4A17



6



BI_MechRly 4



4A27-4A18



7



BI_MechRly 2



4A27-4A19



8



BI_MechRly 1



4A27-4A20



Wiring connector number



CPU status



MON status



CPU status



MON status



CPU status



MON status



4) Auxiliary binary inputs (220/110V opto-couplers) Path: Main Menu -> VALUES-> CPU(MON) BI STATE -> AUX BI No.



Signal name



Equipment terminal number



1



BI_52b_GCB



4A27-4A22



2



BI_Valve_Turbine



4A27-4A26



3 4



BI_UrgBrake



5B25-5B19



BI_SyncCondenser



5B25-5B20



5



BI_ExtTrpCtrl_BFP_Gen



5B25-5B22



6



BI_Pwr_Superv



5B25-5B23



Wiring connector number



4) Binary inputs for power supply supervise (24V opto-couplers) Path: Main Menu -> VALUES-> CPU(MON) BI STATE -> PS SUPERV BI No.



Signal name



Equipment terminal number



1



BI_Print



5B17-5B13



2 3



BI_Pulse_GPS



5B17-5B14



BI_RstTarg



5B17-5B15



Wiring connector number



11.5.2.5 Binary output check ◆ Check alarm signal contacts When detecting a hardware failure in self-supervise, the relay will block all the output and the ―HEALTY‖ LED will not be lit. If the entire operation element for alarm operates, the ―ALARM‖ LED will illuminate. At the same



NR ELECTRIC CO., LTD



291



Chapter11 Commission



time, the BJJ contact and other alarm contacts will be closed. According to the below table we can check these contacts. No



Signal name



Local signal



Remote signal



SOE signal



1



BO_FAIL



3A1-3A3



3A2-3A4



3B4-3B26



2



BO_ALM



3A1-3A5



3A2-3A6



3B4-3B28



3



BO_CTS



3A1-3A7



3A2-3A8



3B4-3B6



4



BO_VTS



3A1-3A9



3A2-3A10



3B4-3B8



5



BO_OvLd



3A1-3A11



3A2-3A12



3B4-3B10



6



BO_NegOC



3A1-3A13



3A2-3A14



3B4-3B12



7



BO_OvLd_Exc



3A1-3A15



3A2-3A16



3B4-3B14



8



BO_EF_Sta



3A1-3A17



3A2-3A18



3B4-3B16



9



BO_Alm_1PEF_Gen



3A1-3A19



3A2-3A20



3B4-3B18



10



BO_LossExc_Gen



3A1-3A21



3A2-3A22



3B4-3B20



11



BO_OOS_Gen



3A1-3A23



3A2-3A24



3B4-3B22



12



BO_UF_Gen



3A1-3A25



3A2-3A26



3B4-3B24



13



BO_RevP_Gen



3A1-3A27



3A2-3A28



3B4-3B29



14



BO_OvExc_Gen



3A1-3A29



3A2-3A30



3B4-3B30



Yes or NO



◆Check tripping signal contacts If the operation element for tripping operates, the ―TRIP‖ LED will illuminate. At the same time, the tripping signal contacts will be closed. According to the below table we can check these contacts. No



Signal name



Local signal



Remote signal



SOE signal



Yes or NO



The first group: 1



BO_Diff_Gen



2A1-2A7



2A3-2A9



2A5-2A11



2



BO_EF_Sta



2A1-2A13



2A3-2A15



2A5-2A17



3



BO_OvLd_Sta



2A1-2A19



2A3-2A21



2A5-2A23



4



BO_LossExc_Gen



2A1-2A25



2A3-2A27



2A5-2A29



5



BO_OV_Gen



2A1-2B1



2A3-2B3



2A5-2B5



6



BO_RevPwr_Gen



2A1-2B7



2A3-2B9



2A5-2B11



7



BO_UF _Gen



2A1-2B13



2A3-2B15



2A5-2B17



8



BO_AccEnerg_Gen



2A1-2B19



2A3-2B21



2A5-2B23



9



BO_Diff_Exc



2A1-2B25



2A3-2B27



2A5-2B29



The second group: 10



BO_InterTurn_Gen



2A2-2A8



2A4-2A10



2A6-2A12



11



BO_OF_Gen



2A2-2A14



2A4-2A16



2A6-2A18



12



BO_NegOC_Gen



2A2-2A20



2A4-2A22



2A6-2A24



13



BO_OOS_Gen



2A2-2A26



2A4-2A28



2A6-2A30



14



BO_OvExc_Gen



2A2-2B2



2A4-2B4



2A6-2B6



15



BO_SeqTrpPwr_Gen



2A2-2B8



2A4-2B10



2A6-2B12



292



NR ELECTRIC CO., LTD



Chapter11 Commission



16



BO_Bak_Gen



2A2-2B14



2A4-2B16



2A6-2B18



17



BO_Trp_MechRly



2A2-2B20



2A4-2B22



2A6-2B24



18



BO_Bak_Exc



2A2-2B26



2A4-2B28



2A6-2B30



◆Check tripping output contacts Setting the tripping logic settings refer to table 5-1. The output x will be closed only when the correspond bit [Output x] is set as ―1‖. According to the below table we can check these contacts. No



