Page 1 3UHIDFH ,QWURGXFWLRQ )XQFWLRQV SIPROTEC 0RXQWLQJ DQG &RPPLVVLRQLQJ Distance Protection 7HFKQLFDO 'DWD 7SA522 $SSHQGL[ V4.3 /LWHUDWXUH Manual *ORVVDU\ ,QGH[ C53000-G1176-C155-3...
Page 2 SIPROTEC, SINAUT, SICAM and DIGSI are registered trade- and software described. However, deviations from the descrip- marks of SIEMENS AG. Other designations in this manual may tion cannot be completely ruled out, so that no liability can be ac- be trademarks that if used by third parties for their own purposes cepted for any errors or omissions contained in the information may violate the rights of the owner.
Page 3: C53000-G1176-C155
(Low-voltage directive 73/23 EEC). This conformity is proved by tests conducted by Siemens AG in accordance with Article 10 of the Council Directive in agreement with the generic standards EN 50081 and EN 61 000-6-2 for EMC directive, and with the standard EN 60 255-6 for the low-voltage directive.
Page 4 4 be desired or should partic- ular problems arise which are not covered sufficiently for the purchaser's purpose, the matter should be referred to the local Siemens representative. Training Courses Individual course offerings may be found in our Training Catalogue, or questions may be directed to our training centre in Nuremberg.
Page 5 Preface Definition QUALIFIED PERSONNEL Prerequisites to proper and safe operation of this product are proper transport, proper storage, setup, installation, operation, and maintenance of the product, as well as careful operation and servicing of the device within the scope of the warn- ings and instructions of this manual.
Page 6 Preface external binary output signal with number (device indication) used as input signal Example of a parameter switch designated FUNCTION with the address 1234 and the possible settings ON and OFF Besides these, graphical symbols are used according to IEC 60 617-12 and IEC 60 617-13 or symbols derived from these standards.
Page 7 Contents Introduction..............17 Overall Operation .
Page 8 Contents Distance protection ............62 2.2.1 Distance protection, general settings.
Page 9 Contents Earth fault overcurrent protection in earthed systems (optional) ....151 2.7.1 Functional Description ........... . 151 2.7.2 Setting Notes .
Page 10 Contents 2.13 Automatic reclosure function (optional) ........227 2.13.1 Method of Operation .
Page 11 Contents 2.19 Monitoring function ............314 2.19.1 Measurement Supervision.
Page 12 Contents 2.21 Auxiliary functions ............346 2.21.1 Processing of Messages .
Page 13 Contents Mounting and Commissioning ........... 371 Mounting and Connections .
Page 14 Contents Technical Data ..............431 General .
Page 15 Contents 4.23 Dimensions ............486 4.23.1 Panel Flush and Cubicle Mounting (Housing Size 1/2) .
Page 16 Contents 7SA522 Manual C53000-G1176-C155-3...
Page 17: Introduction
Introduction ® The SIPROTEC 4 7SA522 is introduced in this chapter. The device is presented in its application, characteristics, and scope of functions. Overall Operation Application Scope Characteristics 7SA522 Manual C53000-G1176-C155-3...
Page 18: Overall Operation
1 Introduction Overall Operation ® The digital Distance Protection SIPROTEC 4 7SA522 is equipped with a powerful mi- croprocessor system. This provides fully numerical processing of all functions in the device, from the acquisition of the measured values up to the output of commands to the circuit breakers Figure 1-1 shows the basic structure of the 7SA522.
Page 19 1.1 Overall Operation Figure 1-1 Hardware structure of the digital Distance Protection 7SA522 A voltage measuring input is provided for each phase-earth voltage. A further voltage input (U ) may optionally be used to measure either the displacement voltage (e-n volt- age), for a busbar voltage (for synchronism and voltage check) or any other voltage (for overvoltage protection).
Page 20 1 Introduction Apart from processing the measured values, the microcomputer system µC also exe- Microcomputer System cutes the actual protection and control functions. They especially consist of: • Filtering and conditioning of the measured signals, • Continuous monitoring of the measured quantities •...
Page 21 1.1 Overall Operation on short circuits in the auxiliary voltage supply of the power system are usually bridged by a capacitor (see also Technical Data, Sub-section 4.1). 7SA522 Manual C53000-G1176-C155-3...
Page 22: Application Scope
1 Introduction Application Scope ® The digital distance protection SIPROTEC 4 7SA522 is a selective and quick protec- tion for overhead lines and cables with single- and multi-ended infeeds in radial, ring or any type of meshed systems of any voltage levels. The network neutral can be earthed, compensated or isolated.
Page 23 1.2 Application Scope Apart from the mentioned fault protection functions, additional protection functions are possible, such as multi-stage overvoltage, undervoltage and frequency protection, circuit breaker failure protection and protection against effects of power swings (simul- taneously active as power swing blocking for the distance protection). For the rapid lo- cation of the damage to the line after a fault, a fault locator is integrated which also may compensate the influence of parallel lines.
Page 24 1 Introduction To establish an extensive communication with other digital operating, control and memory components the device may be provided with further interfaces depending on the order variant. The service interface can be operated through data lines. Also, a modem can be con- nected to this interface.
Page 25: Characteristics
1.3 Characteristics Characteristics General Features • Powerful 32-bit microprocessor system • Complete digital processing of measured values and control, from the sampling of the analog input values up to the closing and tripping commands to the circuit breakers • Complete galvanic and reliable separation between internal processing circuits from the measurement, control, and power supply circuits by analog input transduc- ers, binary inputs and outputs and the DC/DC or AC/DC converters •...
Page 26 1 Introduction • Two sets of earth impedance compensation Power Swing Sup- • Power swing detection with dZ/dt measurement with three measuring systems plement (optional) • Power swing detection up to a maximum of 7 Hz swing frequency; • In service also during single-pole dead times •...
Page 27 1.3 Characteristics Transmission of In- • Transmission of the measured values from all ends of the protected object formation (only • Transmission of 4 commands to all ends with numerical pro- tection data trans- • Transmission of 24 additional binary signals to all ends mission) Tripping at Line •...
Page 28 1 Introduction • Alternatively, check of the de-energized state before reclosing • Closing at asynchronous system conditions with prediction of the synchronization time • Settable minimum and maximum voltage • Verification of the synchronous conditions or de-energized state also possible before the manual closing of the circuit breaker, with separate limit values •...
Page 29 1.3 Characteristics • Short dropout and overshoot times User-defined Func- • Freely programmable combination of internal and external signals for the imple- tions mentation of user-defined logic functions; • All common logic functions • Time delays and set point interrogation Commissioning;...
Page 30 1 Introduction • Commissioning aids such as connection and direction checks as well as circuit breaker test functions 7SA522 Manual C53000-G1176-C155-3...
Page 31: Functions
Functions ® This chapter describes the numerous functions available on the SIPROTEC 7SA522. It shows the setting possibilities for all the functions in maximum configura- tion. Instructions for deriving setting values and formulae, where required are provided. Additionally it may be defined which functions are to be used. General Distance protection Power swing detection (optional)
Page 32: General
2 Functions General A few seconds after the device is switched on, the initial display appears in the LCD. ® Configuration of the device functions are made via the DIGSI software from your PC. ® The procedure is described in detail in the SIPROTEC 4 System Description, Order No.
Page 33 2.1 General For changing configuration parameters in the device, password no.7 is required (for parameter set). Without the password, the settings may be read, but may not be mod- ified and transmitted to the device. The functional scope with the available options is set in the Device Configuration dialog box to match system requirements.
Page 34 2 Functions The setting /RJLF QR switches this function to the French specification. This setting is available in the device variants for the region France (only version 7SA522*-**D** or 10th digit of order number = D). At Address %DFN8S 2& you can select the type of characteristic which the time overcurrent protection uses for operation.
Page 35: Settings
2.1 General The setting 7ULS ZLWK 7DFWLRQ 7ULS ZLWKRXW 7DFWLRQ (default setting = Trip with T-action ...) is preferred if single-pole or single-pole/three-pole auto- reclose cycles are provided for and possible. In this case different dead times after single-pole tripping on the one hand and after three-pole tripping on the other hand are possible (for every reclose cycle).
Page 36 2 Functions Addr. Parameter Setting Options Default Setting Comments Earth Distance Quadrilateral Quadrilateral Earth Distance Disabled Power Swing Disabled Disabled Power Swing detection Enabled Teleprot. Dist. PUTT (Z1B) Disabled Teleprotection for Distance prot. POTT UNBLOCKING BLOCKING SIGNALv.ProtInt Disabled DTT Direct Trip Disabled Disabled DTT Direct Transfer Trip...
Page 37: Device
2.1 General Addr. Parameter Setting Options Default Setting Comments Fault Locator Enabled Enabled Fault Locator Disabled BREAKER FAILURE Disabled Disabled Breaker Failure Protection Enabled Trip Cir. Sup. Disabled Disabled Trip Circuit Supervision 1 trip circuit 2 trip circuits 3 trip circuits P.
Page 38: Setting Notes
2 Functions 2.1.2.3 Setting Notes Fault Annuncia- Pickup of a new protective function generally turns off any previously lit LEDs, so that tions only the latest fault is displayed at any time. It can be selected whether the stored LED displays and the spontaneous annunciations on the display appear upon renewed pickup, or only after a renewed trip signal is issued.
Page 39 2.1 General Information Type of In- Comments formation Non Existent Function Not Available >Time Synch >Synchronize Internal Real Time Clock >Reset LED >Reset LED >Annunc. 1 >User defined annunciation 1 >Annunc. 2 >User defined annunciation 2 >Annunc. 3 >User defined annunciation 3 >Annunc.
Page 40: Power System Data 1
2 Functions 2.1.3 Power System Data 1 The device requires certain system and power system data so that it can adapt the implemented functions according to this data. This comprises e.g. nominal system data, nominal data of instrument transformers, polarity and connection type of mea- sured values, in certain cases circuit breaker properties, etc.
Page 41 2.1 General Voltage Connection The device features four voltage measuring inputs, three of which are connected to the set of voltage transformers. Various possibilities exist for the fourth voltage input • Connect the U input to the open delta winding e–n of the voltage transformer set: Address is then set to: 8 WUDQVIRUPHU = 8GHOWD WUDQVI.
Page 42 2 Functions Figure 2-3 Busbar voltage measured via transformer • Connection of the U - input to any other voltage signal U , which can be processed by the overvoltage protection function: Address is then set to: 8 WUDQVIRUPHU = 8[ WUDQVIRUPHU. •...
Page 43 2.1 General Example: Phase current transformers 500 A/5 A Core balance CT 60 A/1 A • Connection of the I input to the earth current of a parallel line (for parallel line com- pensation of the distance protection and/or fault location): Address is then set to: , WUDQVIRUPHU = ,Q SDUDO OLQH and usually address ,,SK &7 = 1.
Page 44: Settings
2 Functions setting values which depend on this distance unit. They have to be re-entered into their corresponding valid addresses. Mode of Earth Im- Matching of the earth to line impedance is an essential prerequisite for the accurate pedance (Residual) measurement of the fault distance (distance protection, fault locator) during earth faults.
Page 45 2.1 General Addr. Parameter Setting Options Default Setting Comments SystemStarpoint Solid Earthed Solid Earthed System Starpoint is Peterson-Coil Isolated U4 transformer Not connected Not connected U4 voltage transformer is Udelta transf. Usync transf. Ux transformer Uph / Udelta 0.10 .. 9.99 1.73 Matching ratio Phase-VT To Open-Delta-VT...
Page 46: Setting Group Changeover
2 Functions 2.1.4 Setting Group Changeover 2.1.4.1 Purpose of the Setting Groups Up to four independent setting groups can be created for establishing the device's function settings. During operation, the user can locally switch between setting groups using the operator panel, binary inputs (if so configured), the operator and service in- terface per PC, or via the system interface.
Page 47: Information List
2.1 General 2.1.4.4 Information List Information Type of In- Comments formation Group A IntSP Group A Group B IntSP Group B Group C IntSP Group C Group D IntSP Group D >Set Group Bit0 >Setting Group Select Bit 0 >Set Group Bit1 >Setting Group Select Bit 1 2.1.5 Power System Data 2...
Page 48 2 Functions The line angle is computed as follows In address the setting /LQH $QJOH = 66° is entered. Address 'LVWDQFH $QJOH specifies the angle of inclination of the R sections of the distance protection polygons. Usually you can also set the line angle here as in address .
Page 49 2.1 General The following applies for the capacitance per distance unit: Calculation Example: 110 kV overhead line 150 mm as above = 0.19 Ω/km = 0.42 Ω/km = 0.008 µF/km Current Transformer 600 A/1 A Voltage transformer 110 kV / 0.1 kV The secondary per distance unit reactance is therefore: In address the setting [ = 0.229 Ω/km is entered.
Page 50 2 Functions Where = Zero sequence resistance of the line = Zero sequence reactance of the line = Positive sequence resistance of the line = Positive sequence reactance of the line These values may either apply to the entire line length or be based on a per unit of line length, as the quotients are independent of length.
Page 51 2.1 General Where = (complex) zero sequence impedance of the line = (complex) positive sequence impedance of the line These values may either apply to the entire line length or be based on a per unit of line length, as the quotients are independent of length. Furthermore it makes no difference if the quotients are calculated with primary or secondary values.
Page 52 2 Functions The magnitude and angle of the earth impedance (residual) compensation factors setting for the first zone Z1 and the remaining zones of the distance protection may be different. This allows the setting of the exact values for the protected line, while at the same time the setting for the back-up zones may be a close approximation even when the following lines have substantially different earth impedance factors (e.g.
Page 53 2.1 General may a smaller setting be useful. A more detailed explanation of parallel line compen- sation can be found in Section 2.2.1 under distance protection. Figure 2-4 Reach with parallel line compensation at II The current ratio may also be calculated from the desired reach of the parallel line compensation and vice versa.
Page 54 2 Functions ® the presetting is sufficient. This setting is only possible via DIGSI at Additional Set- tings. The remaining voltage , which will definitely not be exceeded when the circuit breaker pole is open, is set in address 3ROH2SHQ9ROWDJH. Voltage transformers must be on the line side.
Page 55 2.1 General In the former case the synchronism check function must be configured as available, a busbar voltage must be connected to the device and this must be correctly parame- terized in the power system data (Section 2.1.3.1, address 8 WUDQVIRUPHU = 8V\QF WUDQVI, as well as the the associated factors).
Page 56 2 Functions fault L1–L2–E, i.e. the pickup image is consistent with a two-phase ground fault. If single pole tripping and reclosure is employed, it is therefore desirable that each line only trips and recloses single pole. This is possible with setting SROH FRXSOLQJ = ZLWK 75,3.
Page 57: Settings
2.1 General 2.1.5.2 Settings Addresses which have an appended "A" can only be changed with DIGSI, under Ad- ditional Settings. The table indicates region-specific presettings. Column C (configuration) indicates the corresponding secondary nominal current of the current transformer. Addr. Parameter Setting Options Default Setting Comments...
Page 58: Information List
2 Functions Addr. Parameter Setting Options Default Setting Comments 1128 RATIO Par. Comp 50 .. 95 % 85 % Neutral current RATIO Par- allel Line Comp 1130A PoleOpenCurrent 0.05 .. 1.00 A 0.10 A Pole Open Current Thresh- 0.25 .. 5.00 A 0.50 A 1131A PoleOpenVoltage...
Page 59 2.1 General Information Type of In- Comments formation >Manual Close >Manual close signal >Close Cmd. Blk >Block all Close commands from external >FAIL:Feeder VT >Failure: Feeder VT (MCB tripped) >FAIL:Bus VT >Failure: Busbar VT (MCB tripped) >CB1 Pole L1 >CB1 Pole L1 (for AR,CB-Test) >CB1 Pole L2 >CB1 Pole L2 (for AR,CB-Test) >CB1 Pole L3...
Page 60: Oscillographic Fault Records
2 Functions Information Type of In- Comments formation 1pole open L2 Single pole open detected in L2 1pole open L3 Single pole open detected in L3 2.1.6 Oscillographic Fault Records 2.1.6.1 Description The 7SA522 distance protection is equipped with a fault recording function. The in- stantaneous values of the measured quantities or i and u...
Page 61: Settings
2.1 General is also the extent of a fault recording (address :$9()250 '$7$ = )DXOW HYHQW). If automatic reclosure is implemented, the entire system disturbance — pos- sibly with several reclose attempts — up to the ultimate fault clearance can be stored (address :$9()250 '$7$ = 3RZ6\V)OW).
Page 62: Distance Protection
2 Functions Distance protection Distance protection is the main function of the device. It is characterized by high mea- suring accuracy and the ability to adapt to the given system conditions. It is supple- mented by a number of additional functions. 2.2.1 Distance protection, general settings 2.2.1.1...
Page 63 2.2 Distance protection Negative Sequence On long, heavily loaded lines, the earth current measurement could be overstabilized Current 3I by large currents (ref. Figure 2-7). To ensure secure detection of earth faults in this case, a negative sequence comparison stage is additionally provided. In the event of a single-phase fault, the negative sequence current I has approximately the same magnitude as the zero sequence current I...
Page 64 2 Functions The earth fault recognition alone does not cause a general pickup of the distance pro- tection, but merely controls the further fault detection modules. It is only alarmed in case of a general fault detection. Figure 2-9 Logic of the earth fault detection Earth Fault Recog- In order to prevent undesired pickup of the earth fault detection, caused by load cur- nition during...
Page 65: Calculation Of The Impedances
2.2 Distance protection 2.2.1.2 Calculation of the Impedances A separate measuring system is provided for each of the six possible impedance loops L1-E, L2-E, L3-E, L1-L2, L2-L3, L3-L1. The phase-earth loops are evaluated when an earth fault detection is recognized and the phase current exceeds a settable minimum value 0LQLPXP ,SK!.
Page 66 2 Functions Figure 2-12 Logic of the phase-phase measuring system Phase-Earth Loops For the calculation of the phase-earth loop, for example during a L3–E short-circuit (Figure 2-13) it must be noted that the impedance of the earth return path does not correspond to the impedance of the phase.
Page 67 2.2 Distance protection Figure 2-14 Logic of the phase-earth measuring system Unfaulted Loops The above considerations apply to the relevant short-circuited loop. All six loops are however equated in case of impedance pickup; the impedances of the unfaulted loops are also influenced by the short-circuit currents and voltages in the short-circuited phases.
Page 68 2 Functions Double Faults in In systems with an effectively or low-resistant earthed starpoint, each connection of a Effectively Earthed phase with earth results in a short-circuit condition which must be isolated immediately Systems by the closest protection systems. Fault detection occurs in the faulted loop associat- ed with the faulted phase.
Page 69 2.2 Distance protection Double Earth Faults In isolated or resonant-earthed networks a single earth fault does not result in a short in Non-earthed circuit current flow. There is only a displacement of the voltage triangle (Figure 2-15). Systems For the system operation this state is no immediate danger. The distance protection must not pick up in this case even though the voltage of the phase with the earth fault is equal to zero in the whole galvanically connected system.
Page 70 2 Functions Table 2-3 Evaluation of the Measuring Loops for Multi-phase Pickup in the Non-earthed Network Loop pickup Evaluated loop(s) Setting of parameter 1220 L1-E, L2-E, (L1-L2) L1-E PHASE PREF.2phe = L3 (L1) ACYCLIC L2-E, L3-E, (L2-L3) L3-E L1-E, L3-E, (L3-L1) L3-E L1-E, L2-E, (L1-L2) L1-E...
Page 71 2.2 Distance protection the other line data — during the parameterisation of the device. The line impedance is calculated similar to the calculation shown earlier. Figure 2-16 Earth fault on a double circuit line Without parallel line compensation, the earth current on the parallel line will in most cases cause the reach threshold of the distance protection to be shortened (under- reach of the distance measurement).
Page 72: Setting Notes
2 Functions Figure 2-17 Circuit breaker closure onto a fault Note When switching onto a three-pole fault with the MHO circle, there will be no voltage in the memory or unfaulted loop voltage available. To ensure fault clearance when switching onto three-pole close-up faults, please make sure that in conjunction with the configured MHO characteristic the instantaneous tripping function is always en- abled.
Page 73 2.2 Distance protection 8! to activate both criteria for earth-fault detection. This setting can only be ® changed via DIGSI at Additional Settings. If you want to detect only the earth cur- rent, set ,! 25 8! and also 8! 7KUHVKROG (address ) to ∞. Note Do under no circumstances set address 8! 7KUHVKROG to ∞, if you have set address () UHFRJQLWLRQ = ,! $1' 8! since earth fault detection will...
Page 74 2 Functions The coupling factors were already set as part of the general protection data (Subsec- tion 2.1.5.1), as was the reach of the parallel line compensation. The loop selection for double earth faults is set in address 3K( IDXOWV Double Earth Faults ®...
Page 75 2.2 Distance protection Load Range On long heavily loaded lines, the risk of encroachment of the load impedance into the tripping characteristic of the distance protection may exist. To exclude the risk of un- wanted fault detection by the distance protection during heavy load flow, a load trap- ezoid characteristic may be set for tripping characteristics with large R-reaches, which excludes such unwanted fault detection by overload.
Page 76: Settings
2 Functions 2.2.1.4 Settings Addresses which have an appended "A" can only be changed with DIGSI, under Ad- ditional Settings. The table indicates region-specific presettings. Column C (configuration) indicates the corresponding secondary nominal current of the current transformer. Addr. Parameter Setting Options Default Setting Comments...
Page 77: Information List
2.2 Distance protection Addr. Parameter Setting Options Default Setting Comments 1232 SOTF zone PICKUP Inactive Instantaneous trip after Zone Z1B SwitchOnToFault Inactive Z1B undirect. 0.100 .. 600.000 Ω; ∞ ∞ Ω 1241 R load (Ø-E) R load, minimum Load Im- pedance (ph-e) 0.020 ..
Page 78 2 Functions Information Type of In- Comments formation 3652 Dist. BLOCK Distance is BLOCKED 3653 Dist. ACTIVE Distance is ACTIVE 3654 Dis.ErrorK0(Z1) Setting error K0(Z1) or Angle K0(Z1) 3655 DisErrorK0(>Z1) Setting error K0(>Z1) or Angle K0(>Z1) 3671 Dis. PICKUP Distance PICKED UP 3672 Dis.Pickup L1 Distance PICKUP L1...
Page 79 2.2 Distance protection Information Type of In- Comments formation 3744 Dis. Z1 L12 Distance Pickup Z1, Loop L12 3745 Dis. Z1 L23 Distance Pickup Z1, Loop L23 3746 Dis. Z1 L31 Distance Pickup Z1, Loop L31 3747 Dis. Z1B L1E Distance Pickup Z1B, Loop L1E 3748 Dis.
Page 80: Distance Protection With Quadrilateral Characteristic (Optional)
2 Functions 2.2.2 Distance protection with quadrilateral characteristic (optional) The 7SA522 distance protection may optionally be provided with polygonal tripping characteristic or with a MHO circle characteristic, or with both depending on which version was ordered. If both characteristics are available, they may be selected sep- arately for phase-phase loops and phase-earth loops.
Page 81 2.2 Distance protection Figure 2-18 Polygonal characteristic (setting values are marked by dots) 7SA522 Manual C53000-G1176-C155-3...
Page 82 2 Functions Determination of For each loop an impedance vector is also used to determine the direction of the short- Direction circuit. Usually, Z is used as for distance calculation. However, depending on the “quality” of the measured values, different computation techniques are used. Immedi- ately after fault inception, the short circuit voltage is disturbed by transients.
Page 83 2.2 Distance protection practice this can only occur when the circuit breaker closes onto a de-energized line, and there is a fault on this line (e.g. closing onto an earthed line). Figure 2-20 shows the theoretical steady-state characteristic. In practice, the position of the directional characteristic when using memorized voltages is dependent on both the source impedance as well as the load transferred across the line prior to fault in- ception.
Page 84 2 Functions Figure 2-21 Directional characteristic with quadrature or memorized voltages Determination of The directional characteristics and their displacement by the source impedance apply Direction in Case of also for lines with series capacitors. If a short-circuit occurs behind the local series ca- Series-compensa- pacitors, the short-circuit voltage however reverses its direction until the protective ted Lines...
