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Where K = (Z0 - Z1)/(3 x Z1)

and

0.0833 < ¦K¦ < 2.0

47° < MTA

+ ∠Κ

< 113°

Given the impedance settings selected,

K = 0.702

∠0.57°

You should perform a cursory check to be sure the minimum Zone 1, Zone 2, or Zone 3
secondary reaches at MTA are not below the minimum distance element reach setting of
0.125

Ω

secondary or above the maximum setting limit of 64

Ω

secondary.

- Other Settings Affected

Z1%, Z2%, Z3%, MTA

Current and Potential Transformer Ratio Selection

Current  transformer  ratio  (CTR)  selection  for  line  protection  is  often  based  on  the
transmission  line  current  carrying  capability. CTR  selections  also  determine  the  magnitude  of
secondary  fault  current  presented  to  the  relay.

Select  a  current  transformer  ratio  which  reduces  the  likelihood  of  CT  saturation  and  allows
the  current  transformer  to  deliver  a  reliable  secondary  representation  of  the  primary  current
during  a  fault  condition.

The potential transformer ratio (PTR) setting should be selected to match the primary voltage
ratio (l-n) to approximately 67 V

l-n

.

The synch-check potential transformer ratio (SPTR) setting should be selected to allow the
synch-check voltage input to range between 67 V

l-n

and 120 V

l-n

.

The  current  transformer  ratio  selected  for  this  example  is  1000/5  or  200:1.  This  ratio  allows
1000  A  of  load  to  flow  without  exceeding  five  amperes  of  secondary  current,  while  limiting
the  secondary  current  to  well  below  50  A  for  the  maximum  available  fault  duty.

The system voltage is 230 kV line-line or 132.8 kV line-neutral. The relay requires a
nominal phase voltage of approximately 66.4 V

l - n

or 115 V

l - l

. The PTR selected for this

example is 2000:1.The synch-check potential transformer uses the same ratio.

5-6

Applications

SEL-221F, -1 Instruction Manual

Date Code 920508

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Summary of Contents for SEL-221F

Page 1: ...ISTANCE RELAY GROUND DIRECTIONAL OVERCURRENT RELAY SYNCHRONISM CHECKING RELAY RECLOSING RELAY FAULT LOCATOR INSTRUCTION MANUAL SCHWEITZER ENGINEERING LABORATORIES 2350 NE HOPKINS COURT PULLMAN WA 99163 5603 TEL 509 332 1890 FAX 509 332 7990 ...

Page 2: ...national Treaty provisions All rights are reserved You may not copy alter disassemble or reverse engineer the software You may not provide the software to any third party The schematics and parts lists are provided solely for the purpose of product maintenance Copyright SEL 1989 1991 1992 1996 All rights reserved Printed in USA Patents Pending ...

Page 3: ......

Page 4: ...ses related to the shipment of defective units back to SEL or the provision of a substitute unit to the customer are the responsibility of the customer This expense may include but is not limited to freight insurance Customs clearance and duties All expenses related to the shipment of repaired units back to customers or the provision of a new unit to the customer will be borne by SEL PRODUCT UPGRA...

Page 5: ...ts not manufactured by SEL Such equipment and products may be covered by a warranty issued by the respective manufacturer This warranty is in lieu of any other warranties express or implied including without limitation any warranty of merchantability or fitness for a particular purpose and is in lieu of any and all other obligations or liability of SEL Under no circumstances shall SEL be liable fo...

Page 6: ...on to appear less remote by approximately a factor of 1 cos bL where bL is the line length in radians at 50 Hz One wavelength at 50 Hz is 5996 kilometers For example the line length of a 100 kilometer line in radians is 100 5996 x 2 x 3 14159 0 1048 radians The indication neglecting capacitance is about cos 0 1048 0 9945 times the actual fault location or about 0 55 kilometers short for a fault at...

Page 7: ...cifications as follows Equations for IEC Curves t operating time in seconds TD time dial setting M multiples of pickup Curve Cl Standard Inverse Beyond 20 multiples of pickup all characteristics become definite time equal to the time of M 20 Curve C2 Very Inverse Curve C3 Extremely Inverse Curve C4 Long Time Backup 2 SEL 221F Relay Addendum Date Code 961202 ...

Page 8: ...Time Curve C1 Time Curve C2 Time Curve C3 Time Curve C4 Date Code 961202 SEL 221F Relay Addendum 3 ...