Output name



1



TrpOutput 1



2



TrpOutput 2



Equipment terminal number 1A3-1A5、1A7-1A9 1A11-1A13、1A15-1A17



Wiring connector number



Yes or No



1A19-1A21、1A23-1A25 1A27-1A29、1B1-1B3



3



TrpOutput 3



1A2-1A4、1A6-1A8 1A10-1A12、1A14-1A16



4



TrpOutput 4



1A18-1A20、1A22-1A24



5



TrpOutput 5



1A26-1A28、1B2-1B4 1B6-1B8、1B10-1B12



6



TrpOutput 6



1B5-1B7、1B9-1B11 1B13-1B15



7



TrpOutput 7



1B17-1B19



8



TrpOutput 8



1B21-1B23



9



TrpOutput 9



1B25-1B27



10



TrpOutput 10



1B29-1B30



11



TrpOutput 11



1B14-1B16、1B18-1B20



12



TrpOutput 12



1B22-1B24、1B26-1B28



11.5.2.6 Communications port This test should only be performed where the protection is to be accessed from a remote location and will vary depending on the communications standard being adopted. It is not the intention of the test to verify the operation of the complete system from the relay to the remote location, just the protection‘s rear communications port and any protocol converter necessary. Courier communications Ensure that the RS-232 wire link the RS-232 port in front of the RCS-985G and the communication baud rate in RCSPC must be set as ―9600‖. Check that communications can be established with this protection using the portable PC. Remote communication This test is to check the status of communications between RCS-985G and the engineer‘s NR ELECTRIC CO., LTD



293



Chapter11 Commission



workstation in SAS (Substation automation system) if it is applicable. Before test, the communication baud rate in RCS-985G must be set as ―1200-38400‖ depending on the Substation Automation System, and the protection‘s [Comm_Adrr] must be set to a value between 1 and 254. In the menu of ―DEBUG‖->‖COMM STATUS‖ on the LCD display, ―485A‖or ―485B‖ indicates the communication status of 485A port or 485B port. If ―Receive Data‖ is ―N‖, it means the equipment has not received data from the external system. If ―Valid Frame‖ is ‗N‘, it indicates the setting error of baud rate or protocol while ―Valid Address‖ is ―N‖, it means the communication address is set wrongly. ‖Send Data‖ is "N‖ means datagram sent from the equipment is wrong. If all those status are ‗Y‘, it means communication is established successfully. 11.5.2.7 AC Current inputs check This test verifies that the accuracy of current measurement is within the acceptable tolerances. All protections will leave the factory with setting for operation at a system frequency of 50Hz or 60Hz. All relays will be set for operation at a system frequency of 50Hz. If operation at 60Hz is required then this must be set at menu. Apply current equal to the current transformer secondary winding rating to each current transformer input of the corresponding rating in turn, see the following table or external connection diagram for appropriate terminal numbers, checking its magnitude using a multimeter/test set readout. The corresponding reading can then be checked in the relays‘ menu. The measurement accuracy of the relay is ±5%. However an additional allowance must be made for the accuracy of the test equipment being used. Table 11.5-2 Current linearity and precision check out Items



No.



1



I_S1_Exc



2



I_S2_Exc



3



I_Term_Gen



4



I_NP_Gen



5



Itransv



6



I_Rot



Input value



Phase A



Displayed on LCD Angle Phase B Phase C between A and B



Angle between A and C



In 4In In 4In In 4In In 4In In 4In 20mA



******************* ******************* *******************



40mA



*******************



Note:



294



NR ELECTRIC CO., LTD



Chapter11 Commission



To avoid damage the equipment, we can‘t inject a high value current (such as 4In or more) to the equipment for long time, we suggest that the time in high current condition should not be over 3 second every time. The measurement accuracy of the protection is ± 5%. However, an additional allowance must be made for the accuracy of the test equipment being used. 11.5.2.8 AC Voltage inputs check This test only needs to be performed on models with voltage transformer inputs as it verifies that the accuracy of voltage measurement is within the acceptable tolerance levels. Apply rated voltage to voltage transformer input, checking its magnitude using a multimeter/test set readout. The corresponding reading can then be checked in the relays menu. The measurement accuracy of the relay is ±5%. However an additional allowance must be made for the accuracy of the test equipment being used. Table 11.5-3 Voltage linearity and precision check out Displayed in LCD Input value



No.



Items



1



U_VT1_Term_Gen



2



U_VT2_Term_Gen



3



U0_DeltVT1_Term_Gen



4



U0_DeltVT2_Term_Gen



5



U0_NP_Gen



6



U_Busbar



7



U_RotWdg (DC)



220V



8



I_RotWdg (DC)



0.075V



PhA



PhB



PhC



Angle between A and B



Angle between A and C



58V 20V 58V 20V 58V 20V 100V 20V 100V 20V 100V 20V



Note: When checking the rotor current channel, 0.075V is equal to 1000A of rotor current, please refer to section 7.2 [I1n_RotWdg] and [U2n_Shunt_RotWdg] The measurement accuracy of the protection is ±5%. However, an additional allowance must be



NR ELECTRIC CO., LTD



295



Chapter11 Commission



made for the accuracy of the test equipment being used.