Page 85 2.2 Distance protection always smaller than the series reactance — does not cause the apparent direction re- versal (Figure 2-23b). If the short-circuit is located before the capacitor, from the relay location (current trans- former) in reverse direction, the zeniths of the directional characteristics are shifted to the other direction (Figure 2-23c).
Page 86: Setting Notes
2 Functions Figure 2-24 Release logic for one zone (example for Z1) In total, the following zones are available: Independent zones: • 1st zone (fast tripping zone) Z1 with ;=; 5= ‘‘, 5(= ‘(; delayable with 7SKDVH or 7PXOWLSKDVH, • 2nd zone (backup zone) Z2 with ;=; 5= ‘‘, 5(= ‘(; may be delayed by 7SKDVH or 7PXOWLSKDVH, •...
Page 87 2.2 Distance protection In the case of parameterization with secondary quantities, the values derived from the grading coordination chart must be converted to the secondary side of the current and voltage transformers. In general: Accordingly, the reach for any distance zone can be specified as follows: where = Current transformer ratio = Transformation ratio of voltage transformer...
Page 88 2 Functions Most important for this setting on overhead lines, is the resistance of the fault arc. In cables on the other hand, an appreciable arc can not exist. On very short cables, care must however be taken that an arc fault on the local cable termination is inside the set resistance of the first zone.
Page 89 2.2 Distance protection 5(= ‘( (address ) for the R intersection applicable to phase-earth faults and delay time settings. For the first zone, Z1, an additional tilt α can be set by means of the parameter in address =RQH 5HGXFWLRQ. This setting is required if short circuits with a large fault resistance (e.g.
Page 90: Settings
2 Functions SKDVH (address ). If parameter 2S PRGH =% is set to )RUZDUG or 5HYHUVH, a non-directional trip is also possible in case of closure onto a fault if parameter 627) ]RQH is set to =% XQGLUHFW (see also Section 2.2.1.3). Zone Z1B is usually used in combination with automatic reclosure and/or teleprotec- tion schemes.
Page 91 2.2 Distance protection Addr. Parameter Setting Options Default Setting Comments 0 .. 45 ° 0 ° 1307 Zone Reduction Zone Reduction Angle (load compensation) 1311 Op. mode Z2 Forward Forward Operating mode Z2 Reverse Non-Directional Inactive 0.050 .. 600.000 Ω 2.500 Ω...
Page 92: Distance Protection With Mho Characteristic (Optional)
2 Functions Addr. Parameter Setting Options Default Setting Comments 0.050 .. 600.000 Ω 12.000 Ω 1342 R(Z5) Ø-Ø R(Z5), Resistance for ph- ph-faults 0.010 .. 120.000 Ω 2.400 Ω 0.050 .. 600.000 Ω 12.000 Ω 1343 X(Z5)+ X(Z5)+, Reactance for Forward direction 0.010 ..
Page 93 2.2 Distance protection 'LVWDQFH $QJOH which usually corresponds to the line angle ϕ . A load trap- Line and ϕ ezoid with the setting R may be used to cut the area of the load imped- Load Load ance out of the circle. The reach Z may be separately set for each zone;...
Page 94 2 Functions Figure 2-26 Basic MHO circle Characteristics of As the quadrature or memorized voltage (without load transfer) equals the corre- the MHO Circle sponding generator voltage E and does not change after fault inception (refer also to Figure 2-27), the lower zenith is shifted in the impedance diagram by the polarizing quantity k·Z = k·E .
Page 95 2.2 Distance protection Figure 2-27 Polarized MHO circle with quadrature or memorized voltages Selecting Polariza- False directional decisions may be made (tripping or blocking in spite of a reverse tion fault) in short lines the zone reach of which must be very small and in small loop volt- ages the phase angle comparison of which becomes inaccurate between difference voltage and loop voltage.
Page 96 2 Functions Note When switching onto a three-pole fault with the MHO circle, there will be no voltage in the memory or unfaulted loop voltage available. To ensure fault clearance when switching onto three-pole close-up faults, please make sure that in conjunction with the configured MHO characteristic the instantaneous tripping function is always en- abled.
Page 97: Setting Notes
2.2 Distance protection For each distance zone a MHO circle can be defined by means of the parameter Z . It can also be determined for each zone whether its sense of action is forward or re- verse. In the reverse direction, the MHO circle is mirrored in the origin of the coordi- nate system.
Page 98 2 Functions Grading Coordina- It is recommended to initially create a grading coordination chart for the entire galvan- tion Chart ically interconnected system. This diagram should reflect the line lengths with their primary impedances Z in Ω/km. For the reach of the distance zones, the impedances Z are the deciding quantities.
Page 99 2.2 Distance protection For the first zone, a setting of 85 % of the line length should be applied, which results in primary: = 0.85 · 14.70 Ω= 12.49 Ω = 0.85 · X prim or secondary: Each zone can be set using the parameter MODE )RUZDUG or 5HYHUVH (address Independent Zones 2S PRGH =, 2S PRGH =, 2S PRGH =, 2S PRGH Z1 up to Z5...
Page 100 2 Functions Note For instantaneous tripping (undelayed) in the forward direction, the first zone Z1 should always be used, as only the Z1 and Z1B are guaranteed to trip with the shortest operating time of the device. The further zones should be used sequentially for grading in the forward direction.
Page 101: Settings
2.2 Distance protection 2.2.3.3 Settings Addresses which have an appended "A" can only be changed with DIGSI, under Ad- ditional Settings. The table indicates region-specific presettings. Column C (configuration) indicates the corresponding secondary nominal current of the current transformer. Addr. Parameter Setting Options Default Setting...
Page 102: Tripping Logic Of The Distance Protection
2 Functions Addr. Parameter Setting Options Default Setting Comments 0.050 .. 200.000 Ω 10.000 Ω 1432 ZR(Z4) ZR(Z4), Impedance Reach 0.010 .. 40.000 Ω 2.000 Ω 1441 Op. mode Z5 Forward Inactive Operating mode Z5 Reverse Inactive 0.050 .. 200.000 Ω 10.000 Ω...
Page 103 2.2 Distance protection In the case of zones Z1, Z2 and Z1B single-pole tripping is possible for single-phase faults, if the device version includes the single-pole tripping option. Therefore the event output in these cases is provided for each pole. Different trip delay times can be set for single-phase and multiple-phase faults in these zones.
Page 104 2 Functions Figure 2-31 Tripping logic for the 2nd zone Figure 2-32 Tripping logic for the 3rd zone Figure 2-33 Tripping logic for the 4th and 5th zone, shown for Z4 7SA522 Manual C53000-G1176-C155-3...
Page 105 2.2 Distance protection Zone Logic of the The controlled zone Z1B is usually applied as an overreaching zone. The logic is Controlled Zone shown in Figure 2-34. It may be activated via various internal and external functions. The binary inputs for external activation of Z1B of the distance protection are ´!(1$%/( =%µ...
Page 106 2 Functions Figure 2-34 Tripping logic for the controlled zone Z1B 7SA522 Manual C53000-G1176-C155-3...
Page 107: Setting Notes
2.2 Distance protection Tripping Logic The output signals generated by the individual zones are logically connected to the output signals ´'LV*HQ 7ULSµ, ´'LV7ULS S/µ, ´'LV7ULS S/µ, “'LV7ULS S/µ, ´'LV7ULS Sµ in the actual tripping logic. The single-pole in- formation implies that tripping will take place single-pole only. Furthermore, the zone that initiated the tripping is identified;...
Page 108: Power Swing Detection (Optional)
2 Functions Power swing detection (optional) The 7SA522 has an integrated power swing supplement which allows both the block- ing of trips by the distance protection during power swings (power swing blocking) and the calculated tripping during unstable power swings (out-of-step tripping). To avoid uncontrolled tripping, the distance protection devices are supplemented with power swing blocking functions.
Page 109 2.3 Power swing detection (optional) the event of a short-circuit (1), the impedance vector abruptly changes from the load condition into this fault detection range. However, in the event of a power swing, the apparent impedance vector initially enters the power swing range PPOL and only later enters the fault detection range APOL (2).
Page 110 2 Functions Figure 2-37 Pickup characteristic for the power swing detection for the MHO circle Figure 2-38 Impedance vector during power swing Trajectory The rate of change of the impedance vector is very important for the differentiation Continuity and between faults and power swing conditions. This is shown in Figure 2-38. During the Monotony power swing the measured impedance from one sample to the next has a defined change in R and X, referred to as dR(k) and dX(k).
Page 111 2.3 Power swing detection (optional) bility. For release of the power swing detection a further criterion is therefore used. In 2-39 the range for steady state instability is shown. This range is detected in the dis- tance protection relay. This is done by calculating the center of the ellipse and check- ing if the actual measured X value is less than this value.
Page 112 2 Functions In Figure 2-40 a simplified logic diagram for the power swing function is given. This measurement is done on a per phase basis although 2-40 only shows the logic for one phase. Before a power swing detected signal is generated, the measured impedance must be inside the power swing polygon (PPOL).
Page 113: Setting Notes
2.3 Power swing detection (optional) It is possible with FNo. 4160 ´!3RZ 6ZLQJ %/.µ to block the power swing detec- tion via a binary input. Power Swing Trip- If tripping in the event of an unstable power swing (out-of-step condition) is desired, the parameter 3RZHU6ZLQJ WULS = <(6 is set.
Page 114: Settings
2 Functions 2.3.3 Settings Addr. Parameter Setting Options Default Setting Comments 2002 P/S Op. mode All zones block All zones block Power Swing Operating mode Z1/Z1B block Z2 to Z5 block Z1,Z1B,Z2 block 2006 PowerSwing trip Power swing trip 2007 Trip DELAY P/S 0.08 ..
Page 115: Protection Data Interfaces And Communication Topology (Optional)
2.4 Protection data interfaces and communication topology (optional) Protection data interfaces and communication topology (optional) Where a teleprotection scheme is to be used to achieve 100 % instantaneous protec- tion (Section 2.6), digital communication channels can be used for data transmission between the devices.
Page 116 2 Functions Using three ends, at least one 7SA522 device with two protection data interfaces is required. Thus a communication chain can be formed. The number of devices (ad- dress 180%(5 2) 5(/$<) must correspond to the number of ends of the pro- tected object.
Page 117 2.4 Protection data interfaces and communication topology (optional) Table 2-5 Communication via direct connection Module Connector Fibre type Optical Perm. path Maximum length type in the Wavelength attenuation Optical Fibre device Multimode 820 nm 8 dB 1.5 km / 0.95 miles 62.5/125 µm Multimode 820 nm...
Page 118: Setting Notes
2 Functions Functional Logout In an overall topology up to 3 devices that use teleprotection, it is possible to take out one device, e.g. for maintenance purposes, from the protection function “Teleprotec- tion” without having to re-parameterize the device. A logged out device (in the Func- tional Logout) no longer participates in the teleprotection, but still sends and receives remote indications and commands (see Section 2.4.2 under “Communication Topol- ogy”).
Page 119 2.4 Protection data interfaces and communication topology (optional) The devices measure and monitor the transmission times. Deviations are corrected, as long as they are within the permissible range. These permissible ranges are set at address and and can generally be left at their default values. The maximum permissible transmission time (address 3527 7'(/$<) is set to a value that does not exceed the usual value of communication media.
Page 120 2 Functions Figure 2-45 Distance protection topology for 2 ends with 2 devices - example For a protected object with more than two ends (and corresponding devices), the third end is allocated to its device ID at parameter addresses ,' 2) 5(/$< . A maximum of 3 line ends is possible with 3 devices.
Page 121 2.4 Protection data interfaces and communication topology (optional) Figure 2-46 Distance protection topology for 3 ends with 3 devices - example In address /2&$/ 5(/$< you finally indicate the actual local device. Enter the index for each device (according to the consecutive numbering used). Each index from 1 to the entire number of devices must be used once, but may not be used twice.
Page 122: Settings
2 Functions 2.4.3 Settings Addresses which have an appended "A" can only be changed with DIGSI, under Ad- ditional Settings. Addr. Parameter Setting Options Default Setting Comments 4501 STATE PROT I 1 State of protection interface 1 4502 CONNEC. 1 OVER F.optic direct F.optic direct Connection 1 over...
Page 123 2.4 Protection data interfaces and communication topology (optional) Information Type of In- Comments formation 3230 PI1 Datafailure Prot Int 1: Total receiption failure 3231 PI2 Data fault Prot Int 2: Reception of faulty data 3232 PI2 Datafailure Prot Int 2: Total receiption failure 3233 DT inconsistent Device table has inconsistent numbers...
Page 124: Remote Signals Via Protection Data Interface (Optional)
2 Functions Remote signals via protection data interface (optional) 2.5.1 Description 7SA6 allows the transmission of up to 28 items of binary information of any type from one device to the other via the communications links provided for protection tasks. Four of 28 information items are transmitted like protection signals with high priority, i.e.
Page 125: Information List
2.5 Remote signals via protection data interface (optional) 2.5.2 Information List Information Type of In- Comments formation 3541 >Remote Trip1 >Remote Trip 1 signal input 3542 >Remote Trip2 >Remote Trip 2 signal input 3543 >Remote Trip3 >Remote Trip 3 signal input 3544 >Remote Trip4 >Remote Trip 4 signal input...
Page 126 2 Functions Information Type of In- Comments formation 3584 Rem.Sig12recv Remote signal 12 received 3585 Rem.Sig13recv Remote signal 13 received 3586 Rem.Sig14recv Remote signal 14 received 3587 Rem.Sig15recv Remote signal 15 received 3588 Rem.Sig16recv Remote signal 16 received 3589 Rem.Sig17recv Remote signal 17 received 3590 Rem.Sig18recv...
Page 127: Teleprotection For Distance Protection
2.6 Teleprotection for distance protection Teleprotection for distance protection 2.6.1 General Purpose of Telepro- Faults which occur on the protected line, beyond the first distance zone, can only be tection cleared selectively by the distance protection after a delay time. On line sections that are shorter than the smallest sensible distance setting, faults can also not be selec- tively cleared instantaneously.
Page 128: Method Of Operation
2 Functions 7SA522 allows also the transmission of phase-selective signals. This presents the ad- vantage that single-pole automatic reclosure can be carried out even when two single- phase faults occur on different lines in the system. Where the digital protection data interface is used, the signal transmission is always phase segregated.
Page 129: Permissive Underreach Transfer Trip With Zone Acceleration Z1B (Putt)
2.6 Teleprotection for distance protection 2.6.3 Permissive Underreach Transfer Trip with Zone Acceleration Z1B (PUTT) The following procedure is suited for both conventional and digital transmission media. Principle Figure 2-48 shows the operation scheme with zone acceleration for this permissive underreach transfer trip scheme.
Page 130 2 Functions Sequence Figure 2-49 Logic diagram of the permissive underreach transfer trip (PUTT) scheme using Z1B (one line end) 7SA522 Manual C53000-G1176-C155-3...
Page 131: Direct Underreach Transfer Trip
2.6 Teleprotection for distance protection The permissive transfer trip only functions for faults in the “forward” direction. Accord- ingly, the first zone Z1 and the overreach zone Z1B of the distance protection must definitely be set to )RUZDUG in addresses 2S PRGH = and 1351 2S PRGH =%, refer also to Subsection 2.2.2 under the margin heading “Independent Zones Z1 up to Z5”.
Page 132: Permissive Overreach Transfer Trip (Pott)
2 Functions On two terminal lines, the signal transmission may be phase segregated. On three ter- minal lines, the transmit signal is sent to both opposite line ends. The receive signals are then combined with a logical OR function. Figure 2-50 Function diagram of the direct underreach transfer trip scheme 2.6.5 Permissive Overreach Transfer Trip (POTT)
Page 133 2.6 Teleprotection for distance protection In protective relays equipped with a protection data interface, address 7HOHSURW 'LVW allows to set 6,*1$/Y3URW,QW. At address )&7 7HOHS 'LV 3277 can be set. Figure 2-51 Function diagram of the permissive overreach transfer trip method Sequence The permissive overreach transfer trip only functions for faults in the “forward”...
Page 134 2 Functions The circuit breaker can also be tripped at the line end with no or only weak infeed. This “Weak-infeed tripping” is referred to in Section 2.9.1. Figure 2-52 Logic diagram of the permissive overreach transfer trip (POTT) scheme (one line end, conventional, no pro- tection data interface) 7SA522 Manual C53000-G1176-C155-3...
Page 135 2.6 Teleprotection for distance protection Figure 2-53 Logic diagram of the permissive overreach transfer trip (POTT) scheme (one line end, with protection data interface) 7SA522 Manual C53000-G1176-C155-3...
Page 136: Directional Unblocking Scheme
2 Functions Figure 2-54 Logic diagram of the permissive overreach transfer trip (POTT) scheme with protection data interface - continued 2.6.6 Directional Unblocking Scheme The following scheme is suited for conventional transmission media. Principle The unblocking method is a permissive release scheme. It differs from the permissive overreach transfer scheme in that tripping is possible also when no release signal is received from the opposite line end.
Page 137 2.6 Teleprotection for distance protection If the release frequency is received from the opposite end, a trip signal is forwarded to the trip logic. Accordingly, it is a prerequisite for fast tripping, that the fault is recog- nized inside Z1B in the forward direction at both line ends. The distance protection is set such that the overreaching zone Z1B reaches beyond the opposite station (ap- proximately 120% of line length).
Page 138 2 Functions and the blocking signal e.g. ´!'LV78% EO µ disappears. The internal signal “Un- block 1” is passed on to the receive logic, where it initiates the release of the over- reaching zone Z1B of the distance protection (when all remaining conditions have been fulfilled).
Page 139 2.6 Teleprotection for distance protection Figure 2-56 Logic diagram of the unblocking scheme (one line end) 7SA522 Manual C53000-G1176-C155-3...
Page 140: Directional Blocking Scheme
2 Functions Figure 2-57 Unblock logic 2.6.7 Directional Blocking Scheme The following scheme is suited for conventional transmission media. Principle In the case of the blocking scheme, the transmission channel is used to send a block signal from one line end to the other. The signal may be sent directly after fault incep- tion (jump detector above dotted line in Figure 2-58), and stopped immediately, as soon as the distance protection detects a fault in the forward direction, alternatively the signal is only sent when the distance protection detects the fault in the reverse direc-...
Page 141 2.6 Teleprotection for distance protection and the attenuation of the transmitted signal at the fault location may be so severe that reception at the other line cannot necessarily be guaranteed. The scheme functionality is shown in Figure 2-58. Faults inside the overreaching zone Z1B, which is set to approximately 120% of the line length, will initiate tripping if a blocking signal is not received from the other line end.
Page 142 2 Functions Figure 2-59 Logic diagram of the blocking scheme (one line end) 7SA522 Manual C53000-G1176-C155-3...
Page 143: Transient Blocking
2.6 Teleprotection for distance protection As soon as the distance protection has detected a fault in the reverse direction, a blocking signal is transmitted (e.g. ´'LV76(1'µ, FNo 4056). The transmitted signal may be prolonged by setting address accordingly. The blocking signal is stopped if a fault is detected in the forward direction (e.g.
Page 144: Measures For Weak And Zero Infeed
2 Functions Figure 2-60 Transient blocking for permissive schemes 2.6.9 Measures for Weak and Zero Infeed In cases where there is weak or no infeed present at one line end, the distance pro- tection will not pick up. Neither a trip nor a send signal can therefore be generated there.
Page 145 2.6 Teleprotection for distance protection In case of single- or two-pole pickup of the distance protection, it is nevertheless pos- sible to send an echo if measurement of the phases that have not picked up recogniz- es a weak-infeed condition. To avoid an incorrect echo following switching off of the line and reset of the fault de- tection, the RS flip-flop in Figure 2-61 latches the fault detection condition until the signal receive condition resets, thereby barring the release of an echo.
Page 146: Setting Notes
2 Functions Figure 2-61 Logic diagram of the echo function with distance protection with teleprotection 2.6.10 Setting Notes General The teleprotection supplement of distance protection is only in service if it is set during the configuration to one of the possible modes of operation in address . Depend- ing on this configuration, only those parameters which are applicable to the selected mode appear here.
Page 147 2.6 Teleprotection for distance protection Digital Transmis- The following modes are possible with digital transmission using the protection data sion interface (described in Subsection 2.6): 3877 =% Permissive Underreach Transfer Trip with Zone Accel- eration Z1B (PUTT) via protection interface, 3277 Permissive Overreach Transfer Trip (POTT).
Page 148 2 Functions With the release delay 5HOHDVH 'HOD\ (address ) the release of the zone Z1B can be delayed. This is only required for the blocking scheme %/2&.,1* to allow suf- ficient transmission time for the blocking signal during external faults. This delay only has an effect on the receive circuit of the teleprotection;...
Page 149: Settings
2.6 Teleprotection for distance protection If the distance protection and earth fault protection use a common transmission chan- nel, spurious tripping may occur when the distance protection and the earth fault pro- tection create an echo independently of each other. For this scenario, parameter (FKRFKDQQHO (address ) must be set to <(6.
Page 150 2 Functions Information Type of In- Comments formation 4007 >Dis.T.RecCh1L1 >Dis.Tele.Carrier RECEPTION Channel 1,L1 4008 >Dis.T.RecCh1L2 >Dis.Tele.Carrier RECEPTION Channel 1,L2 4009 >Dis.T.RecCh1L3 >Dis.Tele.Carrier RECEPTION Channel 1,L3 4010 >Dis.T.Rec.Ch2 >Dis.Tele. Carrier RECEPTION Channel 2 4030 >Dis.T.UB ub 1 >Dis.Tele. Unblocking: UNBLOCK Channel 1 4031 >Dis.T.UB bl 1 >Dis.Tele.
Page 151: Earth Fault Overcurrent Protection In Earthed Systems (Optional)
2.7 Earth fault overcurrent protection in earthed systems (optional) Earth fault overcurrent protection in earthed systems (optional) In earthed systems, where extremely large fault resistances may exist during earth faults (e.g. overhead lines without earth wire, sandy soil) the fault detection of the dis- tance protection will often not pick up because the resulting earth fault impedance could be outside the fault detection characteristic of the distance protection.
Page 152 2 Functions derived from a set of three star connected current transformers must be available and connected to the device. The zero-sequence voltage is determined by its definition formula . Depending on the application for the fourth voltage input L1-E L2-E L3-E of the device, the zero-sequence voltage can be measured or calculated.
Page 153 2.7 Earth fault overcurrent protection in earthed systems (optional) Figure 2-63 Logic diagram of the 3I >>>–stage Definite Time Very The logic of the high set current stage 3I >> is the same as that of the 3l >>> stage. In all references ,!!! must merely be replaced with ,!!.
Page 154 2 Functions time delay is calculated here based on the type of the set characteristic, the intensity of the earth current and a time multiplier ,S 7LPH 'LDO (IEC characteristic, Figure 2-64) or a time multiplier 7LPH'LDO 7',S (ANSI characteristic). A pre-selection of the available characteristics was already done during the configuration of the protec- tion functions.
Page 155 2.7 Earth fault overcurrent protection in earthed systems (optional) Inverse Time Over- The inverse logarithmic characteristic differs from the other inverse characteristics current Stage with mainly by the fact that the shape of the curve can be influenced by a number of pa- rameters.
Page 156 2 Functions Zero Sequence The zero sequence voltage time protection operates according to a voltage-depen- Voltage Time Pro- dent trip time characteristic. It can be used instead of the time overcurrent stage with tection (U -inverse) inverse time delay.t The voltage/time characteristic can be displaced in voltage direction for a determined constant voltage 8LQY PLQLPXP, valid for t→...
Page 157 2.7 Earth fault overcurrent protection in earthed systems (optional) Figure 2-66 Directional zero-sequence voltage time protection with non-directional backup stage Zero Sequence The zero sequence power protection operates according to a power-dependent trip Power Protection time characteristic. It can be used instead of an inverse time overcurrent stage. The power is calculated from the zero sequence voltage and the zero sequence cur- rent.