Page 9: ...ACB phase rotation option references made in the instruction manual to voltage and current phase angle should be noted accordingly The firmware identification number FID may be used to verify whether your relay was ordered with ABC or ACB rotation All current and voltage inputs are connected to the SEL relay rear panel as shown in the instruction manual Date Code 930719 SEL Relay Addendum A 1 ...

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Page 14: ...fications 2 2 Detailed Specifications 2 7 Functional Description 2 31 Relay Element Operating Time Curves 2 38 Time Overcurrent Curve Equations 2 39 Logic Diagrams 2 44 COMMUNICATIONS Introduction 3 1 Serial Port Connections and Configurations 3 1 Communications Protocol 3 3 Command Characteristics 3 5 Command Descriptions 3 7 SEL 221F Distance Relay Fault Locator Command Summary 3 24 EVENT REPORT...

Page 15: ...rent Element Tests 7 30 Residual Time Overcurrent Element Timing Tests 7 30 Phase Overcurrent Element Tests 7 31 Loss Of Potential Test 7 32 Z2DG and Z3DG Timer Tests 7 33 Z2DP Timer Test 7 34 Remote End Just Opened Tests 7 35 Switch Onto Fault Tests 7 36 Recloser Test 7 37 Synchronizing and Polarizing Voltage Element Tests 7 38 Voltage Checking Logic Tests 7 38 Synchronism Checking Logic Tests 7 ...

Page 16: ...mple 4 5 40 Table 6 1 Pin Definition 6 4 Table 7 1 Fault Locator Test Values 7 10 Table 7 2 Output Contact and Target LED Results 7 10 Table 7 3 Three Phase Fault Voltages and Currents at MTA 7 18 Table 7 4 Zone 1 Three Phase Fault Test Quantities at MTA 7 20 Table 7 5 Zone 1 Three Phase Fault Test Quantities at MTA 45 7 21 Table 7 6 Zone 1 Phase Phase Test Voltages and Currents BC Fault 7 24 Tabl...

Page 17: ...e 4 1 Example System Single Line Diagram 4 11 Figure 5 1 230 kV Setting Example System Single Line Diagram 5 3 Figure 5 2 Sync Check Window 5 l 1 Figure 5 3 52A Input and 52BT Timing Diagram 5 22 Figure 5 4 Faulted Line With All Sources In 5 23 Figure 5 5 Faulted System with Breakers 1 and 2 Closed 5 24 Figure 5 6 Faulted System with Breaker 2 Open 5 24 Figure 5 7 Single Shot Unsupervised Reclose ...

Page 18: ...Test Connections for Three Phase Fault Test 7 20 Figure 7 9a Three Phase Voltage and Two Phase Current Source Test Connections for Phase Phase Mho Test 7 23 Figure 7 9b Three Phase Voltage and One Phase Current Source Test Connections for Phase Phase Mho Test 7 23 Figure 7 13 Three Phase Voltage and One Phase Current Source Test Connections for Phase Ground Distance Element Test 7 26 Figure 7 11 T...

Page 19: ...N TABLE OF CONTENTS Getting Started 1 1 Relay Overview 1 1 Model Variations Covered By This Instruction Manual 1 2 Other SEL 221F Relay Model Variations l 3 General Description l 3 FIGURES Figure 1 1 System Single Line Diagram for the SEL 221F 1 Relay Modification Explanation 1 3 ...

Page 20: ...ctive features perfor mance and versatility gained when applying any SEL 221F relay to your installations Three zones of instantaneous definite time phase and ground distance protection Residual time overcurrent element with selectable curves Instantaneous residual overcurrent element Negative sequence polarization of ground directional elements Versatile user programmable logic for outputs and tr...

Page 21: ... after 5 seconds with hot bus dead line supervision with the 79RS timer set for 20 seconds Breaker 2 is set up for synch check supervised closure with the 79RS timer also set for 20 seconds Assume the synch check timer is set for five seconds The MOD is setup for hot line dead bus reclosure in 35 seconds 25 seconds after Breaker 2 closes For the system shown consider a permanent fault on the trans...

Page 22: ...only displays targets TARGET command execution from Level 2 displays targets and allows the operator to change front panel LED assignments Excluding these differences the SEL 221F 8 relay is identical to the SEL 221F relay GENERAL DESCRIPTION Because the 1 relay variation is derived from the SEL 221F relay this manual refers to both variations standard and 1 as the SEL 221F relay The SEL 221F Phas...

Page 23: ...ents and saved for additional features such as metering and fault locating Relay elements process the analog data Some intermediate logic is performed such as overcurrent supervision of the mho elements directional supervision of the residual over current elements and grouping of certain elements into zones The relay generates an eleven cycle event report starting with information captured four cy...