11.5.3 Setting Testing The setting checks ensure that the entire application-specific relay, for the particular installation, has been correctly applied to the relay. Note: The trip circuit should remain isolated during these checks to prevent accidental operation of the associated circuit breaker. If the application-specific settings are not available, ignore sections 11.5.3. Apply application-specific settings There are two methods of applying the settings to the relay: Transfer them from a pre-prepared setting file to the relay using a portable PC running the appropriate software via the relay‘s RS232 port located on the frontplate of the relay. This method is preferred for transferring function settings as it is much faster and there is less possiblity for error. Enter them manually via the relay‘s operator interface. Demonstrate correct relay operation Tests mentioned above have already demonstrated that the relay is within calibration, thus the purpose of these tests is as follows: − To determine that the primary protection functions, such as generator differential protection, overcurrent protection and so on, can trip according to the correct application settings. − To verify correct assignment of the trip contacts, by monitoring the response to a selection of fault injections.



11.5.4 Rear communications port EIA (RS) 485 This test should only be performed where the relay is to be accessed from a remote location and will vary depending on the communications standard being adopted. It is not the intension of the test to verify the operation of the complete system from the relay to the remote location, just the relay‘s rear communications port and any protocol converter necessary. Connect a portable PC to the relay via a EIA (RS) 485-232 converter. Ensure that the relay address and the baud rate settings in the application software are set the same as those in relay. If the relay has the optional fiber optic communications port, then a fibre optic-RS232 converter shall be applied.



11.5.5 On-load checks The objectives of the on-load checks are to: 296



NR ELECTRIC CO., LTD



Chapter11 Commission



-Confirm the external wiring to the current and voltage inputs is correct. -Check the polarity of the current transformers at each side is consistent. Remove all test leads, temporary shorting leads, etc. and replace any external wiring that has been removed to allow testing. If it has been necessary to disconnect any of the external wiring from the relay in order to perform any the foregoing tests. It should be ensured that all connections are replaced in accordance with the relevant external connection or scheme diagram. Voltage connections Using a multimeter to measure the voltage generator secondary voltages to ensure they are correctly rated. Check that the system phase rotation is correct using a phase rotation meter. Compare the values of the secondary phase voltages with the relays measured values, which can be found in the menu. Current connections Measure the current transformer secondary values for each input using a multimeter connected in series with the corresponding current input. (It is preferable to use a tong-test ammeter instead) Check that the current transformer polarities are correct by measuring the phase angle between the current and voltage either against a phase meter already installed on site and known to be correct or by determining the direction of power flow by contacting the networks control center (NCC). Compare the values of the secondary phase currents and phase angle with the relay‘s measured values, which can be found in menu.



11.5.6 Final check The tests are now complete. Remove all test or temporary shorting leads, etc. If it has been necessary to disconnect any of the external wiring from the relay in order to perform the wiring verification tests, it should be ensured that all connections (wiring, fuses and links) are replaced in accordance with the relevant external connection or scheme diagram. Ensure that all event records, fault records, disturbance records, alarms and LEDs have been reset before leaving the relay.



11.6



Use of assistant test software RCSPC



11.6.1 Function summary of RCSPC communication software RCSPC configuration and testing program (user version) is developed for the user to configure, test and maintain RCS-985G generator protection equipment on site. It comprises of four parts: sampled value display, settings reading and modification, report process and test. These four parts correspond to 4 files RCS-985G_status, RCS-985G_set, NR ELECTRIC CO., LTD



297



Chapter11 Commission



RCS-985G_rpt and RCS-985G_tst respectively and are described hereinafter. We have to say that the four configuration file is relevant with a special version of protection program. That is, when the protection program is upgraded, the above mentioned four configuration files must also be upgrade at the same time; otherwise it may cause confusion to the equipment at the time of setting. Connect RS-232 communication port of the computer and that of RCS-985G protection equipment by a cable with DB-9 connectors on both ends. Run the program RCSPC. If the connection is correct, the screen will show ―RCS-985G connected‖, see Figure 11.6-1. Even if the computer is off line, this picture will be still shown but the words about connection will disappear.



Figure 11.6-1 Display of connection status of RCSPC with RCS-985G



11.6.2 Connection way of protection equipment and personal computer A 9-pin RS232C serial port is located on the relay‘s front panel for communication with a personal computer. All that is required to use this interface is a personal computer running the RCSPC software provided with the equipment. Cabling for the RS232 port is shown in the following figure for 9 pin connectors.



Figure 11.6-2 Definition of RS-232 wiring cable



11.6.3 Configuration of PC and the software before use 11.6.3.1 PC configuration Set the PC com port‘s baud rate which is connected with front series port of RCS-985G as 9600bps.



298



NR ELECTRIC CO., LTD



Chapter11 Commission



11.6.3.2 Software configuration There are 3 bars on top of the screen, from top to bottom: title bar, menu bar and tool bar, see Figure 11.6-3.



Figure 11.6-3 Title bar, menu bar and tool bar



First, click the first button of tool bar



parameter, dialog box of communication parameters is



displayed, see Figure 11.6-4. Only the parameter of [COM port] shall be configured as the port of computer which is actually connected with the equipment, all other parameters shall be configured as the same as displayed in Figure 11.6-4.