Page 158 2 Functions The power-time characteristic can be displaced in power direction via a reference (= basic value for the inverse characteristic for ϕ = ϕ value S ) and in time direc- comp tion by a factor k. Figure 2-67 shows the logic diagram. The tripping time depends on the level of the compensated zero sequence power S as defined above.
Page 159 2.7 Earth fault overcurrent protection in earthed systems (optional) bilization factor (= slope) may be changed by means of the parameter ,SK67$% 6ORSH (address ). It applies to all stages. Figure 2-68 Phase current stabilization Inrush Stabilization If the device is connected to a transformer feeder, large inrush currents can be expect- ed when the transformer is energized;...
Page 160 2 Functions the direction can only be determined if it is polarized with the transformer starpoint current and this exceeds a minimum value corresponding to the setting I >. The direc- tion determination with 3U is inhibited if a “trip of the voltage transformer mcb” is re- ported via binary input.
Page 161 2.7 Earth fault overcurrent protection in earthed systems (optional) Figure 2-70 Directional characteristic with zero sequence power, example S = setting value S FORWARD Selecting the Earth- Since the earth fault protection employs the quantities of the zero sequence system Faulted Phase and the negative sequence system, the faulted phase cannot be determined directly.
Page 162 2 Functions External signaling of the phase-selective pickup is accomplished via the information ´() / VHOHFµ etc. They appear only if the phase was clearly detected. Single- pole tripping requires of course the general prerequisites to be fulfilled (device must be suited for single-pole tripping, single-pole tripping allowed).
Page 163: Setting Notes
2.7 Earth fault overcurrent protection in earthed systems (optional) sure to prevent signal race conditions. It is issued as fault indication ´() %/2&.µ (FNo 1332). If the device is combined with an external automatic reclose device or if single-pole tripping can result from a separate (parallel tripping) protection device, the earth fault protection must be blocked via binary input during the single-pole open condition.
Page 164 2 Functions The earth fault protection must be blocked during single-pole automatic reclose dead time, to avoid pick-up with the false zero sequence values and, if applicable, the neg- ative sequence values arising during this state (address %/2&. S'HDG7LP). A setting of <(6 (default setting for devices with single-pole tripping) is required if single-pole automatic reclosure is to be carried out.
Page 165 2.7 Earth fault overcurrent protection in earthed systems (optional) Inverse Time Stage Also for the inverse time overcurrent stage the operating mode is initially set: address 2S PRGH ,S. The stage can be set to operate )RUZDUG (usually towards with IEC line), 5HYHUVH (usually towards busbar) or 1RQ'LUHFWLRQDO (in both directions).
Page 166 2 Functions ([WUHPHO\ ,QY, 'HILQLWH ,QY. The characteristics and equations they are based on are listed in the Technical Data. The setting of the pickup threshold ,S 3,&.83 (address ) is similar to the setting of definite time stages (see above). In this case it must be noted that a safety margin between the pickup threshold and the set value has already been incorporat- ed.
Page 167 2.7 Earth fault overcurrent protection in earthed systems (optional) Figure 2-72 Curve parameters in the logarithmic–inverse characteristic If you have configured the zero sequence voltage controlled stage (address Zero Sequence (DUWK )DXOW 2& = 8 LQYHUVH) the operating mode is initially set: address Voltage Stage with 2S PRGH ,S.
Page 168 2 Functions Figure 2-73 Characteristic settings of the zero-sequence voltage time dependent stage — without additional times If you have configured the fourth stage as zero sequence power stage (address Zero Sequence (DUWK )DXOW 2& = 6U LQYHUVH), set the mode first: Address 2S PRGH Power Stage ,S.
Page 169 2.7 Earth fault overcurrent protection in earthed systems (optional) The time setting $GG7'(/$< (address ) allows an additional power-indepen- dent delay time to be set. Determination of The direction of each required stage was already determined when setting the differ- Direction ent stages.
Page 170 2 Functions Only if you have set in the 36\VWHP 'DWD (see Section 2.1.3.1) the connection of the fourth current transformer , WUDQVIRUPHU (address ) = ,< VWDUSRLQW, address ,<! will appear. It is the lower threshold for the current measured in the starpoint of a source transformer.
Page 171 2.7 Earth fault overcurrent protection in earthed systems (optional) ,!! 7HOHS%, for stage 3I >>, address ,!!! 7HOHS%, for stage >>>, address ,S 7HOHS%, for stage 3I (if used). If the echo function is used in conjunction with the teleprotection scheme, or if the weak-infeed tripping function should be used, the additional teleprotection stage ,R0LQ 7HOHSURW (address ) must be set to avoid non-selective tripping during through-fault earth current measurement.
Page 172: Settings
2 Functions In applications on transformer feeders or lines that are terminated on transformers it may be assumed that, if very large currents occur, a short circuit has occurred in front of the transformer. In the event of such large currents, the inrush stabilization is inhib- ited.
Page 173 2.7 Earth fault overcurrent protection in earthed systems (optional) Addr. Parameter Setting Options Default Setting Comments 3121 3I0>> 0.05 .. 25.00 A 2.00 A 3I0>> Pickup 0.25 .. 125.00 A 10.00 A 0.00 .. 30.00 sec; ∞ 3122 T 3I0>> 0.60 sec T 3I0>>...
Page 174 2 Functions Addr. Parameter Setting Options Default Setting Comments 3150 3I0p InrushBlk Inrush Blocking 3151 IEC Curve Normal Inverse Normal Inverse IEC Curve Very Inverse Extremely Inv. LongTimeInverse 3152 ANSI Curve Inverse Inverse ANSI Curve Short Inverse Long Inverse Moderately Inv. Very Inverse Extremely Inv.
Page 175: Information List
2.7 Earth fault overcurrent protection in earthed systems (optional) Addr. Parameter Setting Options Default Setting Comments 3174 BLK for DisZone in zone Z1 in each zone Block E/F for Distance Pro- in zone Z1/Z1B tection Pickup in each zone 3182 3U0>(U0 inv) 1.0 ..
Page 176: Teleprotection For Earth Fault Overcurrent Protection (Optional)
2 Functions Teleprotection for earth fault overcurrent protection (optional) 2.8.1 General With the aid of the integrated comparison logic, the directional earth fault protection according to Section 2.7 can be expanded to a directional comparison protection scheme. One of the stages which must be directional )RUZDUG is used for the directional com- Transmission Modes parison.
Page 177: Directional Comparison Pickup
2.8 Teleprotection for earth fault overcurrent protection (optional) The comparison function can be switched on and off by means of the parameter Activation and )&7 7HOHS (), via the system interface (if available) and via binary input (if allo- Deactivation cated).
Page 178 2 Functions Sequence Figure 2-76 shows the logic diagram of the directional comparison scheme for one line end. The directional comparison only functions for faults in the “forward” direction. Accord- ingly the over current stage intended for operation in the direction comparison mode must definitely be set to )RUZDUG (, ',5(&7,21);...
Page 179 2.8 Teleprotection for earth fault overcurrent protection (optional) Figure 2-76 Logic diagram of the directional comparison scheme (one line end) Figure 2-77 and 2-78 shows the logic diagram of the directional comparison scheme for one line end with protection interface. For earth fault protection, only directional comparison pickup is offered for transmis- sion via protection interface.
Page 180 2 Functions Figure 2-77 Logic diagram of the directional comparison scheme with protection data interface (for one device) 7SA522 Manual C53000-G1176-C155-3...
Page 181: Directional Unblocking Scheme
2.8 Teleprotection for earth fault overcurrent protection (optional) Figure 2-78 Logic diagram of the directional comparison scheme with protection data interface (for one device) — con- tinued 2.8.3 Directional Unblocking Scheme The following scheme is suited for conventional transmission media. Principle The unblocking method is a permissive scheme.
Page 182 2 Functions If the unblock frequency is received from the opposite end, a signal is routed to the trip logic. A pre-condition for fast fault clearance is therefore that the earth fault is recog- nized in the forward direction at both line ends. The send signal can be prolonged by T (settable).
Page 183 2.8 Teleprotection for earth fault overcurrent protection (optional) possible. On three terminal lines, the unblock logic can be controlled via both receive channels. If none of the signals is received for a period of more than 10 s the alarm ´() 7HOH8% )DLOµ...
Page 184 2 Functions Figure 2-80 Logic diagram of the unblocking scheme (one line end) 7SA522 Manual C53000-G1176-C155-3...
Page 185: Directional Blocking Scheme
2.8 Teleprotection for earth fault overcurrent protection (optional) Figure 2-81 Unblock logic 2.8.4 Directional Blocking Scheme The following scheme is suited for conventional transmission media. Principle In the case of the blocking scheme, the transmission channel is used to send a block signal from one line end to the other.
Page 186 2 Functions and the attenuation of the transmitted signal at the fault location may be so severe that reception at the other line cannot necessarily be guaranteed. The scheme functionality is shown in Figure 2-82. Earth faults in the forward direction cause tripping if a blocking signal is not received from the opposite line end.
Page 187 2.8 Teleprotection for earth fault overcurrent protection (optional) Figure 2-83 Logic diagram of the blocking scheme (one line end) 7SA522 Manual C53000-G1176-C155-3...
Page 188: Transient Blocking
2 Functions As soon as the earth fault protection has detected a fault in the reverse direction, a blocking signal is transmitted (e.g. ´() 7HOH 6(1'µ, FNo. 1384). The transmitted signal may be prolonged by setting address accordingly. The blocking signal is stopped if a fault is detected in the forward direction (e.g.
Page 189: Measures For Weak Or Zero Infeed
2.8 Teleprotection for earth fault overcurrent protection (optional) 2.8.6 Measures for Weak or Zero Infeed On lines where there is only a single sided infeed or where the star-point is only earthed behind one line end, the line end without zero sequence current cannot gen- erate a permissive signal, as fault detection does not take place there.
Page 190: Setting Notes
2 Functions Figure 2-85 Logic diagram of the echo function for the earth fault protection with teleprotection 2.8.7 Setting Notes General The teleprotection supplement for earth fault protection is only operational if it was set to one of the available modes during the configuration of the device (address ). Depending on this configuration, only those parameters which are applicable to the selected mode appear here.
Page 191 2.8 Teleprotection for earth fault overcurrent protection (optional) Digital Transmis- The following mode is possible with digital transmission using the protection data in- sion terface: 6,*1$/Y3URW,QW = Directional Comparison Pickup. At address )&7 7HOHS () the use of a teleprotection scheme can be switched 21 or 2)).
Page 192 2 Functions Figure 2-87 Possible unfavourable current distribution on a three terminal line during an ex- ternal earth fault The send signal prolongation 6HQG 3URORQJ(address ) must ensure that the Time Settings send signal reliably reaches the opposite line end, even if there is very fast tripping at the sending line end and/or the signal transmission time is relatively long.
Page 193 2.8 Teleprotection for earth fault overcurrent protection (optional) The preset value should be sufficient in most cases. Echo Function In the case of line ends with weak infeed, or not sufficient earth current, the echo func- tion is sensible for the permissive scheme so that the infeeding line end can be re- leased.
Page 194: Settings
2 Functions 2.8.8 Settings Addresses which have an appended "A" can only be changed with DIGSI, under Ad- ditional Settings. Addr. Parameter Setting Options Default Setting Comments 3201 FCT Telep. E/F Teleprotection for Earth Fault O/C 3202 Line Config. Two Terminals Two Terminals Line Configuration Three terminals...
Page 195 2.8 Teleprotection for earth fault overcurrent protection (optional) Information Type of In- Comments formation 1380 EF TeleON/offBI IntSP E/F Teleprot. ON/OFF via BI 1381 EF Telep. OFF E/F Teleprotection is switched OFF 1384 EF Tele SEND E/F Telep. Carrier SEND signal 1386 EF TeleTransBlk E/F Telep.
Page 196: Weak-Infeed Tripping
2 Functions Weak-infeed tripping In cases, where there is no or only weak infeed present at one line end, the distance protection does not pick up there during a short-circuit on the line. The settings and information table at “Weak Infeed” applies for the following functions. If there is no or only a very small zero sequence current at one line end during an earth fault, the earth fault protection can also not function.
Page 197 2.9 Weak-infeed tripping After a security margin time of 40 ms following the start of the receive signal, the weak- infeed tripping is released if the remaining conditions are satisfied: undervoltage, circuit breaker closed and no pickup of the distance protection or of the earth fault pro- tection.
Page 198 2 Functions Figure 2-88 Logic diagram of the weak infeed tripping 7SA522 Manual C53000-G1176-C155-3...
Page 199: Setting Notes
2.9.2 Tripping According to French Specification 2.9.1.2 Setting Notes General It is a prerequisite for the operation of the weak infeed function that it was enabled during the configuration of the device at address :HDN ,QIHHG = (QDEOHG. With the parameter )&7 :HDN ,QIHHG (address ) it is determined whether the device shall trip during a weak infeed condition or not.
Page 200 2 Functions Non-delayed Trip- ping Figure 2-89 Logic diagram for non-delayed tripping 7SA522 Manual C53000-G1176-C155-3...
Page 201 2.9.2 Tripping According to French Specification Trip with Delay Figure 2-90 Logic for delayed tripping 7SA522 Manual C53000-G1176-C155-3...
Page 202: Setting Notes
2 Functions 2.9.2.2 Setting Notes Echo Enable Applications with a transmission channel used by both the distance and the earth fault protection spurious trippings may occur, if distance protection and earth fault protec- tion create an echo independently from each other. In this case parameter (FKRFKDQQHO (address ) has to be set to <(6.
Page 203: Settings
2.9.2 Tripping According to French Specification In address :, QRQ GHOD\HG the stage for instantaneous tripping is switched 2)) or 21 continuously. Trip with Delay The operation of the delayed tripping is determined by three parameters: • Address SRO 7ULS enables a single-pole trip command in case of single- pole faults if set to 21.
Page 204: Information List
2 Functions Addr. Parameter Setting Options Default Setting Comments Time const. τ 2511 1 .. 60 sec 5 sec Time constant Tau 2512A Rec. Ext. 0.00 .. 30.00 sec 0.65 sec Reception extension 2513A T 3I0> Ext. 0.00 .. 30.00 sec 0.60 sec 3I0>...
Page 205 2.9.2 Tripping According to French Specification Information Type of In- Comments formation 4244 Weak TRIP 1p.L3 Weak Infeed TRIP command - Only L3 4245 Weak TRIP L123 Weak Infeed TRIP command L123 4246 ECHO SIGNAL ECHO Send SIGNAL 7SA522 Manual C53000-G1176-C155-3...
Page 206: External Direct And Remote Tripping
2 Functions 2.10 External direct and remote tripping Any signal from an external protection or monitoring device can be coupled into the signal processing of the 7SA522 by means of a binary input. This signal may be de- layed, alarmed and routed to one or several output relays. 2.10.1 Method of Operation External Trip of the Figure 2-92 shows the logic diagram.
Page 207: Setting Notes
2.10 External direct and remote tripping On the receiver side, the local external trip function is used. The receive signal is routed to a binary input which is assigned to the logical binary input function ´!'77 7ULS /µ. If single-pole tripping is desired, you can also use binary inputs ´!'77 7ULS /µ, ´!'77 7ULS /µ...
Page 208: Overcurrent Protection
2 Functions 2.11 Overcurrent protection The 7SA522 features a time overcurrent protection function which can be used as either a back-up or an emergency overcurrent protection. All elements may be config- ured independently of each other and combined according to the user's requirements. 2.11.1 General Whereas the distance protection can only function correctly if the measured voltage signals are available to the device, the emergency overcurrent protection only requires...
Page 209: Method Of Operation
2.11 Overcurrent protection 2.11.2 Method of Operation Measured Values The phase currents are fed to the device via the input transformers of the measuring input. The earth current 3 I is either measured directly or calculated from the phase currents, depending on the ordered device version and usage of the fourth current input I of the device.
Page 210 2 Functions Figure 2-93 Logic diagram of the I>> stage Definite Time The logic of the overcurrent stage I> is the same as that of the I>> stages. In all refer- ences ,SK!! must merely be replaced with ,SK! or. ,!! 3,&.83 with ,!. In Overcurrent Stage I>...
Page 211 2.11 Overcurrent protection Figure 2-94 Logic diagram of the I –stage (inverse time overcurrent protection), example for IEC characteristics Stub Protection A further overcurrent stage is the stub protection. It can however also be used as a normal additional definite time overcurrent stage, as it functions independent of the other stages.
Page 212 2 Functions Figure 2-95 Stub fault at an 1 circuit breaker arrangement If a short circuit current I and/or I flows while the line isolator 1 is open, this implies that a fault in the stub range between the current transformers I , and the line iso- lator exists.
Page 213 2.11 Overcurrent protection Figure 2-96 Logic diagram of stub fault protection Instantaneous Trip- Automatic reclosure is applied in order to instantaneously remove the fault before au- ping before tomatic reclosure. A release signal from an external automatic reclosure device can be injected via binary input ´!2&...
Page 214 2 Functions Pickup Logic and The pickup signals of the individual phases (or the ground) and of the stages are linked Tripping Logic in such a way that both the phase information and the stage which has picked up are output (Table 2-6).
Page 215: Setting Notes
2.11 Overcurrent protection 2.11.3 Setting Notes During the configuration of the device scope of functions (address ) the available General characteristics were determined. Only those parameters that apply to the available characteristics, according to the selected configuration and the version of the device, are accessible in the procedures described below.
Page 216 2 Functions Short-circuit power at the beginning of the line: = 2.5 GVA Current Transformer 600 A / 5 A From that the line impedance Z and the source impedance Z are calculated: /s = √0.19 Ω/km = 0.46 Ω/km + 0.42 = 0.46 Ω/km ·...
Page 217 2.11 Overcurrent protection For the setting of the current pickup value, ,SK! (address ), the maximum oper- Overcurrent Stages >, 3I > ating current is most decisive. Pickup due to overload should never occur, since the (O/C with DT) device in this operating mode operates as fault protection with correspondingly short tripping times and not as overload protection.
Page 218 2 Functions line on to a fault should cause a large fault current. It is important to avoid that the se- lected stage picks up in a transient way during line energization. Overcurrent Stages In the case of the inverse overcurrent stages, various characteristics can be selected, depending on the ordering version of the device and the configuration (address ), , 3I (IDMT pro-...
Page 219 2.11 Overcurrent protection Overcurrent Stages In the case of the inverse overcurrent stages, various characteristics can be selected, , 3I (IDMT pro- depending on the ordering version and the configuration (address). With the ANSI characteristics (address %DFN8S 2& = 72& $16,) are available at address tection with ANSI $16, &XUYH: characteristics)
Page 220: Settings
2 Functions When using the Istub protection the pickup thresholds ,SK! 678% (address ) Additional Stage and ,! 678% (address ) are usually not critical, as this protection function is stub only activated when the line isolator is open which implies that every measured current should represents a fault current.
Page 221 2.11 Overcurrent protection Addr. Parameter Setting Options Default Setting Comments 0.10 .. 25.00 A; ∞ 2620 Iph> 1.50 A Iph> Pickup 0.50 .. 125.00 A; ∞ 7.50 A 0.00 .. 30.00 sec; ∞ 2621 T Iph> 0.50 sec T Iph> Time delay 0.05 ..
Page 222: Information List
2 Functions Addr. Parameter Setting Options Default Setting Comments 2670 I(3I0)p Tele/BI Instantaneous trip via Tele- prot./BI 2671 I(3I0)p SOTF Instantaneous trip after SwitchOnToFault 2680 SOTF Time DELAY 0.00 .. 30.00 sec 0.00 sec Trip time delay after SOTF 2.11.5 Information List Information Type of In- Comments...
Page 223 2.11 Overcurrent protection Information Type of In- Comments formation 7211 O/C TRIP Backup O/C General TRIP command 7212 O/C TRIP 1p.L1 Backup O/C TRIP - Only L1 7213 O/C TRIP 1p.L2 Backup O/C TRIP - Only L2 7214 O/C TRIP 1p.L3 Backup O/C TRIP - Only L3 7215 O/C TRIP L123...
Page 224: Instantaneous High-Current Switch-On-To-Fault Protection (Sotf)
2 Functions 2.12 Instantaneous high-current switch-on-to-fault protection (SOTF) The instantaneous high-current switch-onto-fault protection function is provided to dis- connect immediately and without delay feeders that are switched onto a high-current fault. It is primarily used as fast protection in the event of energizing the feeder while the earth switch is closed, but can also be used every time the feeder is energized —...
Page 225: Setting Notes
2.12 Instantaneous high-current switch-on-to-fault protection (SOTF) Figure 2-97 Logic diagram of the high current switch on to fault protection 2.12.2 Setting Notes Requirement A prerequisite for the operation of the switch-onto-fault protection is that in address 627) 2YHUFXUU = (QDEOHG was set during the configuration of the device scope of functions.
Page 226: Information List
2 Functions 2.12.4 Information List Information Type of In- Comments formation 4253 >BLOCK SOTF-O/C >BLOCK Instantaneous SOTF Overcurrent 4271 SOTF-O/C OFF SOTF-O/C is switched OFF 4272 SOTF-O/C BLOCK SOTF-O/C is BLOCKED 4273 SOTF-O/C ACTIVE SOTF-O/C is ACTIVE 4281 SOTF-O/C PICKUP SOTF-O/C PICKED UP 4282 SOF O/CpickupL1...
Page 227: Automatic Reclosure Function (Optional)
2.13 Automatic reclosure function (optional) 2.13 Automatic reclosure function (optional) Experience shows that about 85% of the arc faults on overhead lines are extinguished automatically after being tripped by the protection. This means that the line can be re- closed. Reclosure is performed by an automatic reclosure function (AR). Automatic reclosure is only permitted on overhead lines because the option of auto- matic extinguishing of a fault arc only exists there.
Page 228: Method Of Operation
2 Functions 2.13.1 Method of Operation Reclosure is performed by an automatic reclosure function (AR). An example of the normal time sequence of a double reclosure is shown in the following Figure. Figure 2-98 Timing diagram of a double-shot reclosure with action time (2nd reclosure successful) The integrated automatic reclosure circuit allows up to 8 reclosure attempts.
Page 229 2.13 Automatic reclosure function (optional) Figure 2-99 Reach control before first reclosure, using distance protection If the distance protection is operated with one of the signal transmission methods de- scribed in Section 2.6 the signal transmission logic controls the overreaching zone, i.e. it determines whether an undelayed trip (or delayed with T1B) is permitted in the event of faults in the overreaching zone (i.e.
Page 230 2 Functions Each short circuit protection function can be parameterized as to whether it should operate with the automatic reclose function or not i.e. whether it should start the reclose function or not. The same goes for external trip commands applied via binary input and/or the trip commands generated by the teleprotection via permissive or in- tertrip signals.
Page 231 2.13 Automatic reclosure function (optional) Example 3: 3 cycles are set. At least the first two cycles are set such that they can start the recloser. The action times are set as in example 1. The first protection trip takes place 0.5s after starting.
Page 232 2 Functions tomatic reclosure is blocked for a manual-close-blocking time 7%/2&. 0&. If a trip command is issued during this time, it can be assumed that a metallic short-circuit is the cause (e.g. closed earth switch). Every trip command within this time is therefore a final trip.
Page 233 2.13 Automatic reclosure function (optional) cycles are not allowed, the reclosure is locked out dynamically. The trip command is final. The latter also applies if the CB trips two poles following a single-pole trip command. The device can only detect this if the auxiliary contacts of each pole are connected in- dividually.
Page 234 2 Functions (adjustable) reclaim time is started. If the reclosure is blocked during the dead time fol- lowing a single-pole trip, immediate three-pole tripping can take place as an option (forced three-pole coupling). If the fault is cleared (successful reclosure), the reclaim time expires and all functions return to their quiescent state.
Page 235 2.13 Automatic reclosure function (optional) via binary inputs. The parameters and intervention possibilities of the fourth cycle also apply to the fifth cycle and onwards. The sequence is the same in principle as in the different reclosure programs described above. However, if the first reclosure attempt was unsuccessful, the reclosure function is not blocked, but instead the next reclose cycle is started.