Page 24: ... valuable for unmanned or remote substations The CLOSE A1 A2 A3 A4 and ALARM outputs may be specified as a or b type contacts TRIP outputs are always an a type contact The relay is compatible with the SEL PRTU protective relay terminal unit the SEL DTA Display Transducer Adapter SEL RD Relay Display and the SEL PROFILE Transmission Line Fault Analysis Program Date Code 920508 Introduction SEL 221F...

Page 25: ...2 Figure 2 4 Self Polarized Mho Element Reach at Maximum Torque Angle 2 32 Figure 2 5 Phase Phase Element Response for a Three Phase Forward Fault 2 33 Figure 2 6 Phase Phase Element Response for a Phase Phase Forward Fault 2 33 Figure 2 7 Phase Ground Element Response for a Phase Ground Forward Fault 2 34 Figure 2 8 Positive Sequence Polarizing Voltage Block Diagram 2 35 Figure 2 9 Programmable L...

Page 26: ...ports PORT 2 has front and rear panel connectors The serial ports use standard 9 pin subminiature D connectors 24 48 Volt 20 60 Vdc 12 watts 125 250 Volt 85 350 Vdc or 85 264 Vac 12 watts 3 5 x 19 x 10 5 8 89 cm x 48 2 cm x 26 7 cm H x W x D SEL 221F 1 Mounts in EIA 19 rack or panel cutout 40 F to 158 F 40 C to 70 C V I inputs 2500 Vac for 10 seconds Other 3000 Vdc for 10 seconds excludes EIA RS 2...

Page 27: ... 100 hours IEC 68 2 30 Temp Humidity Cycle Test six day type tested FUNCTIONAL SPECIFICATIONS Expanded Mho Characteristics for Phase Ground Phase Phase and Three Phase Faults Three zones of phase and ground distance protection Distance elements polarized from positive sequence memory voltage Polarization method provides distance element expansion for improved resistive fault coverage Independent t...

Page 28: ...curity to phase and ground distance elements May polarize ground directional overcurrent protection if enabled Loss of Potential LOP Detection Detects blown secondary potential fuse s condition Enabled or disabled with a simple setting When enabled an LOP condition blocks all mho distance elements LOP detection may be selected to close programmable output relay or the ALARM contact for indication ...

Page 29: ...tiate and cancel conditions Settable reclose reset timer Selectable voltage checking and synchronism checking can supervise reclosing Voltage Checking Closing may be supervised by Live line Dead Bus conditions Live bus Dead line conditions or either condition Supervision may be applied to closures initiated by external equipment Supervision is independent of polarizing potential transformer locati...

Page 30: ...ine the state of the output relay and reclosing sequence depending on which elements are asserted in the Relay Word Table 2 1 shows the SEL 221F Relay Word Table 2 1 Relay Word ZlP ZlG Z2PT Z2GT Z3 Z3T 3P21 32Q 67N 51NP 51NT 50NG 50P 50H IN1 REJO LOP 52BT 27S 27P 59S 59P SSC VSC Logic Inputs The relay has six opto isolator inputs to sense external conditions a programmable input received permissiv...

Page 31: ...commands If tripping occurs after the end of the event report the trip triggers a second report For details on the contents and analysis of relay event reports see Section 4 EVENT REPORTING Fault Location The relay computes fault location using event report data stored for each fault or disturbance The primary fault locating algorithm compensates for prefault current to improve fault locating accu...

Page 32: ... runs exhaustive self tests which ensure reliable operation If a test fails the relay enters a warning or failure state closes the ALARM output relay and issues a status report to the port designated automatic The duration of ALARM output contact closure depends on which self test warns or fails Self tests check the following items Analog Channel Offset IR IA IB IC VA VB VC and VS 5 V Power Supply...

Page 33: ...0 Z1 3xZ1 Z0 R0 jX0 Z1 R1 jX1 R0 X0 R1 X1 Relay Impedance Settings Accuracy Steady State Error 5 of set reach 0 01 ohm at MTA for V 5 V and I 2 A 10 of set reach 0 01 ohm at MTA for 1 V 5 V and 0 5 I 2 A Transient Overreach 5 of set reach plus steady state error Operating Speed See Figure 2 10 for operating time curves Memory Polarization Phase and ground distance elements are positive sequence me...