Figure 11.6-4 Dialog box of communication Parameters



11.6.4 Operation instruction of the software Here is only a brief description of usage. Please refer to dedicated manual of RCSPC for more details. 11.6.4.1 Protection parameters setting Offline protection parameters setting—A convenient function of the software This function is used for offline parameter setting. First, input setting parameters and save it in PC, NR ELECTRIC CO., LTD



299



Chapter11 Commission



then connect PC with the protection equipment, executive ―DOWNLOAD‖ command, and the settings saved in PC will be transferred to the protection equipment, so most parts of the setting operation can be finished in office instead of in substation. Here is the procedure to input settings offline: Before connecting PC with RCS-985G, run the software of RCSPC，click on ―setting‖ icon, a popup dialog box will appear which will ask user whether or not to set parameter offline, click ―yes‖ and input ―985Gxxx‖ (xxx represents program version, point ignored) to confirm the relay type and version of the protection program, then parameter setting interface will appear. The settings displayed first are default settings; user can replace them with application-specific settings. After modifications, save the settings into a file. When the PC is connected with the protection equipment, open the settings file and transfer setting to protection. Online setting by RCSPC When PC is connecting with RCS-985G, run RCSPC, the PC screen will display ―RCS-985Gxxx connected‖, click on ―SETTING‖ icon, then parameter setting interface will appear, the settings uploaded from RCS-985G will be displayed, user can modify them to application-specific settings. 11.6.4.2 Status Click



button, user can observe real time sampled data and binary input status.



11.6.4.3 Report Click



button, entering report view part of the program, choose a report in the table, and click



―report record‖, save report data according to following clue on instruction. The data can be used in the auxiliary analyze software to show us the fault course of power system and the logic calculation course of RCS-985G again. 11.6.4.4 SIG RESET Click



button, all magnetic latched output relays and signal relays will be reset.



11.6.4.5 Trip test (if available) Click



button, entering trip test part of the program, click contacts to change the status of



relays displayed, a same operation command to breaker circuit will be issued. This function is used to test breaker circuit without applying electric quantities to the protection equipment.



300



NR ELECTRIC CO., LTD



Chapter12 Maintenance



Chapter12 Maintenance 12.1



Maintenance period



It is recommended that products supplied by NR receive periodic monitoring after installation. In view of the critical nature of protective relays and their infrequent operation, it is desirable to confirm that they are operating correctly at regular intervals. NR protective relays are designed for a life in excess of 10 years. RCS series relays are self-supervising and so require less maintenance than earlier designs of relay. Most problems will result in an alarm so that remedial action can be taken. However, some periodic tests should be done to ensure that the relay is functioning correctly and the external wiring is intact.



12.2



Maintenance checks



Although some functionality checks can be performed from a remote location by utilizing the communications ability of the relays, these are predominantly restricted to checking that the relay is measuring the applied currents and voltages accurately. Therefore it is recommended that maintenance checks are performed locally (i.e. at the substation itself). Before carrying out any work on the equipment, the user should be familiar with the contents of the Safety and technique Data sections and the ratings on the equipment‘s rating label.



12.2.1 Alarms The alarm status LED should first be checked to identify if any alarm conditions exist. If so, try to find the cause of the alarm and eliminate it and clear the alarms to extinguish the LED.



12.2.2 Binary Inputs The opto-isolated inputs can be checked to ensure that the relay responds to their energization.



12.2.3 Binary output The output relays can be checked to ensure that they operate by repeating the commissioning test.



12.2.4 Analog inputs If the power system is energized, the values measured by the relay can be compared with known system values to check that they are in the approximate range that is expected. If they are, then the analog/digital conversion and calculations are being performed correctly by the relay. Alternatively, the values measured by the relay can be checked against known values injected into the relay via the test block, if fitted, or injected directly into the relay terminals. Suitable test methods can be found in relevant manuals. These tests will prove the calibration accuracy is being NR ELECTRIC CO., LTD



301



Chapter12 Maintenance



maintained.



12.3



Method of Repair



If the relay would develop a fault while in service, depending on the nature of the fault, the watchdog contacts will change state and an alarm condition will be flagged. Due to the extensive use of surface-mount components, faulty PCBs should be replaced, as it is not possible to perform repairs on damaged circuits. Thus either the complete relay or just the faulty PCB, identified by the in-built diagnostic software, can be replaced. Advice about identifying the faulty PCB can be found in section 12.3.2. The preferred method is to replace the complete relay as it ensures that the internal circuitry is protected against electrostatic discharge and physical damage at all times and overcomes the possibility of incompatibility between replacement PCBs. Replacing PCBs can reduce transport costs but requires clean, dry conditions on site and higher skills from the person performing the repair. However, if the repair is not performed by an approved service center, the warranty will be invalidated. Before carrying out any work on the equipment, the user should be familiar with the contents of the Safety and technique Data sections and the ratings on the equipment‘s rating label. This should ensure that no damage is caused by incorrect handling of the electronic components.



12.3.1 Replacing the complete relay The case and rear terminal blocks have been designed to facilitate removal of the complete relay without having to disconnect the scheme wiring. Before working at the rear of the relay, isolate all voltage and current supplies to the relay. Note: The RCS serials relays have integral current transformer shorting switches which will close when the connecting terminal is removed. Disconnect the relay earth, IRIG-B and fiber optic connections, as appropriate, from the rear of the relay. Note: The use of a magnetic bladed screwdriver is recommended to minimize the risk of the screws being left in the terminal block or lost. Without exerting excessive force or damaging the scheme wiring, pull the terminal blocks away from their internal connectors. Remove the screws used to fasten the relay to the panel, rack, etc. These are the screws with the larger diameter heads on front of the faceplate of the relay. Withdraw the relay carefully from the panel, rack, etc. because it will be heavy due to the internal 302



NR ELECTRIC CO., LTD



Chapter12 Maintenance



transformers. To reinstall the repaired or replacement relay, follow the above instructions in reverse, ensuring that each terminal block is relocated in the correct position and the case earth, and fiber optic connections are replaced. Once reinstallation is complete the relay should be re-commissioned using the instructions in Chapter11 of this manual.