Page 236 2 Functions send a three pole trip command so that the circuit-breaker does not remain open with one pole (forced three-pole coupling). Dead Line Check If the voltage of a disconnected phase does not disappear following a trip, reclosure (DLC) can be prevented.
Page 237 2.13 Automatic reclosure function (optional) located on the line side of the circuit breaker or that facilities for transfer of a close command to the remote line end exists. Figure 2-101 shows an example with voltage measurement. It is assumed that the device I is operating with defined dead times whereas the adaptive dead time is con- figured at position II.
Page 238 2 Functions CLOSE Command With close command transmission via the digital connection paths the dead times are Transmission only set at one line end. The other line end (or line ends in lines with more than two (Remote-CLOSE) ends) are set to “Adaptive Dead Time (ADT)”. The latter just responds to the received close commands from the transmitting end.
Page 239 2.13 Automatic reclosure function (optional) 382 ´!2QO\ SK $5µ The external reclosure device is only programmed for 1 pole; the stages of the individual protection functions that are activated before reclosure via FNo. 383 only do so in the case of single-phase faults; in the event of multiple phase faults these stages of the individual short-circuit functions do not operate.
Page 240 2 Functions Figure 2-103 Connection example with external auto-reclosure device for 1-/3-pole AR with mode selector switch Figure 2-104 Connection example with external reclosure device for 3-pole AR 7SA522 Manual C53000-G1176-C155-3...
Page 241 2.13 Automatic reclosure function (optional) Controlling the In- If the 7SA522 is equipped with the internal automatic reclosure function, it may also ternal Automatic be controlled by an external protection device. This is of use for example on line ends Reclosure by an with redundant protection or additional back-up protection when the second protection External Protection...
Page 242 2 Functions Instead of the three phase-segregated trip commands, the single-pole and three-pole tripping may also be signalled to the internal automatic reclosure function - provided that the external protection device is capable of this -, i.e. assign the following binary inputs of the 7SA522: 2711 ´!$5 6WDUWµ...
Page 243 2.13 Automatic reclosure function (optional) Figure 2-106 Connection example with external protection device for 3-pole reclosure; AR control mode = with TRIP But if the internal automatic reclose function is controlled by the pickup (only possible for 3-pole pickup: 7ULS PRGH = SROH RQO\), the phase-dedicated pickup signals of the external protection must be connected if distinction shall be made between different types of fault.
Page 244 2 Functions Figure 2-107 Connection example with external protection device for fault detection depen- dent dead time — dead time control by pickup signals of the protection device; AR control mode = with PICKUP 2 Protection Relays If redundant protection is provided for a line and each protection operates with its own with 2 Automatic automatic reclosure function, a certain signal exchange between the two combinations Reclosure Circuits...
Page 245: Setting Notes
2.13 Automatic reclosure function (optional) Figure 2-108 Connection example for 2 protection devices with 2 automatic reclosure functions 2.13.2 Setting Notes General If no reclosure is required on the feeder to which the 7SA522 distance protection is applied (e.g. for cables, transformers, motors or similar), the automatic reclosure func- tion must be inhibited during configuration of the device (see Section 2.1.1.2, address ).
Page 246 2 Functions If, on the other hand, the internal automatic reclosure function is to be used, the type of reclosure must be selected during the configuration of the functions (see Section 2.1.1.2) in address $XWR 5HFORVH the AR control mode and in address the $5 FRQWURO PRGH.
Page 247 2.13 Automatic reclosure function (optional) breaker was detected, no reclosure takes place and a final three-pole trip command is issued. If this is not desired, set address to 0. The options for handling evolving faults are described in Subsection 2.13 under margin heading “Handling Evolving Faults”.
Page 248 2 Functions Table 2-7 In 7SA522 this concerns: Address 3420 AR w/ DIST., i.e. with distance protection Address 3421 AR w/ SOTF-O/C, i.e. with high-current fast tripping Address 3422 AR w/ W/I, i.e. with weak–infeed trip function Address 3423 AR w/ EF-O/C, i.e. with transfer trip and remote trip Address 3424 AR w/ DTT, i.e.
Page 249 2.13 Automatic reclosure function (optional) Adaptive Dead When operating with adaptive dead time, it must be ensured in advance that one end Time (ADT) per line operates with defined dead times and has an infeed. The other (or the others in multi-branch lines) may operate with adaptive dead time.
Page 250 2 Functions ficient synchronism exists. This is applicable on condition that either the internal syn- chronism and voltage check function is available or that an external device is available for synchronism check. If only single-pole reclose cycles are executed or no stability problems are expected during three-pole dead times (e.g.
Page 251 2.13 Automatic reclosure function (optional) The dead time after single-pole tripping (if set) $5 7GHDG7ULS (address ) should be long enough for the short-circuit arc to be extinguished and the surrounding air to be de-ionized so that the reclosure promises to be successful. The longer the line, the longer is this time due to the charging of the conductor capacitances.
Page 252 2 Functions For the 2nd cycle: 3461 2.AR: START Start in 2nd cycle generally allowed 3462 2.AR: T-ACTION Action time for the 2nd cycle 3464 2.AR Tdead 1Flt Dead time after 1-phase pickup 3465 2.AR Tdead 2Flt Dead time after 2-phase pickup 3466 2.AR Tdead 3Flt Dead time after 3-phase pickup 3467 2.AR Tdead1Trip...
Page 253 2.13 Automatic reclosure function (optional) Notes on the Infor- The most important information about automatic reclosure is briefly explained insofar mation Overview as it was not mentioned in the following lists or described in detail in the preceding text. ´!%/. $5F\FOHµ (FNo. 2742) to ´!%/. Q $5µ (FNo. 2745) The respective auto-reclose cycle is blocked.
Page 254: Settings
2 Functions ´!6\QFUHOHDVHµ (FNo. 2731) Release of reclosure by an external synchronism check device if this was requested by the output information ´$5 6\QF5HTXHVWµ (FNo 2865). 2.13.3 Settings Addresses which have an appended "A" can only be changed with DIGSI, under Ad- ditional Settings.
Page 255 2.13 Automatic reclosure function (optional) Addr. Parameter Setting Options Default Setting Comments 3434 T-MAX ADT 0.50 .. 3000.00 sec 5.00 sec Maximum dead time 3435 ADT 1p allowed 1pole TRIP allowed 3436 ADT CB? CLOSE CB ready interrogation before re- closing 3437 ADT SynRequest...
Page 256: Information List
2 Functions Addr. Parameter Setting Options Default Setting Comments 0.01 .. 1800.00 sec; ∞ 3476 3.AR Tdead 2Flt 1.20 sec Dead time after 2phase faults 0.01 .. 1800.00 sec; ∞ 3477 3.AR Tdead 3Flt 0.50 sec Dead time after 3phase faults 0.01 ..
Page 257 2.13 Automatic reclosure function (optional) Information Type of In- Comments formation 2741 >BLK 3phase AR >AR: Block 3phase-fault AR-cycle 2742 >BLK 1.AR-cycle >AR: Block 1st AR-cycle 2743 >BLK 2.AR-cycle >AR: Block 2nd AR-cycle 2744 >BLK 3.AR-cycle >AR: Block 3rd AR-cycle 2745 >BLK 4.-n.
Page 258 2 Functions Information Type of In- Comments formation 2891 AR 3.CycZoneRel AR 3rd cycle zone extension release 2892 AR 4.CycZoneRel AR 4th cycle zone extension release 2893 AR Zone Release AR zone extension (general) 2894 AR Remote Close AR Remote close signal send 7SA522 Manual C53000-G1176-C155-3...
Page 259: Synchronism And Voltage Check (Optional)
2.14 Synchronism and voltage check (optional) 2.14 Synchronism and voltage check (optional) The synchronism and voltage check function ensures, when switching a line onto a busbar, that the stability of the network is not endangered. The voltage of the feeder to be energized is compared to that of the busbar to check conformances in terms of magnitude, phase angle and frequency within certain tolerances.
Page 260 2 Functions If a power transformer is located between the feeder voltage transformers and the bus- bar voltage transformers (Figure 2-110), its vector group can be compensated for by the 7SA522 relay, so that no external matching transformers are necessary. Figure 2-110 Synchronism check across a transformer The synchronism check function in the 7SA522 usually operates together with the in-...
Page 261 2.14 Synchronism and voltage check (optional) The synchronism check function only operates when it is requested to do so. Various possibilities exist to this end: • Measuring request from the internal automatic reclosure device. If the internal au- tomatic reclosing function is set accordingly (one or more reclosing attempts set to synchronism check, see also Section 2.13.2), the measuring request is accom- plished internally.
Page 262 2 Functions 8V\QF 8OLQH = Release for de-energized busbar (Ubus<) and de-en- ergized line (Uline<). 29(55,'( = Release without any check. Each of these conditions can be enabled or disabled individually; combinations are also possible (e.g., release if 8V\QF! 8OLQH or 8V\QF 8OLQH! are fulfilled). Combination of 29(55,'( with other parameters is, of course, not reasonable.
Page 263: Setting Notes
2.14 Synchronism and voltage check (optional) | within the permissible tolerance 0D[ 9ROW • Is the voltage difference |U – U line 'LII? ± 3 Hz? • Are the two frequencies f and f within the permitted operating range f line | lie within the permissible tolerance 0D[ •...
Page 264 2 Functions WARNING! Closing at Asynchronous System Conditions! Closing at asynchronous system conditions requires the closing time of the circuit breaker to be set correctly in the Power system data 1 (address ). Otherwise, faulty synchronization may occur. The synchronism check function can only operate if it was configured as (QDEOHG General (address ) and 8 WUDQVIRUPHU as 8V\QF WUDQVI (address ) during con- figuration of the functional scope.
Page 265 2.14 Synchronism and voltage check (optional) figured conditions must be fulfilled within this time. If not, closure will not be released. If this time is set to ∞, the conditions will be checked until they are fulfilled or the mea- surement request is cancelled.
Page 266 2 Functions Addresses to are relevant to the check conditions before manual closure Synchronism Check Conditions and closing via control command of the circuit breaker. When setting the general pro- before Manual tection data (Power System Data 2, Section 2.1.5.1) it was already decided at address whether synchronism and voltage check should be carried out before manual Closing closing.
Page 267 2.14 Synchronism and voltage check (optional) The five possible release conditions are independent of each other and can be com- bined. Note The closing functions of the device issue individual output indications for the corre- sponding close command. Be sure that the output indications are assigned to the correct output relays.
Page 268: Settings
2 Functions 2.14.3 Settings Addresses which have an appended "A" can only be changed with DIGSI, under Ad- ditional Settings. Addr. Parameter Setting Options Default Setting Comments 3501 FCT Synchronism Synchronism and Voltage Check function ON:w/o CloseCmd 3502 Dead Volt. Thr. 1 ..
Page 269: Information List
2.14 Synchronism and voltage check (optional) Addr. Parameter Setting Options Default Setting Comments 3537 MC Usyn< Uline> Dead bus / live line check before Man.Cl 3538 MC Usyn< Uline< Dead bus / dead line check before Man.Cl 3539 MC O/RIDE Override of any check before Man.Cl 2.14.4 Information List...
Page 270 2 Functions Information Type of In- Comments formation 2976 Sync. U-line>> Sync. Line voltage > Umax (P.3504) 2977 Sync. U-line<< Sync. Line voltage < U> (P.3503) 7SA522 Manual C53000-G1176-C155-3...
Page 271: Undervoltage And Overvoltage Protection (Optional)
2.15 Undervoltage and overvoltage protection (optional) 2.15 Undervoltage and overvoltage protection (optional) Voltage protection has the function to protect electrical equipment against undervolt- age and overvoltage. Both operational states are unfavourable as for example under- voltage may cause stability problems or overvoltage may cause insulation problems. The overvoltage protection in the 7SA522 detects the phase voltages U L1–E L2–E...
Page 272 2 Functions Figure 2-111 Logic diagram of the overvoltage protection for phase voltage Overvoltage The phase–phase overvoltage protection operates just like the phase–earth protection Phase–Phase except that it detects phase–to–phase voltages. Accordingly, phase–to–phase voltag- es which have exceeded one of the stage thresholds 8SKSK! or 8SKSK!!are also indicated.
Page 273 2.15 Undervoltage and overvoltage protection (optional) Figure 2-112 Logic diagram of the overvoltage protection for the positive sequence voltage system Overvoltage U with The overvoltage protection for the positive sequence system may optionally operate Configurable Com- with compounding. The compounding calculates the positive sequence system of the pounding voltages at the remote line end.
Page 274 2 Functions the ohmic line resistance, the line inductance. Figure 2-113 PI equivalent diagram for compounding Overvoltage Nega- The device calculates the negative sequence system voltages according to its defining tive Sequence equation: System U ·(U ·U + a·U j120° where a = e The resulting single–phase AC voltage is fed to the two threshold stages 8! and 8!!.
Page 275 2.15 Undervoltage and overvoltage protection (optional) protection system (working in parallel), the overvoltage protection for the negative se- quence system must be blocked via a binary input during single-pole tripping. Overvoltage Zero Figure 2-115 depicts the logic diagram of the zero sequence voltage stage. The fun- Sequence System damental frequency is numerically filtered from the measuring voltage so that the har- monics or transient voltage peaks remain largely harmless.
Page 276: Undervoltage Protection
2 Functions Figure 2-115 Logic diagram of the overvoltage protection for zero sequence voltage Freely Selectable As the zero sequence voltage stages operate separately and independent from the Single–phase other protective overvoltage functions they can be used for any other single–phase Voltage voltage.
Page 277 2.15 Undervoltage and overvoltage protection (optional) behaviour of the undervoltage protection when the line is deenergized. While the voltage usually remains present or reappears at the busbar side after a trip command and opening of the circuit breaker, it is switched on at the outgoing side. For the und- ervoltage protection this results in a pick-up state being present if the voltage trans- formers are on the outgoing side.
Page 278 2 Functions Figure 2-116 Logic diagram of the undervoltage protection for phase voltages Undervoltage Basically, the phase–phase undervoltage protection operates like the phase–earth Phase–Phase protection except that it detects phase–to–phase voltages. Accordingly, both phases are indicated during pick-up of an undervoltage stage if one of the stage thresholds 8SKSK or 8SKSK was undershot.
Page 279 2.15 Undervoltage and overvoltage protection (optional) Undervoltage Posi- The device calculates the positive sequence system according to its defining equation tive Sequence ·(U + a·U ·U System U j120° where a = e The resulting single–phase AC voltage is fed to the two threshold stages 8 and 8 (see Figure 2-117).
Page 280: Setting Notes
2 Functions 2.15.3 Setting Notes The voltage protection can only operate if it has been set to (QDEOHG during the con- General figuration of the device scope (address ). Compounding is only available if address is set to (QDEO Z FRPS. The overvoltage and undervoltage stages can detect phase-to-earth voltages, phase- to-phase voltages or the symmetrical positive sequence system of the voltages;...
Page 281 2.15 Undervoltage and overvoltage protection (optional) For symmetrical voltages an increase of the positive sequence system corresponds to an AND gate of the voltages. These stages are particularly suited to the detection of steady-state overvoltages on long, weak-loaded transmission lines (Ferranti effect). Here too, the 8! stage (address ) with a longer delay time 7 8! (address ) is used for the detection of steady-state overvoltages (some seconds), the 8!! stage (address ) with the short delay time 7 8!! (address ) is used...
Page 282 2 Functions This protective function also has two stages. The settings of the voltage threshold and the timer values depend on the type of application. Here no general guidelines can be established. The stage 8! (address ) is usually set with a high sensitivity and a longer delay time 7 8! (address ).
Page 283 2.15 Undervoltage and overvoltage protection (optional) of stability problems, the permissible levels and durations of overvoltages must be ob- served. With induction machines undervoltages have an effect on the permissible torque thresholds. If the voltage transformers are located on the line side, the measuring voltages will be missing when the line is disconnected.
Page 284: Settings
2 Functions 2.15.4 Settings Addresses which have an appended "A" can only be changed with DIGSI, under Ad- ditional Settings. Addr. Parameter Setting Options Default Setting Comments 3701 Uph-e>(>) Operating mode Uph-e overvolt- Alarm Only age prot. 1.0 .. 170.0 V; ∞ 3702 Uph-e>...
Page 285 2.15 Undervoltage and overvoltage protection (optional) Addr. Parameter Setting Options Default Setting Comments 3741 U2>(>) Operating mode U2 overvoltage Alarm Only prot. 2.0 .. 220.0 V; ∞ 3742 U2> 30.0 V U2> Pickup 0.00 .. 100.00 sec; ∞ 3743 T U2> 2.00 sec T U2>...
Page 286: Information List
2 Functions 2.15.5 Information List Information Type of In- Comments formation 10201 >Uph-e>(>) BLK >BLOCK Uph-e>(>) Overvolt. (phase-earth) 10202 >Uph-ph>(>) BLK >BLOCK Uph-ph>(>) Overvolt (phase-phase) 10203 >3U0>(>) BLK >BLOCK 3U0>(>) Overvolt. (zero sequence) 10204 >U1>(>) BLK >BLOCK U1>(>) Overvolt. (positive seq.) 10205 >U2>(>) BLK >BLOCK U2>(>) Overvolt.
Page 287 2.15 Undervoltage and overvoltage protection (optional) Information Type of In- Comments formation 10272 3U0> TimeOut 3U0> TimeOut 10273 3U0>> TimeOut 3U0>> TimeOut 10274 3U0>(>) TRIP 3U0>(>) TRIP command 10280 U1> Pickup U1> Pickup 10281 U1>> Pickup U1>> Pickup 10282 U1> TimeOut U1>...
Page 288: Frequency Protection (Optional)
2 Functions 2.16 Frequency protection (optional) The frequency protection function detects abnormally high and low frequencies in the system or in electrical machines. If the frequency lies outside the allowable range, ap- propriate actions are initiated, such as load shedding or separating a generator from the system.
Page 289 2.16 Frequency protection (optional) Operating Ranges Frequency evaluation requires a measured quantity that can be processed. This implies that at least a sufficiently high voltage is available and that the frequency of this voltage is within the working range of the frequency protection. The frequency protection selects automatically the largest of the phase-earth voltag- es.
Page 290: Setting Notes
2 Functions Figure 2-118 Logic diagram of frequency protection for 50 Hz rated frequency 2.16.2 Setting Notes Frequency protection is only in effect and accessible if address )5(48(1&< General 3URW is set to (QDEOHG during configuration of protective functions. If the function is not required, 'LVDEOHG is to be set.
Page 291 2.16 Frequency protection (optional) The following 3 options are available: • Stage 2)): The stage is ineffective; • Stage 21 ZLWK 7ULS: The stage is effective and issues an alarm and a trip command (after time has expired) following irregular frequency deviations; •...
Page 292: Settings
2 Functions Further application examples exist in the field of power stations. The frequency values to be set mainly depend, also in these cases, on the specifications of the power sys- tem/power station operator. In this context, the underfrequency protection also ensures the power station’s own demand by disconnecting it from the power system on time.
Page 293: Information List
2.16 Frequency protection (optional) 2.16.4 Information List Information Type of In- Comments formation 5203 >BLOCK Freq. >BLOCK frequency protection 5206 >BLOCK f1 >BLOCK frequency protection stage f1 5207 >BLOCK f2 >BLOCK frequency protection stage f2 5208 >BLOCK f3 >BLOCK frequency protection stage f3 5209 >BLOCK f4 >BLOCK frequency protection stage f4...
Page 294: Fault Locator
2 Functions 2.17 Fault locator The measurement of the distance to a fault is an important supplement to the protec- tion functions. Availability of the line for power transmission within the system can be increased when the fault is located and cleared faster. 2.17.1 Functional Description Initiation Condi- The fault location function in the 7SA522 distance protection is a function which is in-...
Page 295 2.17 Fault locator Note The distance can only be applicable in the form of kilometres, miles or percent if the relevant line section is homogeneous. If the line is made up of several sections with different reactances, e.g. overhead line - cable sections, then the reactance calculated by the fault location can be evaluated for a separate calculation of the fault distance.
Page 296: Setting Notes
2 Functions Figure 2-119 Fault currents and voltages on double–end fed lines 2.17.2 Setting Notes The fault location function is only in service if it was selected to (QDEOHG during the General configuration of the device functions (Section 2.1.1.2, address ). If the fault location calculation is to be started by the trip command of the protection, set address 67$57 = 75,3.
Page 297: Settings
2.17 Fault locator If the parallel line compensation is used, set address 3DUDO/LQH &RPS to <(6 (presetting for devices with parallel line compensation). Further prerequisites are that • the earth current of the parallel line has been connected to the fourth current input with the correct polarity and •...
Page 298 2 Functions Information Type of In- Comments formation 1128 FL Loop L3L1 OUT_Ev Fault Locator Loop L3L1 1132 Flt.Loc.invalid Fault location invalid 1133 Flt.Loc.ErrorK0 Fault locator setting error K0,angle(K0) 7SA522 Manual C53000-G1176-C155-3...
Page 299: Circuit Breaker Failure Protection (Optional)
2.18 Circuit breaker failure protection (optional) 2.18 Circuit breaker failure protection (optional) The circuit breaker failure protection provides rapid back-up fault clearance, in the event that the circuit breaker fails to respond to a trip command from a protective func- tion of the local circuit breaker.
Page 300 2 Functions Figure 2-121 Simplified function diagram of circuit breaker failure protection controlled by circuit breaker auxiliary contact Current Flow Moni- Each of the phase currents and an additional plausibility current (see below) are fil- toring tered by numerical filter algorithms so that only the fundamental component is used for further evaluation.
Page 301 2.18 Circuit breaker failure protection (optional) Figure 2-122 Current flow monitoring with plausibility currents 3·I and 3·I Processing of the It is the central function control of the device that informs the breaker failure protection Circuit Breaker on the position of the circuit breaker (refer also to Section 2.20.1). Evaluation of the Auxiliary Contacts breaker auxiliary contacts is carried out in the breaker failure protection function only when the current flow monitoring has not picked up.
Page 302 2 Functions (Figure 2-125 left). This input initiates the breaker failure protection even if no current flow is detected. Common Phase Common phase initiation is used, for example, for lines without automatic reclosure, Initiation for lines with only three-pole automatic reclosure, for transformer feeders, or if the bus- bar protection trips.
Page 303 2.18 Circuit breaker failure protection (optional) start signal is maintained until the auxiliary contact criterion reports that the circuit breaker is open. Initiation can be blocked via the binary input ´!%/2&. %NU)DLOµ (e.g. during test of the feeder protection relay). Additionally, an internal blocking option is provided. Figure 2-125 Breaker failure protection with common phase initiation Phase Segregated...
Page 304 2 Functions Figure 2-126 Breaker failure protection with phase segregated initiation — example for initia- tion by an external protection device with release by a fault detection signal Figure 2-127 Breaker failure protection with phase segregated initiation — example for initia- tion by an external protection device with release by a separate set of trip con- tacts Initiation of a single-phase, e.g.
Page 305 2.18 Circuit breaker failure protection (optional) The additional release-signal ´!%) UHOHDVHµ (if assigned to a binary input) affects all starting conditions. Initiation can be blocked via the binary input ´!%/2&. %NU)DLOµ (e.g. during test of the feeder protection relay). Additionally, an internal blocking option is provided.
Page 306 2 Functions the feeder protection, common phase or phase segregated initiation conditions may occur. Tripping by the breaker failure protection is always three-pole. The simplest solution is to start the delay timer 7 (Figure 2-129). The phase-segre- gated initiation signals are omitted if the feeder protection always trips three-pole or if the circuit breaker is not capable of single-pole tripping.
Page 307 2.18 Circuit breaker failure protection (optional) Figure 2-131 Two-stage breaker failure protection with phase segregated initiation Circuit Breaker not There may be cases when it is already obvious that the circuit breaker associated with Operational a feeder protection relay cannot clear a fault, e.g. when the tripping voltage or the trip- ping energy is not available.
Page 308 2 Functions End Fault Protec- An end fault is defined here as a short–circuit which has occurred at the end of a line tion or protected object, between the circuit breaker and the current transformer set. This situation is shown in Figure 2-133. The fault is located — as seen from the current transformers (= measurement location) —...
Page 309: Setting Notes
2.18 Circuit breaker failure protection (optional) ancy is permitted only for a short time interval during a single-pole automatic reclose cycle. The scheme functionality is shown in Figure 2-135. The signals which are processed here are the same as those used for the breaker failure protection. The pole discrep- ancy condition is established when at least one pole is closed (“...
Page 310 2 Functions choice is made in address S5(75,3 7. Set this parameter to <(6 if you wish single-pole trip for the first stage, otherwise to 12. If the breaker does not respond to this trip repetition, the adjacent circuit breakers are tripped after T2 i.e., the circuit breakers of the busbar or of the concerned busbar section and if necessary also the circuit breaker at the remote end unless the fault has been cleared.
Page 311 2.18 Circuit breaker failure protection (optional) pole trip to the busbar. Set 7 (address ) to ∞ or equal to 7SROH (address ) . Be sure that the correct trip commands are assigned to the desired trip re- lay(s). The delay times are determined from the maximum operating time of the feeder circuit breaker, the reset time of the current detectors of the breaker failure protection, plus a safety margin which allows for any tolerance of the delay timers.
Page 312: Settings
2 Functions The pole discrepancy supervision can be switched 21 or 2)) independently at Pole Discrepancy address 3ROH'LVFUHSDQF\. It is only useful if the breaker poles can be oper- Supervision ated individually. It avoids that only one or two poles of the local breaker are open during steady state.
Page 313: Information List
2.18 Circuit breaker failure protection (optional) 2.18.4 Information List Information Type of In- Comments formation 1401 >BF on >BF: Switch on breaker fail protection 1402 >BF off >BF: Switch off breaker fail protection 1403 >BLOCK BkrFail >BLOCK Breaker failure 1415 >BF Start 3pole >BF: External start 3pole 1432...
Page 314: Monitoring Function
2 Functions 2.19 Monitoring function The device incorporates extensive monitoring functions of both the device hardware and software; the measured values are also continually checked to ensure their plau- sibility; the current and voltage transformer secondary circuits are thereby substantial- ly covered by the monitoring function.
Page 315 2.19 Monitoring function Scanning The sampling frequency and the synchronism of the analog-digital converters is con- Frequency tinuously monitored. If any deviations cannot be removed by remedied synchroniza- tion, then the processor system is restarted. Measurement Value Up to four input currents are measured by the device. If the three phase currents and Acquisition –...
Page 316: Software Monitoring
2 Functions This malfunction is signaled as ´)DLO Σ 8 3K(µ (FNo. 165). Note Voltage sum monitoring can operate properly only when an externally formed open delta voltage is connected to the residual voltage input of the relay. 2.19.1.2 Software Monitoring Watchdog For continuous monitoring of the program sequences, a time monitor is provided in the hardware (watchdog for hardware) that expires upon failure of the processor or an in-...
Page 317 2.19 Monitoring function Figure 2-139 Current symmetry monitoring Broken Conductor A broken conductor of the protected line or in the current transformer secondary circuit can be detected, if the minimum current 3ROH2SHQ&XUUHQW flows via the feeder. If the smallest phase currents is below this threshold while the other phase currents are above it, an interruption of a conductor may be assumed.
Page 318 2 Functions the measured values. Phase rotation of measured voltages is checked by verifying the phase sequences of the voltages beforeU beforeU This check takes place if each measured voltage has a minimum magnitude of |, |U |, |U | > 40 V/√3 In case of negative phase rotation, the indication ´)DLO 3K 6HTµ...
Page 319 2.19 Monitoring function the voltage criterion has been removed by correction of the secondary circuit failure, will the blocking automatically reset, thereby releasing the blocked protection func- tions again. Figure 2-141 Logic diagram of the fuse failure monitor with zero and negative sequence system Three-Phase Mea- A three-phase failure of the secondary measured voltage can be distinguished from suring Voltage...
Page 320 2 Functions If such a voltage failure is recognized, the distance protection and all other functions that operate on the basis of undervoltage (e.g. also weak infeed tripping) are blocked until the voltage failure is removed; thereafter the blocking is automatically removed. Definite time overcurrent emergency operation is possible during the voltage failure if the overcurrent protection was configured accordingly (refer to Section 2.11).
Page 321: Malfunction Responses
2.19 Monitoring function 2.19.1.4 Malfunction Responses Depending on the type of malfunction detected, an indication is sent, a restart of the processor system initiated, or the device is taken out of service. After three unsuccess- ful restart attempts, the device is also taken out of service. The operational readiness NC contact (“life contact”) operates to indicate the device is malfunctioning.
Page 322: Setting Notes
2 Functions Monitoring Possible Causes Malfunction Re- Alarm (FNo.) Output sponse Voltage Symmetry External (power system or Message “Fail U balance” As allocated voltage transformer) (167) Voltage phase se- External (power system or Message “Fail Ph. Seq.” (171) as allocated quence connection) Measuring voltage fail-...
Page 323 2.19 Monitoring function at address Σ, )$&725. These settings can only be changed via DIGSI ® at Ad- ditional Settings. Note Current sum monitoring can operate properly only when the residual current of the protected line is fed to the fourth current input (I ) of the relay.
Page 324: Settings
2 Functions 2.19.1.6 Settings Addresses which have an appended "A" can only be changed with DIGSI, under Ad- ditional Settings. The table indicates region-specific presettings. Column C (configuration) indicates the corresponding secondary nominal current of the current transformer. Addr. Parameter Setting Options Default Setting Comments...
Page 325: Information List
2.19 Monitoring function 2.19.1.7 Information List Information Type of In- Comments formation Fail I Superv. Failure: General Current Supervision Failure Σ I Failure: Current Summation Fail I balance Failure: Current Balance Fail U Superv. Failure: general Voltage Supervision Fail Σ U Ph-E Failure: Voltage summation Phase-Earth Fail U balance Failure: Voltage Balance...
Page 326 2 Functions Figure 2-143 Principle of the trip circuit monitoring with two binary inputs Monitoring with two binary inputs does not only detect interruptions in the trip circuit and loss of control voltage, it also monitors the response of the circuit breaker using the position of the circuit breaker auxiliary contacts.
Page 327 2.19 Monitoring function Figure 2-144 Logic diagram of the trip circuit monitoring with two binary inputs Monitoring with The binary input is connected in parallel to the respective command relay contact of One Binary Input the protection device according to Figure 2-145. The circuit breaker auxiliary contact is bridged with a high-ohm substitute resistor R.
Page 328: Setting Notes
2 Functions Figure 2-146 Logic diagram for trip circuit monitoring with one binary input 2.19.2.2 Setting Notes General The number of circuits to be monitored was set during the configuration in address 7ULS &LU 6XS (Section 2.1.1.2). If the trip circuit supervision is not used at all, the setting 'LVDEOHG must be applied there.
Page 329 2.19 Monitoring function Information Type of In- Comments formation 6865 FAIL: Trip cir. Failure Trip Circuit 6866 TripC1 ProgFAIL TripC1 blocked: Binary input is not set 6867 TripC2 ProgFAIL TripC2 blocked: Binary input is not set 6868 TripC3 ProgFAIL TripC3 blocked: Binary input is not set 7SA522 Manual C53000-G1176-C155-3...
Page 330: Function Control And Circuit Breaker Testing
2 Functions 2.20 Function control and circuit breaker testing 2.20.1 Function control The function control is the control centre of the device. It coordinates the sequence of the protection and ancillary functions, processes their decisions and the information coming from the power system. Applications •...
Page 331 2.20 Function control and circuit breaker testing Figure 2-147 Logic diagram of the manual closing procedure Reclosure via the integrated control functions such as — on-site control, control via ® DIGSI , control via serial interface — can have the same effect as manual reclosure, see parameter .
Page 332 2 Functions &ORVHµ must be triggered by a separate contact at the control discrepancy switch (Figure 2-149). If in that latter case a manual close command can also be given by means of an inter- nal control command from the device, such a command must be combined with the manual CLOSE function via parameter 0DQ&ORV ,PS (Figure 2-147).
Page 333: Detection Of The Circuit Breaker Position
2.20 Function control and circuit breaker testing Figure 2-150 Generation of the energisation signal The line energization detection enables the distance protection, earth fault protection, time-overcurrent protection and high-current switch onto fault protection to trip without delay after energization of their line was detected. Depending on the configuration of the distance protection, an undelayed trip command can be generated after energization for each pickup or for pickup in zone Z1B.
Page 334 2 Functions A circuit breaker position logic is incorporated in the device (Figure 2-151). Depending on the type of auxiliary contact(s) provided by the circuit breaker and the method in which these are connected to the device, there are several alternatives of implement- ing this logic.
Page 335 2.20 Function control and circuit breaker testing Figure 2-151 Circuit breaker position logic For Automatic Re- Separate binary inputs comprising information on the position of the circuit breaker are closure and Circuit available for the automatic reclosure and the circuit breaker test. This is important for Breaker Test •...
Page 336: Open Pole Detector
2 Functions For this, separate binary inputs are available, which should be treated the same and configured additionally if necessary. These have a similar significance as the inputs described above for protection applications and are marked with “CB1 ...” to distin- guish them, i.e.: •...
Page 337: Pickup Logic For The Entire Device
2.20 Function control and circuit breaker testing Single-pole Dead During a single-pole dead time, the load current flowing in the two healthy phases Time forces a current flow via earth which may cause undesired pickup. The temporarily ap- plying zero-sequence voltage may also prompt undesired responses of the protection functions.
Page 338: Tripping Logic Of The Entire Device
2 Functions Spontaneous Spontaneous displays are fault messages which appear in the display automatically Displays following a general fault detection or trip command of the device. For the 7SA522, these messages include: “Relay PICKUP”: protective function that picked up; ´38 7LPHµ: the operating time from the general pickup to the dropout of the device, the time is given in ms;...
Page 339 2.20 Function control and circuit breaker testing These alarms can be allocated to LEDs or output relays. In the event of three-pole trip- ping all three alarms pick up. If single-pole tripping is possible, the protection functions generates a group signal for the local displaying of alarms and for the transmission of the alarms to a PC or a central control system, e.g.
Page 340 2 Functions General Trip All trip signals for the protective functions are connected by OR and generate the message ´5HOD\ 75,3µ. This can be allocated to LED or output relay. Terminating the Once a trip command is initiated, it is phase segregatedly latched (in the event of Trip Signal three-pole tripping for each of the three poles) (refer to Figure 2-153).
Page 341 2.20 Function control and circuit breaker testing Reclosure Inter- When tripping the circuit breaker by a protection function the manual reclosure must locking often be blocked until the cause for the protection function operation is found. 7SA522 enables this via the integrated reclose interlocking. The interlocking state (“LOCKOUT”) will be realized by a RS flipflop which is protected against auxiliary voltage failure (see Figure 2-154).
Page 342 2 Functions Breaker Tripping While on feeder without automatic reclosure every trip command by a protection func- Alarm Suppression tion is final, it is desirable, when using automatic reclosure, to prevent the operation detector of the circuit-breaker (transient contact on the breaker) from sending an alarm if the trip of the breaker is not final (Figure 2-155).
Page 343 2.20 Function control and circuit breaker testing Figure 2-156 Breaker tripping alarm suppression — sequence examples Trip Dependent The latching of messages allocated to local LEDs, and the storage of spontaneous Messages messages can be made dependent on whether the device has issued a trip command. This information is then not output if during a system disturbance one or more protec- tion functions have picked up, but no tripping by the 7SA522 resulted because the fault was cleared by a different device (e.g.
Page 344: Setting Notes
2 Functions If the device is equipped with the integrated automatic reclosure, the automatic close commands are also counted, separately for reclosure after single-pole tripping, after three-pole tripping as well as separately for the first reclosure cycle and other reclo- sure cycles.
Page 345: Setting Notes
2.20 Function control and circuit breaker testing Table 2-13 Circuit breaker test programs Serial Test programs Circuit Output indications (FNo) Breaker 1-pole TRIP/CLOSE-cycle phase L1 CB1-TESTtrip L1 (7325) 1-pole TRIP/CLOSE-cycle phase L2 CB1-TESTtrip L2 (7326) 1-pole TRIP/CLOSE-cycle phase L3 CB 1 CB1-TESTtrip L3 (7327) 3-pole TRIP/CLOSE-cycle CB1-TESTtrip 123 (7328)
Page 346: Auxiliary Functions
2 Functions 2.21 Auxiliary functions The additional functions of the 7SA522 distance protection relay include: • processing of messages, • processing of operational measured values, • storage of fault record data. 2.21.1 Processing of Messages After the occurrence of a system fault, data regarding the response of the protective relay and the measured quantities should be saved for future analysis.
Page 347 2.21 Auxiliary functions fault display). In the event of a system fault, information regarding the fault, the so- called spontaneous messages, are displayed instead. After the fault related indica- tions have been acknowledged, the quiescent data are shown again. Acknowledge- ment can be performed by pressing the LED buttons on the front panel (see above).
Page 348 2 Functions auto-reclose cycles are also stored cohesively. Accordingly a system fault may contain several individual fault events (from fault detection up to reset of fault detection). Information to a If the device has a serial system interface, stored information may additionally be Control Centre transferred via this interface to a centralised control and storage device.
Page 349: Statistics
2.21 Auxiliary functions so that the duration of the fault until tripping and up to reset of the trip command can be ascertained. The resolution of the time information is 1ms. A system fault starts with the recognition of the fault by the fault detection, i.e. first pickup of any protection function, and ends with the reset of the fault detection, i.e.
Page 350: Function Description
2 Functions 2.21.2.1 Function Description Counters and The counters and memories of the statistics are saved by the device. Therefore, the Memories information will not get lost in case the auxiliary voltage supply fails. The counters, however, can be reset to zero or to any value within the setting range. ®...
Page 351: Measurement
2.21 Auxiliary functions Information Type of In- Comments formation Σ IL2 1028 Accumulation of interrupted current L2 Σ IL3 1029 Accumulation of interrupted current L3 1030 Max IL1 = Max. fault current Phase L1 1031 Max IL2 = Max. fault current Phase L2 1032 Max IL3 = Max.
Page 352 2 Functions er) positively. Using parameter address 34 VLJQ the signs for these compo- nents can be inverted. The computation of the operational measured values is also executed during an exis- tent system fault in intervals of approx. 0.5s. Table 2-14 Operational measured values of the local device Measured Values...
Page 353: Information List
2.21 Auxiliary functions Remote Measured During communication, the data of the other ends of the protected object can also be Values read out. For each of the devices, the currents and voltages involved as well as phase shifts between the local and transfer measured quantities can be displayed. This is es- pecially helpful for checking the correct and coherent phase allocation and polarity at the different line ends.
Page 354 2 Functions Information Type of In- Comments formation Usync = Usync (synchronism) Ux (separate VT) U1 (positive sequence) U2 (negative sequence) Udiff = U-diff (line-bus) Uline = U-line Ubus = U-bus P (active power) Q (reactive power) PF = Power Factor Freq= Frequency S (apparent power)
Page 355: Demand Measurement Setup
2.21 Auxiliary functions 2.21.4 Demand Measurement Setup Long-term average values are calculated by 7SA522 and can be read out with the point of time (date and time of the last update). 2.21.4.1 Long-term Average Values The long-term average values of the three phase currents I , the positive sequence components I for the three phase currents, and the real power P, reactive power Q,...
Page 356: Information List
2 Functions 2.21.4.4 Information List Information Type of In- Comments formation I1dmd = I1 (positive sequence) Demand Pdmd = Active Power Demand Qdmd = Reactive Power Demand Sdmd = Apparent Power Demand IL1dmd= I L1 demand IL2dmd= I L2 demand IL3dmd= I L3 demand 1052...
Page 357: Information List
2.21 Auxiliary functions Addr. Parameter Setting Options Default Setting Comments 2813 MiMa RESETCYCLE 1 .. 365 Days 7 Days MinMax Reset Cycle Period 2814 MinMaxRES.START 1 .. 365 Days 1 Days MinMax Start Reset Cycle in 2.21.5.4 Information List Information Type of In- Comments formation...
Page 358: Set Points (Measured Values)
2 Functions Information Type of In- Comments formation UL1EMax= U L1E Maximum UL2EMin= U L2E Minimum UL2EMax= U L2E Maximum UL3EMin= U L3E Minimum UL3EMax= U L3E Maximum UL12Min= U L12 Minimum UL12Max= U L12 Maximum UL23Min= U L23 Minimum UL23Max= U L23 Maximum UL31Min=...
Page 359: Limit Value Monitoring
2.21 Auxiliary functions 2.21.6.1 Limit Value Monitoring Set points can be set for the following measured and metered values: • IL1dmd>: Exceeding a preset maximum average value in Phase L1. • IL2dmd>: Exceeding a preset maximum average value in Phase L2. •...
Page 360: Energy
2 Functions 2.21.7 Energy Metered values for real and reactive power are determined by the processor system in the background. They can be displayed at the front of the device, read out via the ® operating interface using a PC with DIGSI , or transferred to a central operational station via the system interface.
Page 361 2.21 Auxiliary functions Information Type of In- Comments formation Wp+= MVMV Wp Forward Wq+= MVMV Wq Forward Wq+= MVMV Wq Forward Wp-= MVMV Wp Reverse Wp-= MVMV Wp Reverse Wq-= MVMV Wq Reverse Wq-= MVMV Wq Reverse 7SA522 Manual C53000-G1176-C155-3...
Page 362: Command Processing
2 Functions 2.22 Command processing ® A control command process is integrated in the SIPROTEC 4 7SA522 to coordinate the operation of circuit breakers and other equipment in the power system. Control commands can originate from four command sources: • Local operation using the keypad on the local user interface of the device, ®...
Page 363: Sequence In The Command Path
2.22 Command processing • Acknowledgment and resetting commands for setting and resetting internal buffers or data stocks. • Information status commands to set/delete the additional “Information Status” item of a process object, such as – Acquisition blocking, – Output blocking. 2.22.1.2 Sequence in the Command Path Security mechanisms in the command path ensure that a switch command can be carried out only if the test of previously established criteria has been successfully com-...
Page 364: Switchgear Interlocking
2 Functions – Command in progress (only one command can be processed at a time for each circuit breaker or switch); – 1–of–n check (for multiple allocations such as common contact relays it is checked if a command procedure was already initiated for the output relays con- cerned).
Page 365 2.22 Command processing Table 2-17 Command types and corresponding messages Type of command Control Cause Message Control issued Switching CO+/– Manual tagging (positive / nega- Manual tagging MT+/– tive) Information state command, Input Input blocking ST+/– *) blocking Information state command, Binary Output ST+/–...
Page 366 2 Functions Figure 2-163 Standard interlockings Source of Command REMOTE includes LOCAL. LOCAL command using substation controller REMOTE Command using remote source such as SCADA through controller to device The device display shows the configured interlocking reasons. The are marked by letters explained in 2-18.
Page 367: Information List
2.22 Command processing Figure 2-164 Example of Configured Interlocking Conditions Control Logic via For the bay interlocking an enabling logic can be structured using the CFC. Via spe- cific release conditions the information “released” or “bay interlocked” are available. ON / OFF). 2.22.1.4 Information List Information Type of In-...
Page 368: Process Data
2 Functions Information Type of In- Comments formation Fan ON/OFF CF_D2 Fan ON/OFF Fan ON/OFF Fan ON/OFF UnlockDT IntSP Unlock data transmission via BI 2.22.3 Process Data During the processing of commands, independently of the further annunciation alloca- tion and processing, command and process feedbacks are sent to the annunciation processing.
Page 369: Information List
2.22 Command processing 2.22.3.2 Information List Information Type of In- Comments formation >Door open >Cabinet door open >CB wait >CB waiting for Spring charged >Err Mot U >Error Motor Voltage >ErrCntrlU >Error Control Voltage >SF6-Loss >SF6-Loss >Err Meter >Error Meter >Tx Temp.
Page 370 2 Functions 7SA522 Manual C53000-G1176-C155-3...
Page 371: Mounting And Commissioning
Mounting and Commissioning This chapter is intended for experienced commissioning staff. The staff must be famil- iar with the commissioning of protection and control systems, with the management of power systems and with the relevant safety rules and guidelines. Under certain cir- cumstances particular power system adaptations of the hardware are necessary.
Page 372: Mounting And Connections
3 Mounting and Commissioning Mounting and Connections General WARNING! Warning of improper transport, storage, installation, and application of the device. Non–observance can result in death, personal injury or substantial property damage. Trouble free and safe use of this device depends on proper transport, storage, instal- lation, and application of the device according to the warnings in this instruction manual.
Page 373 3.1 Mounting and Connections Voltages Connection examples for current and voltage transformer circuits are provided in Ap- pendix A.3. For normal connection the 4th voltage measuring input is not used. Correspondingly, the following setting must be made in address 8 WUDQVIRUPHU = 1RW FRQQHFWHG.
Page 374 3 Mounting and Commissioning Where: = not energized = energized Table 3-1 Changing Setting Groups with Binary Inputs Binary Input Active Group >Set Group Bit >Set Group Bit Group A Group B Group C Group D Figure 3-1 Connection diagram (example) for setting group switching with binary inputs Trip Circuit Super- It must be noted that two binary inputs or one binary input and one bypass resistor R vision...
Page 375 3.1 Mounting and Connections Figure 3-2 Trip circuit supervision with one binary input — Example for trip circuit 1 This results in an upper limit for the resistance dimension, R , and a lower limit R from which the optimal value of the arithmetic mean R should be selected: In order that the minimum voltage for controlling the binary input is ensured, R derived as: To keep the circuit breaker trip coil energized in the above case, R...
Page 376: Hardware Modifications
3 Mounting and Commissioning Example: ® 1.8 mA (SIPROTEC 4 7SA522) BI (HIGH) 19 V for delivery setting for nominal voltages of 24/48/60 V (from the BImin 7SA522); 88 V for delivery setting for nominal voltages of 110/125/220/250 V (from 7SA522);...
Page 377 3.1 Mounting and Connections are described in the following Section at margin heading “Processor Board C-I/O-1 and C-I/O-10”. Nominal Currents The input transformers of the device are set to a nominal current of 1 A or 5 A with jumpers. The position of the jumpers is determined according to the name-plate stick- er.
Page 378: Disassembly
3 Mounting and Commissioning Spare Parts Spare parts can be the buffer battery that provides for storage of the data in the battery-buffered RAM when the voltage supply fails, and the miniature fuse of the in- ternal power supply. Their spatial arrangement is shown in the figure of the processor board.
Page 379 3.1 Mounting and Connections Work on the Plug Connectors Caution! Mind electrostatic discharges: Non–observance can result in minor personal injury or property damage. When handling with plug connectors, electrostatic discharges may emerge by previ- ously touching an earthed metal surface must be avoided. Do not plug or unplug interface connectors under voltage! The arrangement of the boards for housing size is shown in Figure 3-3 and for...
Page 380: Switching Elements On Printed Circuit Boards
3 Mounting and Commissioning Figure 3-4 Front view with housing size after removal of the front cover (simplified and scaled down) 3.1.2.3 Switching Elements on Printed Circuit Boards Input/Output Board The layout of the PCB for the input/output board C-I/O-1 is shown in Figure 3-5, the C-I/O-1 and C-I/O-10 PCB for the input/output board C-I/O-10 is shown in Figure 3-6.
Page 381 3.1 Mounting and Connections Table 3-2 Jumper settings of the nominal voltage of the integrated Power Supply of the input/output module C-I/O-1. Nominal Voltage Jumper 60/110/125 VDC 110/125/220/250 VDC 115 VAC 24/48 VDC Jumpers X51 to X53 are not used 1-2 and 3-4 interchangeable cannot be...
Page 382 3 Mounting and Commissioning Figure 3-5 Input/output board C-I/O-1 with representation of the jumper settings required for the board configuration 7SA522 Manual C53000-G1176-C155-3...