12.3.2 Replacing a PCB Replacing printed circuit boards and other internal components of protective relays must be undertaken only by Service Centers approved by NR. Failure to obtain the authorization of NR After Sales Engineers prior to commencing work may invalidate the product warranty. Before replacing a PCB the auxiliary supply must be removed, and wait 5s for capacitors to discharge. It is also strongly recommended that the voltage and current transformer connections and trip circuit are isolated. The relay, being modular in design, allows for the withdrawal and insertion of modules. Modules must only be replaced with like modules in their original factory configured slots.



Figure 12.3-1 RCS-985G Module Withdrawal/Insertion NR Support teams are available world-wide, and it is strongly recommended that any repairs be entrusted to those trained personnel. For this reason, details on product disassembly and re-assembly are not included here.



12.4



Changing the relay battery



Each relay has a battery to maintain status data and the correct time when the auxiliary supply voltage fails. The data maintained includes event, fault and disturbance records. This battery will periodically need changing. If the battery-backed facilities are not required to be NR ELECTRIC CO., LTD



303



Chapter12 Maintenance



maintained during an interruption of the auxiliary supply, the steps below can be followed to remove the battery. Before carrying out any work on the equipment, the user should be familiar with the contents of the safety and technique data sections and the ratings on the equipment‘s rating label.



12.4.1 Instructions for replacing the battery Withdraw the CPU board from RCS-985G. Gently extract the battery from its socket. If necessary, use a small, insulated screwdriver to prize the battery free. Ensure that the metal terminals in the battery socket are free from corrosion, grease and dust. The replacement battery should be removed from its packaging and placed into the battery holder, taking care to ensure that the polarity markings on the battery agree with those adjacent to the socket as shown as below. Note: Ensure that the battery is securely held in its socket and that the battery terminals are making good contact with the metal terminals of the socket. Insert the CPU module into RCS-985G.



12.4.2 Battery disposal The battery that has been removed should be disposed of in accordance with the disposal procedure for Lithium batteries in the country in which the relay is installed.



12.5



Cleaning



Before cleaning the equipment ensure that all AC and DC supplies, current transformer and voltage transformer connections are isolated to prevent any chance of an electric shock whilst cleaning. The equipment may be cleaned using a lint-free cloth moistened with clean water. The use of detergents, solvents or abrasive cleaners is not recommended as they may damage the relay‘s surface and leave a conductive residue.



304



NR ELECTRIC CO., LTD



Chapter13 Decommissioning and Disposal



Chapter13 Decommissioning and Disposal 13.1



Decommissioning



13.1.1 Switching Off To switch off the RCS-985G, switch off the external miniature circuit breaker of the power supply.



13.1.2 Disconnecting Cables Disconnect the cables in accordance with the rules and recommendations made by relational department. DANGER: Before disconnecting the power supply cables that connected with the DC module of the RCS-985G, make sure that the external miniature circuit breaker of the power supply is switched off. DANGER: Before disconnecting the cables that are used to connect analog input module with the primary CTs and VTs, make sure that the circuit breaker for the primary CTs and VTs is switched off.



13.1.3 Dismantling The RCS-985G rack may now be removed from the system cubicle, after which the cubicles may also be removed. DANGER: When the station is in operation, make sure that there is an adequate safety distance to live parts, especially as dismantling is often performed by unskilled personnel.



13.2



Disposal



In every country there are companies specialized in the proper disposal of electronic waste. NOTE: Strictly observe all local and national regulations when disposing of the device.



NR ELECTRIC CO., LTD



305



Chapter13 Decommissioning and Disposal



306



NR ELECTRIC CO., LTD



Chapter14 Ordering Form



Chapter14 Ordering Form 14.1



Loose equipment



Essential information should be provided when user orders loose equipment, such as: Equipment type; Amount of equipment to be ordered; AC rated current and rated voltage input; DC power source supply rated voltage; To be simplified, user can provide such information by finishing the following table and send it to manufacture. Table 14.1-1 Ordering information of RCS-985G



NR



RCS-985G



Ordering form



Item



RCS-985G



* * * * * * *



Protective Functions Standard Configuration Communication Port EIA-232 and 2 x EIA-485