Page 383 3.1 Mounting and Connections Figure 3-6 Input/output board C–I/O-10 with representation of the jumper settings required for the board configuration Check of the control voltages of the binary inputs: BI1 to BI8 (with housing size ) according to Table 3-5. BI1 to BI24 (with housing size depending on the version) according to Table 3-6.
Page 384 3 Mounting and Commissioning Table 3-5 Jumper settings of the Control Voltages of the binary inputs BI1 to BI8 on the input/output board C-I/O-1 with housing size binary inputs Jumper 17 V Threshold 73 V Threshold 154 V Threshold slot 19 X21/X22 X23/X24 X25/X26...
Page 385 3.1 Mounting and Connections Board C-I/O-2 The layout of the PCB for the C-I/O-2 board is shown in Figure 3-7. Figure 3-7 Input/output board C–I/O-2 with representation of jumper settings required for checking configuration settings The contact type of binary output BO13 can be changed from normally open to nor- mally closed (see also overview diagrams in section A.2 of the Appendix).
Page 386 3 Mounting and Commissioning Table 3-8 Jumper setting for contact type of binary output BO13 Jumper Open in quiescent state Closed in quiescent state Presetting (NO) (NC) The set nominal current of the input current transformers are to be checked on the in- put/output board C-I/O-2.
Page 387: Interface Modules
3.1 Mounting and Connections 3.1.2.4 Interface Modules Exchanging Inter- The interface modules are located on the C-CPU-1 board. Figure 3-8 shows the PCB face Modules with the arranged modules. Figure 3-8 C-CPU-1 board with interface modules Please note the following: •...
Page 388 3 Mounting and Commissioning Table 3-10 Exchange Interface Modules Interface Mounting location / inter- Exchange module face System Interface Only interface modules that can be ordered in our facilities via the Service Interface order key (see also Appendix, Section A.1). Protection Data Interface 1 FO5 to FO8 Protection Data Interface 2...
Page 389 3.1 Mounting and Connections Jumper Setting 2-3: The connection to the modem is usually done with star coupler or fibre-optic converter. Therefore the modem control signals according to RS232 standard DIN 66020 are not available. Modem signals are not required since the con- ®...
Page 390 3 Mounting and Commissioning Interface PROFIBUS Figure 3-11 Position of the plug-in jumpers for the configuration of the terminating resistors at the interfaces Profibus (FMS and DP) and DNP3.0 interface RS485 Termination Busbar capable interfaces always require a termination at the last device to the bus, i.e.
Page 391: Reassembly
3.1 Mounting and Connections 3.1.2.5 Reassembly The assembly of the device is done in the following steps: • Insert the boards carefully in the housing. The mounting locations of the boards are shown in Figures 3-3 and 3-4. For the variant of the device designed for surface mounting, use the metal lever to insert the processor board C-CPU-1.
Page 392 3 Mounting and Commissioning Figure 3-13 Example of panel flush mounting of a device (housing size Figure 3-14 Example of panel flush mounting of a unit (housing size 7SA522 Manual C53000-G1176-C155-3...
Page 393: Rack Mounting And Cubicle Mounting
3.1 Mounting and Connections 3.1.3.2 Rack Mounting and Cubicle Mounting Two mounting rails are required for installing a device into a frame or cabinet. The or- dering codes are stated in the Appendix, Section A.1 For housing size (Figure 3-15), there are 4 covers and 4 holes. With housing size (Figure 3-16) there are 6 covers and 6 holes.
Page 394 3 Mounting and Commissioning Figure 3-15 Installation example of a unit in a rack or cubicle (housing size 7SA522 Manual C53000-G1176-C155-3...
Page 395: Panel Surface Mounting
3.1 Mounting and Connections Figure 3-16 Installation example of a unit in a rack or cubicle (housing size 3.1.3.3 Panel Surface Mounting For mounting proceed as follows: • Secure the device to the panel with four screws. For dimensions see the Technical Data in Section 4.23.
Page 396: Checking Connections
3 Mounting and Commissioning Checking Connections 3.2.1 Checking Data Connections of Serial Interfaces The tables of the following margin headings list the pin-assignments for the different serial interfaces of the device and the time synchronization interface. The position of the connections can be seen in the following Figure. Figure 3-17 9-pin D-subminiature female connectors Operator Interface...
Page 397 3.2 Checking Connections Table 3-12 The assignments of the subminiature connector for the various interfaces Pin No. Operator in- RS232 RS 485 PROFIBUS FMS Slave, RS DNP3.0 RS485 terface PROFIBUS DP Slave, RS 485 Shield (with shield ends electrically connected) A/A' (RxD/TxD-N) B/B' (RxD/TxD-P) CNTR-A (TTL)
Page 398: Checking The Protection Data Communication
3 Mounting and Commissioning Optical Fibres WARNING! Warning of laser rays! Non-observance of the following measure can result in death, personal injury or sub- stantial property damage. Do not look directly into the fibre-optic elements, not even with optical devices! Laser Class 3A according to EN 60825-1.
Page 399: Checking System Connections
3.2 Checking Connections Communication Optical fibres are usually used for the connections between the devices and commu- Converter nication converters. The optical fibres are checked in the same manner as the optical fibre direct connection which means for every protection data interface. Make sure that under address &211(& 29(5 or &211(& 29(5 the correct connection type is parameterized.
Page 400 3 Mounting and Commissioning – Is the polarity for current input I correct (if used)? – Is the polarity for voltage input U correct (if used, e.g. for broken delta winding or busbar voltage)? • Check the functions of all test switches that are installed for the purposes of sec- ondary testing and isolation of the device.
Page 401: Commissioning
3.3 Commissioning Commissioning WARNING! Warning of dangerous voltages when operating an electrical device Non-observance of the following measures can result in death, personal injury or sub- stantial property damage. Only qualified people shall work on and around this device. They must be thoroughly familiar with all warnings and safety notices in this instruction manual as well as with the applicable safety steps, safety regulations, and precautionary measures.
Page 402: Test Mode / Transmission Block
3 Mounting and Commissioning WARNING! Warning of dangers evolving from improper primary tests Non-observance of the following measure can result in death, personal injury or sub- stantial property damage. Primary tests may only be carried out by qualified persons who are familiar with com- missioning protection systems, with managing power systems and the relevant safety rules and guidelines (switching, earthing etc.).
Page 403: Testing The System Interface
3.3 Commissioning 3.3.3 Testing the System Interface Prefacing Remarks If the device features a system interface and uses it to communicate with the control ® centre, the DIGSI device operation can be used to test if annunciations are transmit- ted correctly. This test option should however definitely not be used while the device is in service on a “live”...
Page 404 3 Mounting and Commissioning Figure 3-18 System interface test with dialog box: Generate indications — example Changing the By clicking one of the buttons in the column Action you will be asked for the password Operating State No. 6 (for hardware test menus). After you have entered the password correctly you now can send the indiciations individually.
Page 405: Checking The Binary Inputs And Outputs
3.3 Commissioning 3.3.4 Checking the Binary Inputs and Outputs ® Prefacing Remarks The binary inputs, outputs, and LEDs of a SIPROTEC 4 device can be individually ® and precisely controlled in DIGSI 4. This feature is used, for example, to verify control wiring from the device to plant equipment during commissioning.
Page 406 3 Mounting and Commissioning Figure 3-19 Test of the Binary Inputs and Outputs — Example Changing the To change the operating state of a hardware component, click on the associated Operating State switching field in the Scheduled column. Before executing the first change of the operating state the password No. 6 will be re- quested (if activated during configuration).
Page 407: Checking The Communication Topology
3.3 Commissioning Proceed as follows in order to check the binary inputs: • Activate in the system each of the functions which cause the binary inputs. • Check the reaction in the Status column of the dialog box. To do this, the dialogue box must be updated.
Page 408 3 Mounting and Commissioning Figure 3-21 PC interfacing via modem — schematic example Checking a Con- For two devices linked with fibre optical cables (as in Figure 3-20 or 3-21), this con- nection Using nection is checked as follows. If two or more devices are linked or, if two devices have Direct Link been (double-) linked with a ring topology, first check only one link.
Page 409 3.3 Commissioning DANGER! Opening the communication converter There is danger to life by energized parts. Before opening the communication converter, it is absolutely necessary to isolate it from the auxiliary supply voltage at all poles! • Both devices at the link ends have to be switched on. •...
Page 410 3 Mounting and Commissioning • Check the operating indications or in the spontaneous annunciations: – Message 3217 ´3, 'DWD UHIOHFµ (Protection interface 1 data reflection ON) when you test protection data interface 1, – Message 3218 ´3, 'DWD UHIOHFµ (Protection interface 2 data reflection ON) when you test protection data interface 2.
Page 411: Tests For Circuit Breaker Failure Protection
3.3 Commissioning – And if the device configuration is also consistent, i.e. the prerequisites for setting the function scope (Section 2.1.1), Power System Data 1 (2.1.3.1), Power System Data 2 (2.1.5.1) topology and protection data interface parameters (Sec- tion 2.4.2) have been considered, the fault message, i.e. FNo. 3229 ´3, 'DWD IDXOWµ...
Page 412 3 Mounting and Commissioning Caution! Also for tests on the local circuit breaker of the feeder a trip command to the surround- ing circuit breakers can be issued for the busbar. Non-observance of the following measure can result in minor personal injury or prop- erty damage.
Page 413: Current, Voltage, And Phase Rotation Testing
3.3 Commissioning Switch off test current. If start is possible without current flow: • Starting by trip command of the external protection without current flow: Binary input functions ´!%) 6WDUW ZR ,µ and, if necessary, ´!%) UHOHDVHµ (in or spontaneous or fault messages). Trip command (dependent on settings). Busbar Tripping The most important thing is the check of the correct distribution of the trip commands to the adjacent circuit breakers in case of breaker failure.
Page 414: Direction Check With Load Current
3 Mounting and Commissioning If the measured values are not plausible, the connection must be checked and correct- ed after the line has been isolated and the current transformer circuits have been short-circuited. The measurements must then be repeated. Phase Rotation The phase rotation must correspond to the configured phase rotation, in general a clockwise phase rotation.
Page 415: Polarity Check For The Voltage Input U4
3.3 Commissioning Q negative, if reactive power flows toward the busbar. Figure 3-23 Apparent Load Power The power measurement provides an initial indication as to whether the measured values have the correct polarity. If both the active power as well as the reactive power have the wrong sign, the polarity in address &7 6WDUSRLQW must be checked and rectified.
Page 416 3 Mounting and Commissioning necessary because the polarity is irrelevant here. The voltage magnitude was checked before. If the input U is used for the measurement of the displacement voltage U (36\VWHP 'DWD Address 8 WUDQVIRUPHU = 8GHOWD WUDQVI), the po- larity together with the current measurement is checked (see in the following).
Page 417 3.3 Commissioning Figure 3-24 Measuring voltages for the synchronism check • If not, first check whether one of the before named messages 2947 ´6\QF 8GLII!µ or 2949 ´6\QF ϕGLII!µ is available in the spontaneous messages. The message ´6\QF 8GLII!µ indicates that the magnitude (ratio) adaptation is incorrect.
Page 418: Polarity Check For The Current Input I4
3 Mounting and Commissioning 3.3.10 Polarity Check for the Current Input I If the standard connection of the device is used whereby current input I is connected in the starpoint of the set of current transformers (refer also to the connection circuit diagram in the Appendix A.3), then the correct polarity of the earth current path in general automatically results.
Page 419 3.3 Commissioning Figure 3-25 Polarity check for the current input I , example for current transformer set in Holmgreen circuit Note If parameters were changed for this test, they must be returned to their original state after completion of the test ! from Parallel Line If I is the current measured on a parallel line, the above procedure is done with the...
Page 420 3 Mounting and Commissioning Figure 3-26 Polarity check for the current input I , example for earth current of a parallel line from a Power If I is the earth current measured in the starpoint of a power transformer and intended Transformer Star- for the earth fault protection direction determination (for earthed networks), then the point...
Page 421: Measuring The Operating Time Of The Circuit Breaker
3.3 Commissioning At least one stage of the earth fault protection must be set to be directional (address 31xx of the earth fault protection). The test current on the line must exceed the pickup threshold setting of these stages; if necessary the pick-up threshold must be reduced. The parameters that have been changed, must be noted.
Page 422: Testing Of The Teleprotection System With Distance Protection
3 Mounting and Commissioning The circuit breaker is closed manually. At the same time the timer is started. After closing the poles of the circuit breaker, the voltage U appears and the timer is Line stopped. The time displayed by the timer is the real circuit breaker closing time. If the timer is not stopped due to an unfavourable closing moment, the attempt will be repeated.
Page 423 3.3 Commissioning Requirements: 7HOHSURW 'LVW is set in address to one of the comparison Checking at Per- schemes using a permissive signal, i.e. 3277 or 81%/2&.,1*. Furthermore, )&7 missive Scheme 7HOHS 'LV is switched 21 at address . Naturally, the corresponding send and receive signals must also be assigned to the corresponding binary output and input.
Page 424: Testing Of The Signal Transmission With Earth-Fault Protection
3 Mounting and Commissioning On the transmitting end, a fault in the reverse direction is simulated, while at the re- ceiving end a fault in Z1B but beyond Z1 is simulated. This can be achieved with a set of secondary injection test equipment at each end of the line. As long as the transmit- ting end is transmitting, the receiving end may not generate a trip signal, unless this results from a higher distance stage.
Page 425 3.3 Commissioning If the signal transmission path for the earth fault protection is the same path that was already tested in conjunction with the distance protection according to the previous Subsection, then this Subsection is of no consequence and may be omitted. For the functional check of the earth fault protection signal transmission, the distance protection should be disabled, to avoid interference of the tests by signals from the dis- tance protection: address )&7 'LVWDQFH = 2)).
Page 426: Check Of The Signal Transmission For Internal And External Remote Tripping
3 Mounting and Commissioning Requirements: 7HOHSURW () is configured in address to one of the compari- Checking for son schemes using blocking signal, i.e. %/2&.,1*. Furthermore, )&7 7HOHS () Blocking Scheme is switched 21 at address . Naturally, the corresponding send and receive signals must also be assigned to the corresponding binary output and input.
Page 427: Testing User-Defined Functions
3.3 Commissioning sive underreach (see “Check at Permissive Underreach Scheme”); however the re- ceived signal causes a direct trip. For remote transmission, the external command input is employed on the receiving line end; it is therefore a prerequisite that: '77 'LUHFW 7ULS is set to (QDEOHG in address and )&7 'LUHFW 7ULS to 21 at adddress .
Page 428: Triggering Oscillographic Recordings For Test
3 Mounting and Commissioning the source of commands used. With the switch mode it is possible to select between interlocked and non-interlocked switching. Note that non-interlocked switching consti- tutes a safety risk. Switching from a If the device is connected to a remote substation via a system (SCADA) interface, the Remote Control corresponding switching tests may also be checked from the substation.
Page 429 3.3 Commissioning ® Figure 3-29 Triggering oscillographic recording with DIGSI — Example Oscillographic recording is immediately started. During the recording, an annunciation is output in the left area of the status line. Bar segments additionally indicate the progress of the procedure. The SIGRA or the Comtrade Viewer program is required to view and analyse the os- cillographic data.
Page 430: Final Preparation Of The Device
3 Mounting and Commissioning Final Preparation of the Device Firmly tighten all screws. Tighten all terminal screws, including those that are not used. Caution! Inadmissable Tightening Torques Non-observance of the following measure can result in minor personal injury or prop- erty damage: The tightening torques must not be exceeded as the threads and terminal chambers may otherwise be damaged!
Page 431: Technical Data
Technical Data ® This chapter provides the technical data of SIPROTEC 4 device 7SA522 and its in- dividual functions, including the limiting values that under no circumstances may be exceeded. The electrical and functional data for the maximum functional scope are fol- lowed by the mechanical specifications with dimension diagrams.
Page 432: General
4 Technical Data General 4.1.1 Analog Inputs and Outputs Nominal Frequency 50 Hz or 60 Hz (adjustable) Current Inputs Rated current 1 A or 5 A Power Consumption per Phase and Earth Path - at I = 1 A Approx. 0.05 VA - at I = 5 A Approx.
Page 433: Auxiliary Voltage
4.1 General 4.1.2 Auxiliary Voltage DC Voltage Voltage Supply via Integrated Converter Rated auxiliary voltage U 24/48 VDC 60/110/125 110/125/ 220/250 VDC 220/250 VDC Permissible voltage ranges 19 to 58 VDC 48 to 150 VDC 88 to 300 VDC 176 to 300 VDC Superimposed AC ripple voltage, ≤...
Page 434 4 Technical Data ≥ 19 VDC (pu = - for rated voltages 24/48 VDC 60/110/125 VDC pickup) ≤ 14 VDC (do = dropout) ≥ 88 VDC - for rated voltages 110/125/220/250 VDC ≤ 66 VDC ≥ 176 VDC - for rated voltages 220/250 VDC ≤...
Page 435: Communication Interfaces
4.1 General Signalling / Command Relays (see also terminal assignments in Appendix A) Quantity and Data According to the Order Variant (allocatable) Order Variant UL-listed NO Contact NO Contact NO or NC NO contact (normal) (fast) (selectable) (high-speed) 120 VAC Pilot duty, B300 240 VAC Pilot duty, B300...
Page 436 4 Technical Data RS232 Transmission distance 15 m / 50 feet RS485 Transmission distance 1 km / 3280 feet / 0.62 miles Fibre optics (FO) FO connector type ST connector Connection for panel flush mounting Rear panel, mounting location “C” housing Connection for panel surface mounting In console housing at device bottom...
Page 437 4.1 General Fibre optics (FO) FO connector type ST connector Connection for panel flush mounting Rear panel, mounting location “B” housing Connection for panel surface mounting In console housing at case bottom housing λ = 820 nm Optical wavelength Laser Class I according to EN 60825-1/-2 Using glass fibre 50/125 µm or For use of FO 62.5/125 µm Max.
Page 438 If the optical interface is required you shall order the following: 11th position 4 (FMS) or L0A (DP) and additionally: For single ring: SIEMENS OLM 6GK1502-3AB10, for double ring: SIEMENS OLM 6GK1502-4AB10 The OLM converter requires an operating voltage of 24 VDC. If the operating voltage is > 24 VDC the additional power supply 7XV5810-0BA00 is required.
Page 439: Electrical Tests
4.1 General 4.1.5 Electrical Tests Specifications Standards: IEC 60255 (product standards) IEEE Std C37.90.0/.1/.2 UL 508 VDE 0435 For more standards see also individual functions Insulation Test Standards: IEC 60255-5 and IEC 60870-2-1 High voltage test (routine test) 2.5 kV (rms), 50 Hz All circuits except power supply, Binary Inputs, High Speed Outputs, Communication Interface and Time Syn- chronization Interfaces...
Page 440 4 Technical Data Impulse: 1.2/50 µs High energy surge voltages (SURGE), IEC 61000-4-5 installation Class 3 Common mode: 2 kV; 12 Ω; 9 µF – Auxiliary voltage diff. mode: 1 kV; 2 Ω; 18 µF Common mode: 2 kV; 42 Ω; 0,5 µF –...
Page 441: Mechanical Stress Tests
4.1 General 4.1.6 Mechanical Stress Tests Vibration and Shock Stress during Stationary Operation Standards: IEC 60255-21 and IEC 60068 Oscillation Sinusoidal 10 Hz to 60 Hz: ± 0.075 mm amplitude; IEC 60255-21-1, Class 2 IEC 60068-2-6 60 Hz to 150 Hz: 1g acceleration Frequency sweep 1 octave/min 20 cycles in 3 orthogonal axes Shock...
Page 442: Climatic Stress Tests
4 Technical Data 4.1.7 Climatic Stress Tests Temperatures Standards: IEC 60255-6 –25 °C to +85 °C Type tested (acc. IEC 60086-2-1 and -2, Test Bd, for 16 h) –20 °C to +70 °C or –4 °F to +158 °F (legibility of display may Admissible temporary operating temperature (tested be restricted from +55 °C or 131 °F) for 96 h)
Page 443: Certifications
4.1 General 4.1.9 Certifications UL listing UL recognition 7SA522-*A***-**** 7SA522-*J***-**** Models with threaded Models with plug–in 7SA522-*C***-**** 7SA522-*L***-**** terminals terminals 7SA522-*D***-**** 7SA522-*M***-**** 4.1.10 Construction Housing 7XP20 Dimensions See dimensional drawings, Section 4.23 Device (for maximum number of components) Size Weight 6 kg /13.2 lb For panel flush mounting 10 kg / 22.04 lb...
Page 444: Distance Protection
4 Technical Data Distance Protection Earth Impedance Ratio -0.33 to 7.00 Increments 0.01 -0.33 to 7.00 Increments 0.01 Separate for first and higher zones 0.000 to 4.000 Increments 0.001 PHI (K -135.00° to +135.00° Separate for first and higher zones Mutual Impedance Ratio 0.00 to 8.00 Increments 0.01...
Page 445 4.2 Distance Protection Distance Measurement Characteristic Polygonal or MHO circle; 5 independent and 1 controlled zone Setting ranges polygon: > = min. current, phases for I = 1 A 0.05 A to 4.00 A Increments 0.01 A for I = 5 A 0.25 A to 20.00 A = 1 A 0.050 Ω...
Page 446 4 Technical Data Times Shortest trip time Approx. 17 ms (50 Hz) / 15 ms (60 Hz) with fast relay and approx. 11 ms (50 Hz) / 10 ms (60 Hz) with high-speed relay Drop-off time Approx. 30 ms 0.00 s to 30.00 s; ∞ Stage timers Increments 0.01 s for all zones;...
Page 447: Power Swing Detection (Optional)
4.3 Power Swing Detection (optional) Power Swing Detection (optional) Power swing detection Rate of the impedance vector and observation of the path curve Maximum power swing frequency Approx. 7 Hz Power swing blocking programs Block 1st zone only Block higher zones Block 1st and 2nd zone Block all zones Power swing trip...
Page 448: Teleprotection For Distance Protection
4 Technical Data Teleprotection for Distance Protection Mode For two line ends With one channel for each direction or with three channels for each direction for phase segregated transmission For three line ends With one channel for each direction or connection Underreach Transfer Trip Schemes Method Transfer trip with overreaching zone Z1B...
Page 449 4.4 Teleprotection for Distance Protection Overreach Schemes via Protection Data Interface (optional) Phase-segregated for two or three line ends Method Permissive Overreach Transfer Trip (POTT) (with overreaching zone Z1B) Send signal prolongation 0.00 s to 30.00 s Increments 0.00 s Enable delay 0.000 s to 30.000 s Increments 0.001 s...
Page 450: Earth Fault Overcurrent Protection In Earthed Systems (Optional)
4 Technical Data Earth Fault Overcurrent Protection in Earthed Systems (optional) Definite time stages >>>, 3I >>, 3I > Inverse time stage (IDMT) one of the characteristics according to Figure 4-1 to Figure 4-4 can be selected Voltage-dependent stage (U -inverse) Characteristics according to Figure 4-4 Zero-sequence power protection...
Page 451 4.5 Earth Fault Overcurrent Protection in Earthed Systems (optional) Definite Time Overcurrent Stage Pickup value 3I > for I = 1 A 0.05 A to 25.00 A Increments 0.01 A 0.003 A to 25.000 A Increments 0.001 A for I = 5 A 0.25 A to 125.00 A Increments 0.01 A 0.015 A to 125.000 A...
Page 452 4 Technical Data Inverse Time Overcurrent Stage with Logarithmic-inverse Characteristic Pickup value 3I for I = 1 A 0.05 A to 25.00 A Increments 0.01 A 0.003 A to 25.000 A Increments 0.001 A for I = 5 A 0.25 A to 125.00 A Increments 0.01 A 0.015 A to 125.000 A Increments 0.001 A...
Page 453 4.5 Earth Fault Overcurrent Protection in Earthed Systems (optional) Zero Sequence Power Protection Stage Pickup value 3I for I = 1 A 0.05 A to 25.00 A Increments 0.01 A 0.003 A to 25.000 A Increments 0.001 A for I = 5 A 0.25 A to 125.00 A Increments 0.01 A 0.015 A to 125.000 A...
Page 454 4 Technical Data Figure 4-1 Trip time characteristics of inverse time overcurrent stage, acc. IEC (phases and earth) 7SA522 Manual C53000-G1176-C155-3...
Page 455 4.5 Earth Fault Overcurrent Protection in Earthed Systems (optional) Figure 4-2 Trip time characteristics of inverse time overcurrent stage, acc. ANSI/IEEE (phases and earth) 7SA522 Manual C53000-G1176-C155-3...
Page 456 4 Technical Data Figure 4-3 Trip time characteristics of inverse time overcurrent stage, acc. ANSI/IEEE (phases and earth) 7SA522 Manual C53000-G1176-C155-3...
Page 457 4.5 Earth Fault Overcurrent Protection in Earthed Systems (optional) Figure 4-4 Trip time caracteristic of the inverse time overcurrent stage with logarithmic- inverse characteristic ·ln(I/,S 3,&.83) Logarithmic inverse t = T — T 3I0p Max T-delay 3I0p Time Dial Note: For I/,S 3,&.83 > 35 the time applies for I/,S 3,&.83 = 35 Figure 4-5 Trip time characteristics of the zero sequence voltage protection U 0 inv.
Page 458 4 Technical Data Figure 4-6 Tripping characteristics of the zero-sequence power protection This characteristic applies for: S = 10 VA and T3I = 0 s. OPverz 7SA522 Manual C53000-G1176-C155-3...
Page 459: Teleprotection For Earth Fault Overcurrent Protection (Optional)
4.6 Teleprotection for Earth Fault Overcurrent Protection (optional) Teleprotection for Earth Fault Overcurrent Protection (optional) Mode For two line ends One channel for each direction or three channels each direc- tion for phase-segregated transmission For three line ends With one channel for each direction or connection Comparison Schemes Method Dir.
Page 460: Weak-Infeed Tripping (Classic)
4 Technical Data Weak-Infeed Tripping (classic) Operating Mode Phase segregated undervoltage detection after reception of a carrier signal from the remote end Undervoltage Set value U < 2 V to 70 V Increments 1 V Drop-off to pick-up ratio Approx. 1.1 ≤...
Page 461: Weak-Infeed Tripping (French Specification)
4.8 Weak-Infeed Tripping (French specification) Weak-Infeed Tripping (French specification) Operating Mode Phase segregated undervoltage detection after reception of a carrier signal from the remote end Undervoltage Set value U < (factor) 0.10 to 1.00 Increments 0.01 Dropout/pickup ratio Approx. 1.1 ≤...
Page 462: Protection Data Interfaces And Communication Topology (Optional)
4 Technical Data Protection Data Interfaces and Communication Topology (optional) Protection Data Interfaces Quantity 1 or 2 - Connection optical fibre Mounting location “D” for one connection or “D” and “E” for two connections For flush-mounted case On the rear side For surface-mounted case At the inclined housing on the case bottom Connection modules for protection data interface, depending on the ordering version:...
Page 463: External Direct And Remote Tripping
4.10 External Direct and Remote Tripping 4.10 External Direct and Remote Tripping External Trip of the Local Breaker Operating time, total Approx. 11 ms Trip time delay 0.00 s to 30.00 s Increments 0.01 s or ∞ (ineffective) Time expiry tolerances 1 % of setting value or 10 ms The set times are pure delay times 7SA522 Manual...
Page 464: Time Overcurrent Protection
4 Technical Data 4.11 Time Overcurrent Protection Operating Modes As Emergency Overcurrent Protection or Back-up Overcurrent Protection: Emergency overcurrent protection Operates on failure of the measured voltage, • On trip of a voltage transformer mcb (via binary input) • For pickup of the “Fuse Failure Monitor” Back-up overcurrent protection Operates independent of any events Characteristics...
Page 465 4.11 Time Overcurrent Protection Definite Time Overcurrent Stage Pickup value I > (phases) For I = 1 A 0.10 A to 25.00 A Increments 0.01 A Or ∞ (ineffective) For I = 5 A 0.50 A to 125.00 A Or ∞ (ineffective) Pickup value 3I >...
Page 466 4 Technical Data Inverse Time Overcurrent Stage (ANSI) Pickup value I (phases) for I = 1 A 0.10 A to 4.00 A Increments 0.01 A or ∞ (ineffective) for I = 5 A 0.50 A to 20.00 A or ∞ (ineffective) Pickup value 3I (earth) for I...
Page 467: Instantaneous High-Current Switch-Onto-Fault Protection
4.12 Instantaneous High-Current Switch-onto-Fault Protection 4.12 Instantaneous High-Current Switch-onto-Fault Protection Pickup High current pick-up I>>> for I = 1 A 1.00 A to 25.00 A Increments 0.01 A for I = 5 A 5.00 A to 125.00 A Drop-off to pick-up ratio Approx.
Page 468: Automatic Reclosure Function (Optional)
4 Technical Data 4.13 Automatic Reclosure Function (optional) Automatic Reclosures Number of reclosures Max. 8, first 4 with individual settings Type (depending on ordered version) 1-pole, 3-pole or 1-/3-pole Control With pickup or trip command 0.01 s to 300.00 s; ∞ Action times Increments 0.01 s Initiation possible without pick-up and action time...
Page 469: Synchronism And Voltage Check (Optional)
4.14 Synchronism and Voltage Check (optional) 4.14 Synchronism and Voltage Check (optional) Operating Modes Operating modes Synchronism check with automatic reclosure Live bus - dead line Dead bus - live line Dead bus and dead line Bypassing Or combination of the above Synchronism Closing the circuit breaker under asynchronous power condi- tions possible (with circuit breaker action time)
Page 470 4 Technical Data Asynchronous Power Conditions ∆f-measurement 0.03 Hz to 2.00 Hz Increments 0.01 Hz Tolerance 15 mHz 5° for ∆f ≤ 1 Hz Max. angle error 10° for ∆f > 1 Hz Synchronous/asynchronous limits 0.01 Hz Circuit breaker operating time 0.01 s to 0.60 s Increments 0.01 s Times...
Page 471: Undervoltage And Overvoltage Protection (Optional)
4.15 Undervoltage and Overvoltage Protection (optional) 4.15 Undervoltage and Overvoltage Protection (optional) Overvoltage Phase-Earth 1.0 V to 170.0 V; ∞ Overvoltage U >> Increments 0.1V 0.00 s to 100.00 s; ∞ Delay T Increments 0.01 s UPh>> 1.0 V to 170.0 V; ∞ Overvoltage U >...
Page 472 4 Technical Data Overvoltage Negative Sequence System U 2.0 V to 220.0 V; ∞ Overvoltage U >> Increments 0.1V 0.00 s to 100.00 s; ∞ Delay T Increments 0.01 s U2>> 2.0 V to 220.0 V; ∞ Overvoltage U > Increments 0.1V 0.00 s to 100.00 s;...
Page 473 4.15 Undervoltage and Overvoltage Protection (optional) Undervoltage Phase–Phase Undervoltage U << 1.0 V to 175.0 V Increments 0.1V PhPh 0.00 s to 100.00 s; ∞ Delay T Increments 0.01 s UPhPh<< Undervoltage U < 1.0 V to 175.0 V Increments 0.1V PhPh 0.00 s to 100.00 s;...
Page 474: Frequency Protection (Optional)
4 Technical Data 4.16 Frequency Protection (optional) Frequency Elements Quantity 4, depending on setting effective on f< or f> Pickup Values f> or f< adjustable for each element For f = 50 Hz 45.50 Hz to 54.50 Hz Increments 0.01 Hz For f = 60 Hz 55.50 Hz to 64.50 Hz...
Page 475: Fault Locator
4.17 Fault Locator 4.17 Fault Locator General Start With trip command or drop-off = 1 A 0.0050 Ω/km up to 9.5000 Ω/km Increments 0.001 Ω/km Setting range reactance (secondary), for I miles or km = 5 A 0.0010 Ω/km up to 1.9000 Ω/km for I = 1 A 0.0050 Ω/mile up to 15.0000 Ω/mile Increments 0.001 Ω/mile for I...
Page 476: Circuit Breaker Failure Protection (Optional)
4 Technical Data 4.18 Circuit Breaker Failure Protection (optional) Circuit Breaker Monitoring Current flow monitoring for I = 1 A 0.05 A to 20.00 A Increments 0.01 A for I = 5 A 0.25 A to 100.00 A Drop-off to pick-up ratio Approx.
Page 477: Monitoring Function
4.19 Monitoring Function 4.19 Monitoring Function Measured Values Current sum = | I · I | > SUM.I Threshold · I + SUM.I factor ·Σ | I | - SUM I THRESHOLD for I = 1 A 0.05 A to 2.00 A Increments 0.01 A for I = 5 A 0.25 A to 10.00 A...
Page 478 4 Technical Data Trip Circuit Monitoring Number of monitored circuits 1 to 3 Operation per circuit With 1 binary input or with 2 binary inputs Pickup and Dropout Time Approx. 1 to 2 s Settable delay time for operation with 1 binary input 1 s to 30 s Increments 1 s 7SA522 Manual...
Page 479: Transmission Of Binary Information (Optional)
4.20 Transmission of Binary Information (optional) 4.20 Transmission of Binary Information (optional) General Note: The setting for remote signal reset delay for communication failure may be 0 s to 300 s or ∞. With setting ∞ an- nunciations are maintained indefinitely. Remote Commands Number of possible remote commands Operating times, total approx.
Page 480 4 Technical Data Remote Signals Number of possible remote signals Operating times, total approx. Transmission speed 512 kbit/s 128 kbit/s 64 kbit/s 2 ends, minimum, 12 ms 14 ms 16 ms typical 14 ms 16 ms 18 ms 3 ends, minimum, 13 ms 16 ms 21 ms...
Page 481: User Defined Functions (Cfc)
4.21 User Defined Functions (CFC) 4.21 User Defined Functions (CFC) Function Modules and Possible Assignments to Task Levels Function Module Explanation Task Level MW_BEARB PLC1_BEARB PLC_BEARB SFS_BEARB ABSVALUE Magnitude calculation Addition AND - Gate BOOL_TO_CO Boolean to Control (conversion) BOOL_TO_DL Boolean to Double Point (conversion) BOOL_TO_IC...
Page 482 4 Technical Data General Limits Description Limit Comments Maximum number of all CFC charts considering all task When the limit is exceeded, an error levels message is output by the device. Conse- quently, the device starts monitoring. The red ERROR-LED lights up. Maximum number of all CFC charts considering one task Only Error Message level...
Page 483 4.21 User Defined Functions (CFC) Maximum Number of TICKS in the Task Levels Task Level Limit in TICKS MW_BEARB (Measured Value Processing) 10 000 PLC1_BEARB (Slow PLC Processing) 1 900 PLC_BEARB (Fast PLC Processing) SFS_BEARB (Switchgear Interlocking) 10 000 When the sum of TICKS of all blocks exceeds the limits before-mentioned, an error message is output by CFC.
Page 484: Auxiliary Functions
4 Technical Data 4.22 Auxiliary Functions Measured Values Operational measured values for currents ; 3I in A primary and secondary and in % I Tolerance 1 % of measured value, or 0.5 % of I Operational measured values for voltages L1-E L2-E L3-E...
Page 485 4.22 Auxiliary Functions Remote measured values for currents of remote end ϕ(I ); ϕ(I ); ϕ(I ) (remote versus local) in ° Remote measured values for voltages of remote end ϕ(U ); ϕ(U ); ϕ(U ) (remote versus local) in ° At nominal frequency Operational Event Log Buffer Capacity...
Page 486: Dimensions
4 Technical Data 4.23 Dimensions 4.23.1 Panel Flush and Cubicle Mounting (Housing Size Figure 4-7 Dimensions of a device for panel flush or cubicle mounting (size 7SA522 Manual C53000-G1176-C155-3...
Page 487 4.23 Dimensions 4.23.2 Panel Flush and Cubicle Mounting (Housing Size Figure 4-8 Dimensions of a device for panel flush or cubicle mounting (size 7SA522 Manual C53000-G1176-C155-3...
Page 488 4 Technical Data 4.23.3 Panel Surface Mounting (Housing Size Figure 4-9 Dimensions of a device for panel surface mounting (size 4.23.4 Panel Surface Mounting (Housing Size Figure 4-10 Dimensions of a device for panel surface mounting (size 7SA522 Manual C53000-G1176-C155-3...
Page 489 Appendix This appendix is primarily a reference for the experienced user. This section provides ordering information for the models of this device. General diagrams indicating the ter- minal connections of the models of this device are included. Following the general di- agrams are diagrams that show the proper connections of the devices to primary equipment in many typical power system configurations.
Page 490: A Appendix
A Appendix Ordering Information and Accessories A.1.1 Ordering information A.1.1.1 Ordering Code (MLFB) 10 11 12 13 14 15 16 17 18 19 Numerical Distance – – Protection (position 1 to 9 Measuring Inputs (4 x U, 4 x I) Pos.
Page 491 A.1 Ordering Information and Accessories 10 11 12 13 14 15 16 17 18 19 Numerical Distance – – Protection (position 1 to 9 Region-specific Default/Language Settings and Function Versions Pos. 10 Region DE, German language (can be changed) Region World, English language (GB) (language can be changed) Region US, English language (US) (can be changed) Region FR, French language (on request) Region World, Spanish language (on request)
Page 492 A Appendix 10 11 12 13 14 15 16 17 18 19 Numerical Distance – – Protection (position 17 to 19 ) Additional information L, further protocols port B Position 18, 19 System port, Profibus DP slave, electrical RS485 0, A System port, Profibus DP slave, optical 820°nm, double ring, ST-connector 0, B System port, DNP3.0, electrical RS485...
Page 493 A.1 Ordering Information and Accessories 10 11 12 13 14 15 16 17 18 19 Numerical Distance – – Protection (position 10 to 16 ) Functions 1 Pos. 13 Only 3-pole tripping Only 1-/3-pole tripping With Functions 1 and Port E see additional information N Functions 2 Pos.
Page 494 A Appendix Functions 4 Pos. 16 Earth Fault Protection / Directional Measured Values, Extended, for Earthed Systems Min / Max Values without without without with with without with with only available with “2” or “6” on position 7 only available with “1” or “5” on position 7 not available with surface mounting housing 10 11 12 13 14 15 16...
Page 495: A.1.2 Accessories
A.1 Ordering Information and Accessories A.1.2 Accessories Voltage Nominal Values Order No. Transformer Thermal 1.6 A; magnetic 6 A 3RV1611-1AG14 Miniature Circuit Breaker Communication Converter for the serial connection of the Converter distance protection system 7SA522 to the synchronous communication interfaces X.21 or G703, or for pilot wire pairs.
Page 496 A Appendix Terminal Block Terminal Block Covering Cap for Block Covering Caps Type Order No. 18 terminal voltage, 12 terminal current block C73334-A1-C31-1 12 terminal voltage, 8 terminal current block C73334-A1-C32-1 Short-Circuit Links Short Circuit Links for Purpose / Terminal Type Order No.
Page 497 A.1 Ordering Information and Accessories Graphical Analysis Software for graphical visualization, anal- Program SIGRA ysis, and evaluation of fault data. Option package of the complete version of DIGSI® Order No. Graphical Analysis Program SIGRA®, Full version with license for 10 computers 7XS5410-0AA0 Display Editor Software for creating basic and power...
Page 498: A.2 Terminal Assignments
A Appendix Terminal Assignments A.2.1 Housing for panel surface and cubicle mounting 7SA522*-*A/J Figure A-1 General diagram 7SA522*-*A/J (panel flush mounting or cubicle mounting; size 7SA522 Manual C53000-G1176-C155-3...
Page 499 A.2 Terminal Assignments 7SA522*-*C/L Figure A-2 General diagram 7SA522*-*C/L (panel flush mounting or cubicle mounting; size 7SA522 Manual C53000-G1176-C155-3...
Page 500 A Appendix 7SA522*-*N/S Figure A-3 General diagram 7SA522*-*N/S (panel flush mounting or cubicle mounting; size 7SA522 Manual C53000-G1176-C155-3...
Page 501 A.2 Terminal Assignments 7SA522*-*D/M Figure A-4 General diagram 7SA522*-*D/M (panel flush mounting or cubicle mounting; size 7SA522 Manual C53000-G1176-C155-3...
Page 502 A Appendix 7SA522*-*P/T Figure A-5 General diagram 7SA522*-*P/T (panel flush mounting or cubicle mounting; size 7SA522 Manual C53000-G1176-C155-3...
Page 503: A.2.2 Housing For Panel Surface Mounting
A.2 Terminal Assignments A.2.2 Housing for Panel Surface Mounting 7SA522*-*E Figure A-6 General diagram 7SA522*-*E (panel surface mounting; size 7SA522 Manual C53000-G1176-C155-3...
Page 504 A Appendix 7SA522*-*E (up to development state Figure A-7 General diagram 7SA522*-*E up to development state /DD (panel surface mounting; size 7SA522 Manual C53000-G1176-C155-3...
Page 505 A.2 Terminal Assignments 7SA522*-*E (begin- ning with develop- ment state EE) Figure A-8 General diagram 7SA522*-*E beginning with development state /EE (panel surface mounting; size 7SA522 Manual C53000-G1176-C155-3...
Page 506 A Appendix 7SA522*-*G Figure A-9 General diagram 7SA522*-*G (panel surface mounting; size 7SA522 Manual C53000-G1176-C155-3...
Page 507 A.2 Terminal Assignments 7SA522*-*Q Figure A-10 General diagram 7SA522*-*Q (panel surface mounting; size 7SA522 Manual C53000-G1176-C155-3...
Page 508 A Appendix 7SA522*-*H Figure A-11 General diagram 7SA522*-*H (panel surface mounting; size 7SA522 Manual C53000-G1176-C155-3...
Page 509 A.2 Terminal Assignments 7SA522*-*R Figure A-12 General diagram 7SA522*-*R (panel surface mounting; size 7SA522 Manual C53000-G1176-C155-3...
Page 510 A Appendix 7SA522*-*G/H/Q/R (up to development state /DD) Figure A-13 General diagram 7SA522*-*G/H/Q/R up to development state /DD (panel surface mounting; size 7SA522 Manual C53000-G1176-C155-3...
Page 511 A.2 Terminal Assignments 7SA522*-*G/H/Q/R (beginning with de- velopment state /EE) Figure A-14 General diagram 7SA522*-*G/H/Q/R beginning at development state /EE (panel surface mounting; size 7SA522 Manual C53000-G1176-C155-3...
Page 512: A.3 Connection Examples
A Appendix Connection Examples A.3.1 Current Transformer Examples Figure A-15 Current connections to three current transformers and starpoint current (normal circuit layout) 7SA522 Manual C53000-G1176-C155-3...
Page 513 A.3 Connection Examples Figure A-16 Current connections to three current transformers and a separate earth current transformer (summation transformer) 7SA522 Manual C53000-G1176-C155-3...
Page 514 A Appendix Figure A-17 Current connections to three current transformers and earth current from the star-point connection of a par- allel line (for parallel line compensation) 7SA522 Manual C53000-G1176-C155-3...
Page 515 A.3 Connection Examples Figure A-18 Current connections to three current transformers and earth current from the star-point current of an earthed power transformer (for directional earth fault protection) 7SA522 Manual C53000-G1176-C155-3...
Page 516: A.3.2 Voltage Transformer Examples
A Appendix A.3.2 Voltage Transformer Examples Figure A-19 Voltage connections to three wye-connected voltage transformers (normal circuit layout) 7SA522 Manual C53000-G1176-C155-3...
Page 517 A.3 Connection Examples Figure A-20 Voltage connections to three wye-connected voltage transformers with addition- al open-delta windings (e–n–winding) 7SA522 Manual C53000-G1176-C155-3...
Page 518 A Appendix Figure A-21 Voltage connections to three wye-connected voltage transformers and addition- ally to a busbar voltage (for overvoltage protection or synchronism check) 7SA522 Manual C53000-G1176-C155-3...
Page 519: A.4 Default Settings
A.4 Default Settings Default Settings When the device leaves the factory, a large number of LED indications, binary inputs and outputs as well as function keys are already preset. They are summarised in the following table. A.4.1 LEDs Table A-1 LED Indication Presettings LEDs Short Text...
Page 520: A.4.2 Binary Inputs
A Appendix A.4.2 Binary Inputs Table A-2 Binary input presettings for all devices and ordering variants Binary Inputs Short Text Function No. Description >Reset LED >Reset LED >Manual Close >Manual close signal >FAIL:Feeder VT >Failure: Feeder VT (MCB tripped) >DisTel Rec.Ch1 4006 >Dis.Tele.
Page 521: A.4.4 Function Keys
A.4 Default Settings Binary Output Short Text Function No. Description BO10 DisTRIP3p. Z1sf 3823 DisTRIP 3phase in Z1 with single-ph Flt. DisTRIP3p.Z1Bsf 3825 DisTRIP 3phase in Z1B with single- ph Flt BO11 DisTRIP3p. Z1mf 3824 DisTRIP 3phase in Z1 with multi-ph Flt.
Page 522: A.4.5 Default Display
A Appendix A.4.5 Default Display 4-line Display Table A-5 This selection is available as start page which may be configured. Page 1 Page 2 Page 3 Page 4 Page 5 Spontaneous Fault The spontaneous annunciations on devices with 4-line display serve to display the Indication of the most important data about a fault.
Page 523: A.4.6 Pre-Defined Cfc Charts
A.4 Default Settings A.4.6 Pre-defined CFC Charts ® Some CFC charts are already supplied with the SIPROTEC device. Depending on the variant the following charts may be implemented: Device and System Some of the event-controlled logical allocations are created with blocks of the slow Logic logic (PLC1_BEARB = slow PLC processing).
Page 524 A Appendix • the input indication “CB wait” is OFF and • the input indication “Door open” is OFF. The disconnector can only be closed, if: • the circuit breaker is set to OPEN and • the earth switch is set to OPEN and •...
Page 525 A.4 Default Settings Figure A-24 Standard interlocking for circuit breaker, disconnector and earth switch 7SA522 Manual C53000-G1176-C155-3...
Page 526 A Appendix Limit Value On two worksheets a set point supervision of the sum of power factor |cosϕ| < and in Handling (Set the maximum functional scope additional set point supervisions of currents (demand Points) meter of phase currents and positive-sequence component) and supervisions of power (apparent power, active power and reactive power) are created with blocks of level “Processing of Measured Values”.
Page 527: A.5 Protocol-Dependent Functions
A.5 Protocol-dependent Functions Protocol-dependent Functions Protocol → IEC 60870-5-103 PROFIBUS FMS PROFIBUS DP DNP3.0 Additional In- terface (op- Function ↓ tional) Operational Mea- sured Values Metered Values Fault Recording No. Only via addi- No. Only via ad- tional service inter- ditional service face interface...
Page 528: A.6 Functional Scope
A Appendix Functional Scope Addr. Parameter Setting Options Default Setting Comments Grp Chge OPTION Disabled Disabled Setting Group Change Option Enabled Trip mode 3pole only 3pole only Trip mode 1-/3pole Phase Distance Quadrilateral Quadrilateral Phase Distance Disabled Earth Distance Quadrilateral Quadrilateral Earth Distance Disabled...
Page 529 A.6 Functional Scope Addr. Parameter Setting Options Default Setting Comments AR control mode Pickup w/ Tact Trip w/ Tact Auto-Reclose control mode Pickup w/o Tact Trip w/ Tact Trip w/o Tact Synchro-Check Disabled Disabled Synchronism and Voltage Check Enabled FREQUENCY Prot. Disabled Disabled Over / Underfrequency Protection...
Page 530: A.7 Settings
A Appendix Settings Addresses which have an appended "A" can only be changed with DIGSI, under Ad- ditional Settings. The table indicates region-specific presettings. Column C (configuration) indicates the corresponding secondary nominal current of the current transformer. Addr. Parameter Function Setting Options Default Setting Comments...