A



EIA-232 and 2 x Optical converter



B



EIA-232 and 2 x Ethernet*



Rated parameters of AC input module 57.7V/Phase; 1 Amp Phase; 50 Hz



1



57.7V/Phase; 1 Amp Phase; 60 Hz



2



57.7V/Phase ; 5 Amp Phase; 50 Hz



3



57.7V/Phase ; 5 Amp Phase; 60 Hz



4



63.5V/Phase; 1 Amp Phase; 50 Hz



5



63.5V Phase; 1 Amp Phase; 60 Hz



6



63.5V Phase ; 5 Amp Phase; 50 Hz



7



63.5V Phase ; 5 Amp Phase; 60 Hz



8



NR ELECTRIC CO., LTD



307



Chapter14 Ordering Form Auxiliary Voltage rating 110/125 Vdc



1



220/250 Vdc



2



Binary input power source supply External 24Vdc



1



External 48Vdc* External 110/125Vdc



3



External 220/250Vdc



4



Communication medium



Shielded twisted pair wires



T



Optical Fiber



O



Communication Protocol IEC 60870-5-103



S



MODBUS



M



IEC 61850*



E



Terminal Type Jointing Terminal



C



Screw terminal Block



S



14.2



Panel installed



If user orders panels too, following information in addition to what is mentioned in table 13.1.1 should be provided. Manufacturer should be informed as early as possible if special requirement is included. The general information includes but not all: Amount and type of the panels; Dimension of the panel (standard dimension is 800mm(W)*600mm(D)*2200mm(H)); Color of panel (Inter Grey, Apple green and light camel grey are recommended colors).



308



NR ELECTRIC CO., LTD



Chapter15 Manual version history



Chapter15 Manual version history In the latest version of the instruction manual, several descriptions on existing features have been modified. Manual version and modification history records Manual Version Source



R1.00



Software



Date



New



Version



R1.00



R3.12



2010-03-22



R1.01



R3.13



2012-06-13



NR ELECTRIC CO., LTD



Description of change Form the original manual. All the signals and settings have been checked according to the software



309



Chapter15 Manual version history



310



NR ELECTRIC CO., LTD



Chapter16 ANNEX



Chapter16 ANNEX 16.1



Appendix A: RCSPC for RCS-985 (User Version)



16.1.1 General RCSPC Configuration and testing program (user version) is developed for the user to configure, test and maintain RCS-985 series protection equipment on site. It comprises four parts: sampled value display, settings reading and modification, report process and trip test. For RCS-985B, these four parts correspond to 4 files 985B3YD_status, 985B3YD _set, 985B3YD_rpt and 985B3YD_tst respectively and are described hereinafter (X represents the special type the protection program, for example, RCS-985B3YD, here, x represent B3YD). Connect RS-232 communication port of the computer and that mounted on left side of front panel of RCS- 985 protection equipment by a cable with DB-9 connectors on both ends. Run the program RCSPC. If the connection is correct, the screen will display ―RCS-985B3YD connected‖, see Figure 16.1-1 . Even if the computer is off line, this picture will be still displayed but the words about connection will disappear.



Figure 16.1-1 RCS-985 being connected There are 3 bars on top of the screen, from top to bottom: title bar, menu bar and tool bar, see Figure 16.1-2.



Figure 16.1-2 Title bar, menu bar and tool bar



First, click the first button of tool bar



parameter, dialog box of communication parameters is



displayed, see Figure 16.1-3. Only the parameter of ―COM port‖ shall be configured as the number of port of computer that is actually connected with the equipment, other parameters shall be configured as the same as displayed values in figure. The title bar shows only title of the program and needs no explanation. Menu bar and tool bar are described as follows:



NR ELECTRIC CO., LTD



311



Chapter16 ANNEX



16.1.2 Menu bar There are five menus in the menu bar: File, Execute, View, Set and Help. Click button of each menu, items will be pulled down, see Figure 16.1-4. The gray items are used not for the user version but others. 1)



File



There is only one item in pull-down menu File, i.e., Exit. Click Exit(X), the program will be exited. 2)



Execute



There are three items in pull-down menu Execute: Setting(E), Download(D) and Trip_Test(T). Click Setting(E), entering settings reading and modification part of the program, please refer to section 16.1.3 for details. Item Download(D) is not used for this program but others. Click Trip_Test(T), entering trip test part of the program, please refer to section 16.1.5 for details. 3)



View



There are five items in pull-down menu View: Toolbar(T), Status(S), Report(L), Status(Z) and Message(M). Item Toolbar specifies whether the tool bar shall be displayed. When the tool bar is displayed, a symbol ―√‖ is put before ―Toolbar (T)‖. If this item is clicked then, the tool bar will be hidden and the symbol ―√‖ will disappear.



Figure 16.1-3 Dialog box of communication Parameters



Figure 16.1-4 Submenu of menu bar Item Status(S) specifies whether status bar in the bottom of the picture shall be displayed. 312



NR ELECTRIC CO., LTD



Chapter16 ANNEX



Click Report(L), entering Report treatment part of the program, please refer to section 16.1.4 for details. Click Status(Z), entering Sampled value display part of the program, see section 16.1.2 for details Click Message(M), data flow between RCSPC program and the protection equipment will be displayed. This is used not for the user version but development version of the program. 4)



Set



There are five items in pull-down menu Set: Switch_CPU_MON(P), Parameter(C), Back_color(B), Font-Color(F) and Font(O). If there is a symbol ―√‖ before item Switch_CPU_MON(P), that means data acquired by module CPU are displayed currently, see Figure 16.1-1. If the item Switch_CPU_MON(P) is clicked then, the data displayed will be changed to those acquired by module MON, see Figure 16.1-5. Meanwhile, symbol ―√‖ will disappear.



Figure 16.1-5 Switching on data acquired by module MON Function of item Parameter(C) is the same as the first button of tool bar parameter. Click this item, dialog box of communication parameters will be displayed, see Figure 16.1-3. Click Back_Color(B), dialog box of background color is displayed. The user can select preferred color for background displayed. Click Font_Color(F), dialog box of font color is displayed. The user can select preferred color for font displaying. Click Font(O), dialog box of name, style and size of the font is displayed. The user can select the preferred ones for font displaying.



NR ELECTRIC CO., LTD



313



Chapter16 ANNEX



5)



Help



There are three items in pull-down menu Help: Help(H), Version(N) and About RCSPC. Click Help(H), commands used for the program will be displayed. It is not necessary for the user to use these commands, and no further information about them is presented here. Click Version(N), historical record about time and description of updating of this program is displayed. Click About RCSPC, developer of this program and copyright declaration will be displayed.



16.1.3 Tool bar There are 23 buttons in the tool bar, in which 16 buttons are enabled. They are depicted in sequence from left to right as follows: 1)



Parameter



Function of this button is the same as that of item Parameter(C) of menu Set of the menu bar. Click this button, dialog box of communication parameters will be displayed, see Figure 16.1-3. 2)



Data parameter



Click this button, other parameters will be displayed. They are data start address, data block size, single data block number, report data number, etc, 11 items in total. These parameters are configured already in the coefficient y and needs no further Configuration on site. 3)



Device type



Click this button, a small dialog box ―please enter device type‖ is displayed. Type of the protection equipment shall be entered. In the RCS-985 case, the device type is 985B3YD. This is used mainly for the user to make configuration in off line condition. 4)



Setting



Function of this button is the same as item Setting(E) of menu Execute of menu bar. Click this button, i.e. entering settings reading and modification part of the program; Please refer to section 16.1.3 for details. 5)



Status



Function of this button is the same as item Status(Z) of menu View of menu bar. Click this button, entering Sampled value display part of the program; Please refer to section 16.1.2 for details. 6)



314



Report



NR ELECTRIC CO., LTD



Chapter16 ANNEX



Function of this button is the same as item Report(L) of menu View of menu bar. Click this button, entering Report view part of the program; Please refer to section 16.1.2 for details. 7)



Trip test



Click this button, entering trip test part of the program; Please refer to section 16.1.2 for details. 8)



Switch to command



When several dialog boxes are displayed, and the operator wants to enter Command mode but not close dialog box, this button can be used to switch on Command and hide dialog boxes. However, it is not needed for the user on site generally. 9)



Download program



This button is used not for this program but others. 10)



CPUMON



Function of this button is the same as item Switch_CPU_MON(P) of menu Set of menu bar. Click this button, data displayed will be changed between those acquired by module CPU and module MON one after another. 11)



Set font



Function of this button is the same as item Font(O) of menu Set of menu bar. 12)



Set font color



Function of this button is the same as item Font_Color(F) of menu Set of menu bar. 13)



Set background color



Function of this button is the same as item Back_Color(B) of menu Set of menu bar. Six buttons



on right hand of



are all gray. They are used not for this



version but others of this program. 14)



SIG RESET



Click this button, all activated output relays and signal relays will be reset. 15)



Synchronize time



This function is not used for the program of RCS-985. NR ELECTRIC CO., LTD



315



Chapter16 ANNEX



16)



Help



Function of this button is the same as item Help(H) of menu Help of menu bar. Besides, some shortcut keys on keyboard of the computer have same functions with items of menu of menu bar or buttons of tool bar: F1 — same as item Help(H) of menu Help and button Help of tool bar; F2 — same as item Parameter(C) of menu Set and button Parameter of tool bar; F3 — same as item Switch_CPU_MON(P) of menu Set and button CPUMON of tool bar; F4 — same as item Setting(E) of menu Execute and button Setting of tool bar; F5 — same as item Status(S) of menu View and button Status of tool bar; F6 — same as item Report(L) of menu View and button Report of tool bar. 16.1.3.1 Sampled Value Displaying Click item Status(S) of menu View or button



Status of tool bar, real time sampled analog



values will be displayed. Click label



, Figure 16.1-6 a) and b) will be displayed. They can be



exchanged to each other by clicking two arrows on



box



right



on left hand of the bottom or pull down hand



of



the



bottom



―Virtual_binary



input/Others_Binary_Input‖. Page 1 shows enabling (―1‖) and disabling (―0‖) of functions:



Figure 16.1-6 Binary input status（page 1, module CPU）



316



NR ELECTRIC CO., LTD



Chapter16 ANNEX



Figure 16.1-7 Binary input status（page 2, module CPU） Page 2 shows mechanical protection inputs as well as others binary input status where ―1‖ is ―yes‖ and ―0‖ is ―no‖.



Figure 16.1-8 Binary input status（page 3, module CPU） Page 3 shows pickup of protective elements where ―1‖ is ―activated‖ and ―0‖ is ―inactivated‖. Figure 16.1-6 a) and b) are pictures of value of module CPU, and can be changed to value of module MON by CPU-MON choose item at the right hand of bottom of this page.



NR ELECTRIC CO., LTD



317



Chapter16 ANNEX



Figure 16.1-9 Example1 of phase angle displaying



Figure 16.1-10 Example2 of phase angle displaying Pull down box at right hand of the bottom is gray. That means these values exist only in module MON and cannot be read from module CPU. 16.1.3.2 Settings Reading and Modification This part is used for reading and modification of settings of the equipment. Click item Setting(E) of menu Execute or the fourth button



Setting of tool bar, settings will be displayed. For



example, Figure 16.1-9 shows the parameters of the equipment. Click label in picture of Setting(E), parameters of the equipment will be displayed as shown in Figure 16.1-9.