Page 531 A.7 Settings Addr. Parameter Function Setting Options Default Setting Comments PRE. TRIG. TIME Osc. Fault Rec. 0.05 .. 0.50 sec 0.25 sec Captured Waveform Prior to Trigger POST REC. TIME Osc. Fault Rec. 0.05 .. 0.50 sec 0.10 sec Captured Waveform after Event 0.10 ..
Page 532 A Appendix Addr. Parameter Function Setting Options Default Setting Comments 0.2 .. 50.0 A; ∞ 1140A I-CTsat. Thres. P.System Data 2 20.0 A CT Saturation Threshold 1.0 .. 250.0 A; ∞ 100.0 A 1150A SI Time Man.Cl P.System Data 2 0.01 ..
Page 533 A.7 Settings Addr. Parameter Function Setting Options Default Setting Comments ϕ load (Ø-Ø) 20 .. 60 ° 45 ° 1244 Dis. General PHI load, maximum Load Angle (ph-ph) 1301 Op. mode Z1 Dis. Quadril. Forward Forward Operating mode Z1 Reverse Non-Directional Inactive 0.050 ..
Page 534 A Appendix Addr. Parameter Function Setting Options Default Setting Comments 0.00 .. 30.00 sec; ∞ 1335 T4 DELAY Dis. General 0.90 sec T4 delay Dis. Quadril. Dis. MHO 1341 Op. mode Z5 Dis. Quadril. Forward Inactive Operating mode Z5 Reverse Non-Directional Inactive 0.050 ..
Page 535 A.7 Settings Addr. Parameter Function Setting Options Default Setting Comments 1451 Op. mode Z1B Dis. MHO Forward Forward Operating mode Z1B (extended Reverse zone) Inactive 0.050 .. 200.000 Ω 3.000 Ω 1452 ZR(Z1B) Dis. MHO ZR(Z1B), Impedance Reach 0.010 .. 40.000 Ω 0.600 Ω...
Page 536 A Appendix Addr. Parameter Function Setting Options Default Setting Comments 2520 T 3I0> alarm Weak Infeed 0.00 .. 30.00 sec 10.00 sec 3I0> exceeded delay for alarm 2530 WI non delayed Weak Infeed WI non delayed 2531 WI delayed Weak Infeed WI delayed by receive fail 2601...
Page 537 A.7 Settings Addr. Parameter Function Setting Options Default Setting Comments 2670 I(3I0)p Tele/BI Back-Up O/C Instantaneous trip via Teleprot./BI 2671 I(3I0)p SOTF Back-Up O/C Instantaneous trip after Switch- OnToFault 2680 SOTF Time DELAY Back-Up O/C 0.00 .. 30.00 sec 0.00 sec Trip time delay after SOTF 2801 DMD Interval...
Page 538 A Appendix Addr. Parameter Function Setting Options Default Setting Comments 3109 Trip 1pole E/F Earth Fault O/C Single pole trip with earth flt.prot. 3110 Op. mode 3I0>>> Earth Fault O/C Forward Inactive Operating mode Reverse Non-Directional Inactive 3111 3I0>>> Earth Fault O/C 0.05 ..
Page 539 A.7 Settings Addr. Parameter Function Setting Options Default Setting Comments 3148 3I0p Telep/BI Earth Fault O/C Instantaneous trip via Teleprot./BI Earth Fault O/C Earth Fault O/C Earth Fault O/C 3149 3I0p SOTF-Trip Earth Fault O/C Instantaneous trip after Switch- Earth Fault O/C OnToFault Earth Fault O/C Earth Fault O/C...
Page 540 A Appendix Addr. Parameter Function Setting Options Default Setting Comments 3203A Send Prolong. Teleprot. E/F 0.00 .. 30.00 sec 0.05 sec Time for send signal prolongation 3207A Delay for alarm Teleprot. E/F 0.00 .. 30.00 sec 10.00 sec Unblocking: Time Delay for Alarm 3208 Release Delay Teleprot.
Page 541 A.7 Settings Addr. Parameter Function Setting Options Default Setting Comments 3458 1.AR: Tdead EV. Autoreclosure 0.01 .. 1800.00 sec 1.20 sec Dead time after evolving fault 3459 1.AR: CB? CLOSE Autoreclosure CB ready interrogation before re- closing 3460 1.AR SynRequest Autoreclosure Request for synchro-check after 3pole AR...
Page 542 A Appendix Addr. Parameter Function Setting Options Default Setting Comments 3510 Op.mode with AR Sync. Check with T-CB close w/o T-CB close Operating mode with AR w/o T-CB close 3511 Max. Volt. Diff Sync. Check 1.0 .. 40.0 V 2.0 V Maximum voltage difference 3512 Max.
Page 543 A.7 Settings Addr. Parameter Function Setting Options Default Setting Comments 3711 Uph-ph>(>) Voltage Prot. Operating mode Uph-ph overvolt- Alarm Only age prot. 2.0 .. 220.0 V; ∞ 3712 Uph-ph> Voltage Prot. 150.0 V Uph-ph> Pickup 0.00 .. 100.00 sec; ∞ 3713 T Uph-ph>...
Page 544 A Appendix Addr. Parameter Function Setting Options Default Setting Comments 3774 U1<< Voltage Prot. 1.0 .. 100.0 V; 0 10.0 V U1<< Pickup 0.00 .. 100.00 sec; ∞ 3775 T U1<< Voltage Prot. 1.00 sec T U1<< Time Delay 3778 CURR.SUP.U1<...
Page 545 A.7 Settings Addr. Parameter Function Setting Options Default Setting Comments 4703 ID OF RELAY 3 Prot. Interface 1 .. 65534 Identification number of relay 3 4710 LOCAL RELAY Prot. Interface relay 1 relay 1 Local relay is relay 2 relay 3 7SA522 Manual C53000-G1176-C155-3...
Page 546: A.8 Information List
A Appendix Information List Indications for IEC 60 870-5-103 are always reported ON / OFF if they are subject to general interrogation for IEC 60 870-5-103. If not, they are reported only as ON. New user-defined indications or such newly allocated to IEC 60 870-5-103 are set to ON / OFF and subjected to general interrogation if the information type is not a spon- taneous event (“.._Ev”).
Page 547 A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio Group B (Group B) Change Group IntSP Group C (Group C) Change Group IntSP Group D (Group D) Change Group IntSP Fault Recording Start (FltRecSta) Osc. Fault Rec. IntSP Reset Minimum and Maximum Min/Max meter...
Page 548 A Appendix Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio Q2 Open/Close (Q2 Op/Cl) Control Device CF_D Q2 Open/Close (Q2 Op/Cl) Control Device Q9 Open/Close (Q9 Op/Cl) Control Device CF_D Q9 Open/Close (Q9 Op/Cl) Control Device Fan ON/OFF (Fan ON/OFF) Control Device...
Page 549 A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio >Setting Group Select Bit 0 (>Set Change Group LED BI Group Bit0) >Setting Group Select Bit 1 (>Set Change Group LED BI Group Bit1) >User defined annunciation 1 Device LED BI...
Page 550 A Appendix Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio Teleprot. ON/OFF (via system Device IntSP port) (TelepONoff) Error with a summary alarm Device (Error Sum Alarm) Error 5V (Error 5V) Device Alarm Summary Event (Alarm Device Sum Event) Failure: General Current Super-...
Page 551 A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio Error Board 7 (Error Board 7) Device Error Board 0 (Error Board 0) Device Error: Offset (Error Offset) Device Error:1A/5Ajumper different from Device setting (Error1A/5Awrong) Alarm: NO calibration data avail- Device...
Page 552 A Appendix Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio >Circuit breaker aux. contact: P.System Data 2 LED BI Pole L3 (>CB Aux. L3) >Manual close signal (>Manual P.System Data 2 LED BI Close) >Block all Close commands from P.System Data 2 LED BI...
Page 553 A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio >S MIN/MAX Buffer Reset (>S Min/Max meter LED BI MiMa Reset) >Q MIN/MAX Buffer Reset (>Q Min/Max meter LED BI MiMa Reset) >Idmd MIN/MAX Buffer Reset Min/Max meter LED BI (>Idmd MiMaReset)
Page 554 A Appendix Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio Relay TRIP command Phases P.System Data 2 L123 (Relay TRIP 3ph.) LOCKOUT is active (LOCKOUT) P.System Data 2 IntSP Primary fault current IL1 (IL1 =) P.System Data 2 Primary fault current IL2 (IL2 =) P.System Data 2...
Page 555 A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 1028 Accumulation of interrupted Statistics current L2 (Σ IL2 1029 Accumulation of interrupted Statistics current L3 (Σ IL3 1030 Max. fault current Phase L1 (Max Statistics IL1 =) 1031...
Page 556 A Appendix Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 1309 >Earth Fault O/C Block 3I0p Earth Fault O/C LED BI (>EF BLOCK 3I0p) 1310 >Earth Fault O/C Instantaneous Earth Fault O/C LED BI trip (>EF InstTRIP) 1311 >E/F Teleprotection ON (>EF...
Page 557 A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 1336 E/F phase selector L1 selected Earth Fault O/C (E/F L1 selec.) 1337 E/F phase selector L2 selected Earth Fault O/C (E/F L2 selec.) 1338 E/F phase selector L3 selected Earth Fault O/C...
Page 558 A Appendix Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 1375 E/F Telep. Block: carrier STOP Teleprot. E/F signal L2 (EF Tele STOP L2) 1376 E/F Telep. Block: carrier STOP Teleprot. E/F signal L3 (EF Tele STOP L3) 1380 E/F Teleprot.
Page 559 A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 1432 >BF: External release (>BF re- Breaker Failure LED BI lease) 1435 >BF: External start L1 (>BF Start Breaker Failure LED BI 1436 >BF: External start L2 (>BF Start Breaker Failure LED BI...
Page 560 A Appendix Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 2701 >AR: Switch on auto-reclose Autoreclosure LED BI function (>AR on) 2702 >AR: Switch off auto-reclose Autoreclosure LED BI function (>AR off) 2703 >AR: Block auto-reclose func- Autoreclosure LED BI tion (>AR block)
Page 561 A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 2749 >AR: External pickup L3 for AR Autoreclosure LED BI start (>Pickup L3 AR) 2750 >AR: External pickup 1phase for Autoreclosure LED BI AR start (>Pickup 1ph AR) 2751 >AR: External pickup 2phase for...
Page 562 A Appendix Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 2845 AR 2nd cycle running (AR Autoreclosure 2ndCyc. run.) 2846 AR 3rd cycle running (AR Autoreclosure 3rdCyc. run.) 2847 AR 4th or higher cycle running Autoreclosure (AR 4thCyc.
Page 563 A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 2901 >Switch on synchro-check func- Sync. Check LED BI tion (>Sync. on) 2902 >Switch off synchro-check func- Sync. Check LED BI tion (>Sync. off) 2903 >BLOCK synchro-check function Sync.
Page 564 A Appendix Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 2948 Sync. Freq. diff. greater than limit Sync. Check (Sync. fdiff>) 2949 Sync. Angle diff. greater than Sync. Check limit (Sync. ϕ-diff>) 2951 Synchronism release (to ext. AR) Sync.
Page 565 A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 3234 Device tables are unequal (DT Prot. Interface unequal) 3235 Differences between common Prot. Interface parameters (Par. different) 3236 Different PI for transmit and Prot.
Page 566 A Appendix Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 3546 Remote Trip 2 received Remote Signals (RemoteTrip2 rec) 3547 Remote Trip 3 received Remote Signals (RemoteTrip3 rec) 3548 Remote Trip 4 received Remote Signals (RemoteTrip4 rec) 3549 >Remote Signal 1 input (>Rem.
Page 567 A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 3569 >Remote Signal 21 input Remote Signals LED BI (>Rem.Signal21) 3570 >Remote Signal 22 input Remote Signals LED BI (>Rem.Signal22) 3571 >Remote Signal 23 input Remote Signals LED BI (>Rem.Signal23)
Page 568 A Appendix Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 3592 Remote signal 20 received Remote Signals (Rem.Sig20recv) 3593 Remote signal 21 received Remote Signals (Rem.Sig21recv) 3594 Remote signal 22 received Remote Signals (Rem.Sig22recv) 3595 Remote signal 23 received Remote Signals...
Page 569 A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 3682 Distance Pickup L1E (Dis.Pick- Dis. General up L1E) 3683 Distance Pickup Phase L2 (only) Dis. General (Dis.Pickup 1pL2) 3684 Distance Pickup L2E (Dis.Pick- Dis.
Page 570 A Appendix Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 3711 Distance Loop L23 selected Dis. General reverse (Dis.Loop L2-3 r) 3712 Distance Loop L31 selected Dis. General reverse (Dis.Loop L3-1 r) 3713 Distance Loop L1E selected non- Dis.
Page 571 A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 3758 Distance Pickup Z3 (Dis. Pickup Dis. General 3759 Distance Pickup Z4 (Dis. Pickup Dis. General 3760 Distance Pickup Z5 (Dis. Pickup Dis. General 3771 DistanceTime Out T1 (Dis.Time Dis.
Page 572 A Appendix Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 3823 DisTRIP 3phase in Z1 with Dis. General single-ph Flt. (DisTRIP3p. Z1sf) 3824 DisTRIP 3phase in Z1 with multi- Dis. General ph Flt. (DisTRIP3p. Z1mf) 3825 DisTRIP 3phase in Z1B with Dis.
Page 573 A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 4040 >Dis.Tele. BLOCK Echo Signal Teleprot. Dist. LED BI (>Dis.T.BlkEcho) 4050 Dis. Teleprotection ON/OFF via Teleprot. Dist. IntSP BI (Dis.T.on/off BI) 4051 Teleprotection is switched ON Device IntSP (Telep.
Page 574 A Appendix Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 4090 Dis.Tele.Carrier RECEPTION, Teleprot. Dist. L3, Device2 (Dis.T.RecL3Dev2) 4091 Dis.Tele.Carrier RECEPTION, Teleprot. Dist. L1, Device3 (Dis.T.RecL1Dev3) 4092 Dis.Tele.Carrier RECEPTION, Teleprot. Dist. L2, Device3 (Dis.T.RecL2Dev3) 4093 Dis.Tele.Carrier RECEPTION, Teleprot.
Page 575 A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 4231 Weak Infeed PICKED UP (Weak- Weak Infeed Inf. PICKUP) 4232 Weak Infeed PICKUP L1 (W/I Weak Infeed Pickup L1) 4233 Weak Infeed PICKUP L2 (W/I Weak Infeed Pickup L2) 4234...
Page 576 A Appendix Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 4412 >Direct Transfer Trip INPUT DTT Direct Trip LED BI Phase L1 (>DTT Trip L1) 4413 >Direct Transfer Trip INPUT DTT Direct Trip LED BI Phase L2 (>DTT Trip L2) 4414 >Direct Transfer Trip INPUT...
Page 577 A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 5237 Frequency protection: f2 TRIP (f2 Frequency Prot. TRIP) 5238 Frequency protection: f3 TRIP (f3 Frequency Prot. TRIP) 5239 Frequency protection: f4 TRIP (f4 Frequency Prot.
Page 578 A Appendix Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 7131 >Enable I-STUB-Bus function Back-Up O/C LED BI (>I-STUB ENABLE) 7151 Backup O/C is switched OFF Back-Up O/C (O/C OFF) 7152 Backup O/C is BLOCKED (O/C Back-Up O/C BLOCK) 7153...
Page 579 A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 7185 Backup O/C Pickup L123E (O/C Back-Up O/C PickupL123E) 7191 Backup O/C Pickup I>> (O/C Back-Up O/C PICKUP I>>) 7192 Backup O/C Pickup I> (O/C Back-Up O/C PICKUP I>) 7193...
Page 580 A Appendix Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 7349 CB-TEST canceled due to CB Testing OUT_ stayed CLOSED (CB-TSTstop CLOS) 7350 CB-TEST was succesful (CB- Testing OUT_ TST .OK.) 10201 >BLOCK Uph-e>(>) Overvolt. Voltage Prot.
Page 581 A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 10227 Uph-ph<(<) Undervolt. is Voltage Prot. switched OFF (Uph-ph<(<) OFF) 10228 Uphph<(<) Undervolt. is Voltage Prot. BLOCKED (Uph-ph<(<) BLK) 10229 U1<(<) Undervolt. is switched Voltage Prot.
Page 582 A Appendix Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 10272 3U0> TimeOut (3U0> TimeOut) Voltage Prot. 10273 3U0>> TimeOut (3U0>> Time- Voltage Prot. Out) 10274 3U0>(>) TRIP command Voltage Prot. (3U0>(>) TRIP) 10280 U1>...
Page 583 A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 10317 Uph-e<(<) TRIP command (Uph- Voltage Prot. e<(<) TRIP) 10325 Uph-ph< Pickup (Uph-ph< Voltage Prot. Pickup) 10326 Uph-ph<< Pickup (Uph-ph<< Voltage Prot. Pickup) 10327 Uphph<(<) Pickup L1-L2 (Uph- Voltage Prot.
Page 584: A.9 Group Alarms
A Appendix Group Alarms Description Description Error Sum Alarm Error 5V Error A/D-conv. Error1A/5Awrong Error neutralCT Failure Σ I Alarm Sum Event Fail I balance Fail Σ U Ph-E Fail U balance Fail U absent VT FuseFail>10s VT FuseFail Fail Ph. Seq. Fail Battery Error Board 1 Error Board 2...
Page 585: A.10 Measured Values
A.10 Measured Values A.10 Measured Values Description Function IEC 60870-5-103 Configurable in Matrix Control DIGSI (CntrlDIGSI) Cntrl Authority Upper setting limit for IL1dmd (IL1dmd>) Set Points(MV) Upper setting limit for IL2dmd (IL2dmd>) Set Points(MV) Upper setting limit for IL3dmd (IL3dmd>) Set Points(MV) Upper setting limit for I1dmd (I1dmd>) Set Points(MV)
Page 586 A Appendix Description Function IEC 60870-5-103 Configurable in Matrix Power Factor (PF =) Measurement Frequency (Freq=) Measurement S (apparent power) (S =) Measurement Frequency (busbar) (F-bus =) Measurement Frequency (difference line-bus) (F-diff=) Measurement Angle (difference line-bus) (ϕ-diff=) Measurement Frequency (line) (F-line=) Measurement U1co (positive sequence, compounding) Measurement...
Page 587 A.10 Measured Values Description Function IEC 60870-5-103 Configurable in Matrix U L23 Maximum (UL23Max=) Min/Max meter U L31 Minimum (UL31Min=) Min/Max meter U L31 Maximum (UL31Min=) Min/Max meter U1 (positive sequence) Voltage Minimum (U1 Min/Max meter Min =) U1 (positive sequence) Voltage Maximum Min/Max meter (U1 Max =) Apparent Power Minimum (SMin=)
Page 588 A Appendix Description Function IEC 60870-5-103 Configurable in Matrix 1047 Reactive Power Maximum Reverse (Qmax Min/Max meter Rev =) 1048 Power Factor Minimum Forward (PFmin- Min/Max meter Forw=) 1049 Power Factor Maximum Forward (PFmax- Min/Max meter Forw=) 1050 Power Factor Minimum Reverse (PFmin Min/Max meter Rev=) 1051...
Page 589 A.10 Measured Values Description Function IEC 60870-5-103 Configurable in Matrix 14030 UL1E (primary) (UL1E =) Measure relay2 14031 Angle UL1E (ϕUL1E =) Measure relay2 14032 UL2E (primary) (UL2E =) Measure relay2 14033 Angle UL2E (ϕUL2E =) Measure relay2 14034 UL3E (primary) (UL3E =) Measure relay2 14035 Angle UL3E (ϕUL3E =)
Page 590 A Appendix 7SA522 Manual C53000-G1176-C155-3...
Page 591: Literature
Literature SIPROTEC 4 System Description; E50417-H1176-C151-A2 SIPROTEC DIGSI, Start UP; E50417-G1176-C152-A2 DIGSI CFC, Manual; E50417-H1176-C098-A4 SIPROTEC SIGRA 4, Manual; E50417-H1176-C070-A2 7SA522 Manual C53000-G1176-C155-3...
Page 592 Literature 7SA522 Manual C53000-G1176-C155-3...
Page 593: Glossary
Glossary Battery The buffer battery ensures that specified data areas, flags, timers and counters are re- tained retentively. Bay controllers Bay controllers are devices with control and monitoring functions without protective functions. Bit pattern indica- Bit pattern indication is a processing function by means of which items of digital tion process information applying across several inputs can be detected together in paral- lel and processed further.
Page 594 Glossary Component view In addition to a topological view, SIMATIC Manager offers you a component view. The component view does not offer any overview of the hierarchy of a project. It does, how- ever, provide an overview of all the SIPROTEC 4 devices within a project. COMTRADE Common Format for Transient Data Exchange, format for fault records.
Page 595 Glossary Earthing means that a conductive part is to connect via an earthing system to the → Earthing earth. Earthing Earthing is the total of all means and measured used for earthing. Electromagnetic Electromagnetic compatibility (EMC) is the ability of an electrical apparatus to function compatibility fault-free in a specified environment without influencing the environment unduly.
Page 596 Glossary image. The current process state can also be sampled after a data loss by means of a GI. Global Positioning System. Satellites with atomic clocks on board orbit the earth twice a day in different parts in approx. 20,000 km. They transmit signals which also contain the GPS universal time.
Page 597 Glossary Internal single point indication → Single point indication Single-point indication fleeting → Transient information, → Single point indication IS_F ISO 9001 The ISO 9000 ff range of standards defines measures used to ensure the quality of a product from the development stage to the manufacturing stage. Link address The link address gives the address of a V3/V2 device.
Page 598 Glossary Navigation pane The left pane of the project window displays the names and symbols of all containers of a project in the form of a folder tree. Object Each element of a project structure is called an object in DIGSI. Object properties Each object has properties.
Page 599 Glossary RIO file Relay data Interchange format by Omicron. RSxxx-interface Serial interfaces RS232, RS422/485 SCADA Interface Rear serial interface on the devices for connecting to a control system via IEC or PROFIBUS. Service port Rear serial interface on the devices for connecting DIGSI (for example, via modem). Setting parameters General term for all adjustments made to the device.
Page 600 Glossary Slave A slave may only exchange data with a master after being prompted to do so by the master. SIPROTEC 4 devices operate as slaves. Time stamp Time stamp is the assignment of the real time to a process event. Topological view DIGSI Manager always displays a project in the topological view.
Page 601: Index
Index Checking: Tripping/Closing for the configured Oper- ating Devices 427 AC Voltage 433 Checking: User-defined Functions 427 Acknowledgement of Commands 368 Checks: Voltage Transformer Miniature Circuit Adaptive Dead Time (ADT) 249 Breaker (VT mcb) 414 Analog Inputs 432 Circuit Breaker 206, 307 Angle of Inclination of the Tripping Circuit Breaker Closure onto an Earth Fault 163 Characteristic 73...
Page 602 Index DC Voltage 433 Failure of the Measuring Voltage 323 Dead Line Check 248 Fault Annunciations 38 Definite Time Overcurrent Stage 3I0> 153 Fault Annunciations (Buffer: Trip Log) 348 Definite Time Stages 164 Fault Location 475 Definite Time Very High Set Current Stage Fault Protocol 485 3I0>>...
Page 603 Index Overcurrent Stage IP (IDMT protection with ANSI characteristics) 219 Life Contact 376 Overcurrent Stage IP (IDMT protection with IEC Limit Value Handling 526 characteristics) 218 Limit Value Monitoring 359 Overcurrent Stage Iph> (O/C with DT) 217 Limit values 359 Overvoltage Negative Sequence System U2 281 Limits for CFC Blocks 482 Overvoltage Phase-Earth 280...
Page 604 Index Retrieving Parameters 360 Transmission Channels 127 RS 485 Termination 397 Transmission of Binary Information 479 Transmission Statistics 350 Trip Circuit Supervision 374 Trip Dependent Messages 37 Trip with Delay 203 Trip/Close Tests for the Configured Operating Scanning Frequency 315 Devices 427 Series-compensated Lines 73 Tripping Logic of the Entire Device 338...
Page 605 Index 7SA522 Manual C53000-G1176-C155-3...
Page 606 Index 7SA522 Manual C53000-G1176-C155-3...

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