318



NR ELECTRIC CO., LTD



Chapter16 ANNEX



Figure 16.1-11 Parameter of the equipment In the same way, user can click other labels in picture of Setting(E) to read and modification all the settings of the equipment. There are 7 buttons in bottom of every picture of the part Settings reading and modification. From left to right, they are: PRINT, DEFAULT, UPLOAD, DOWNLOAD, READ, SAVE and CLOSE and depicted as follows: NO.



Button



Function



1.



PRINT



Print settings displayed in current picture.



2.



DEFAULT



Read and display default settings of RCS-985 from file of RCSPC.



3.



UPLOAD



Read and display actual settings of RCS-985 connected with the PC.



4.



DOWNLOAD



Send current settings displayed on PC to RCS-985 connected.



5.



READ



Read settings from a file saved in computer.



6.



SAVE



Save current settings displayed in the computer as a file.



7.



CLOSE



Close current dialog box.



If default settings are displayed and button UPLOAD is pressed, default settings displayed will be replaced by actual settings of the protection equipment, in which, the settings different from default settings will be displayed in red. Vice versa, if actual settings are displayed and button DEFAULT is pressed, actual settings displayed will be replaced by default settings of the protection equipment, in which, the settings different from actual settings will be displayed in red.



NR ELECTRIC CO., LTD



319



Chapter16 ANNEX



16.1.4 Report There are 3 kinds of reports in this program: tripping report, self-diagnose report and change of status report. The tripping report is displayed first. 16.1.4.1 Tripping report Click item Report(L) of menu View, or click the sixth button



of tool bar, tripping report will be



displayed for a moment. It is the report of operation of protection relays, including number of the report, time of pickup of protection, time interval from pickup to operation, name of the operating protection element and the faulty phase, see Figure 16.1-12.



Figure 16.1-12 Tripping report In order to save time for displaying, report of the latest 3 tripping is displayed firstly. Click the fifth button REFRESH of eight buttons in the bottom of the picture, complete tripping report will be displayed after a longer delay. If oscillogram record of a fault tripping is needed, the record item shall be clicked first, color of this item will be changed to light blue, click the fourth button RECORD at the bottom, then RCSPC starts to read oscillogram data from the protection equipment. Oscillogram data is massive and more time is needed to read it. A dialog block of saving the data displayed as a file will be displayed when data reading is completed. If these data are saved in a file and then oscillogram recorded can be displayed by oscillogram analysis program Drawing.exe or Wave.exe developed by our Company. The oscillogram can be analyzed also if needed. The sixth button SAVE at the bottom is used for saving the report as a file in the computer. The seventh button PRINT is used to print the report. All reports of this program can be saved as file or printed in this way. The eighth button CLOSE is used to close the picture displayed. 16.1.4.2 Diagnose report After click the second button FAIL at bottom of Figure 16.1-13, self-diagnose report will be 320



NR ELECTRIC CO., LTD



Chapter16 ANNEX



displayed for a moment. It is the report of hardware failures, overload, cooling system initiating or other abnormal events detected by the equipment.



Figure 16.1-13 Diagnose report The records are stored in cyclic non-volatile memory and up to 32 events can be recorded. 16.1.4.3 Change of status report After click the third button SW CHG at the bottom of Figure 16.1-13, change of status input report will be displayed for a moment. It is the report of binary input, starting status of the equipment, including serial number of record, time of the change and brief description about the change. The records are stored in cyclic non-volatile memory and up to 32 events can be recorded.



16.1.5 Trip Tests The Trip tests comprise two items: protection tripping test and communication with the host computer test. Object of the tripping test is to check activation of the tripping or signal output relays of the equipment during the test not by applying voltages and currents on the equipment but by operation of the program. Object of the communication with the host computer test is to check correctness of the message sent from the equipment during the test not by applying voltages and currents on the equipment but by operation of the program. 16.1.5.1 Protection tripping test (only for special type of equipment) First, parameter [Test_Trip_Option] shall be set as enabled, if available. Then, click item Trip_Test(T) in menu Execute, or click the seventh button of tool bar



Trip



test, picture of protection tripping test will be displayed as shown in Figure 16.1-14. There is only one item in the picture, i.e., Test_Differential_Trip, differential protection tripping test, NR ELECTRIC CO., LTD



321



Chapter16 ANNEX



click the test button , related output relays will operate, and correspondent signals will be sent. Correctness of these operations can be checked and this button changes to then. Click the red reset button again, all of the operated relays will dropout, test status will be resumed and the reset button will return to



.



Figure 16.1-14 Protection tripping test 16.1.5.2 Communication with the host computer test First, the parameters of [Test_Trip_Option] and [Test_Comm_Option] (if available) shall be set as enabled. Click label



in Figure 16.1-15, picture of communication with the host computer will



be displayed as shown in Figure 16.1-15.



Figure 16.1-15 Communication with host computer test (page 1) 322



NR ELECTRIC CO., LTD



Chapter16 ANNEX



Click test button report.



of any item, relevant activation of this item will be recorded in the



The report will be sent to the host computer, and correctness of the communication can be checked then.



NR ELECTRIC CO., LTD



323