Page 34: ...t overreach 5 of set pickup 50AP 50BP 50CP phase fault detectors Pickup 0 5 to 40 A 0 1 A 2 of setting Transient overreach 5 of set pickup 50AH 50BH 50CH high set phase overcurrent elements Pickup 0 5 to 80 A 0 1 A 2 of setting Transient overreach 5 of set pickup Ground Overcurrent Elements Secondary Quantities 50N residual overcurrent element Nondirectional element supervises ground distance elem...

Page 35: ...onal Description portion of this section for equations to determine directional element sensitivities at fault angles other than maximum torque angle Sequence Component Elements Secondary Quantities The following elements are used in the recloser supervision logic and loss of potential detection logic Negative sequence overvoltage element 47QL Pickup V2 14 V fixed Negative sequence overcurrent ele...

Page 36: ... 0 5 10 000 TDUR Minimum Trip Duration Timer 0 0 2 000 0 Disables the OPEN Command TDPU Time delayed Pickup TDDO Time delayed Dropout Potential Inputs Polarizing potential inputs VA VB and VC should be driven from a set of three line potential transformers with their primaries connected in a grounded wye configuration and secondaries connected in a four wire wye The relay is equipped with three in...

Page 37: ...ns Table 2 2 Logic Input Functions Input Function IN1 Programmable Input PT Permissive Trip Input BT Block Trip Input DC Direct Close Input 52A 52 Auxiliary Contact Input ET External Trigger Input Programmable Input IN1 Asserting the IN1 input immediately and unconditionally sets Relay Word bit IN1 The IN1 bit remains set until the IN1 input deasserts dropping out about one half cycle after IN1 de...

Page 38: ...ps initiated by external protective relays backup protection breaker failure relaying bus differential relaying etc Output Contacts The relay has seven output contacts TRIP CLOSE ALARM and four programmable outputs Al A2 A3 and A4 You can program all outputs except the CLOSE and ALARM outputs using the LOGIC command Any output contacts except TRIP may be factory configured as a or b type All relay...

Page 39: ...LARM output closes while the relay detects a loss of potential condition if you select LOPE 2 3 or 4 Programmable Outputs A1 A2 A3 A4 These four outputs may be assigned to any combination of bits in the Relay Word Logic Description Relay logic includes relay elements timers and combinations of conditions Many of these are recorded in the Relay Word R which is the basis of programmable mask logic E...

Page 40: ...ontact Outputs Circuit breaker trip two contacts Circuit breaker close Programmable output 1 Programmable output 2 Programmable output 3 Programmable output 4 System alarm Timers Zone 2 delay for phase faults Zone 2 delay for ground faults Zone 3 delay Time delayed inverse of 52A Minimum Trip Duration 51NP 51NT 67N 50N 32Q 47QL 46QL 47P 27P 27S 59P 59S 25 IN1 PT BT DC 52A ET TRIP CLOSE A1 A2 A3 A4...

Page 41: ...ciated results are N Rlay sets LOP bit when loss of potential condition is detected Distance and directional elements are not blocked Set the LOP bit in a programmable logic mask to indicate condition if desired Y Relay sets LOP bit when loss of potential condition is detected Distance elements are blocked and directional elements default forward Set the LOP bit in a programmable logic mask to ind...

Page 42: ...E settings and their results LOPE Block 21 Setting on LOP N No Y Yes 1 Yes 2 Yes 3 Yes 4 No Table 2 3 LOPE Settings 52A Supervises LOP Relay Word Bit No No Yes N o Yes No Close ALARM Contact on LOP Bit Assertion No No No Yes Yes Yes Phase Overcurrent Conditions 50G 50AG 50BG 50CG 3G50 50AG 50BG 50CG 50NG 50N 50G 50P 50AP 50BP 50CP 3P50 50AP 50BP 50CP 50H 50AH 50BH 50CH Ground Overcurrent Condition...

Page 43: ... 2 OR 3 Z2G 21AG2 50AG 21BG2 50BG 21CG2 50CG 50N FDS NOT LOP LOPE Y 1 2 OR 3 Z3G 21AG3 50AG 21BG3 50BG 21CG3 50CG 50N FDS NOT LOP LOPE Y 1 2 OR 3 Z3 Z3P Z3G Zone 3 phase or ground fault Z2PT Z2P Z2PD Zone 2 phase timeout Z2GT Z2G Z2GD Zone 2 ground timeout Z3T Z3 Z3D Zone 3 timeout Synchronism and Voltage Checking Logic SSCI 59S 59P 25 NOT 52A NOT 50NG synchronism check initiate SSC SSCI for 25T 0...

Page 44: ... Program logic by setting masks for various conditions These masks are applied to the general Relay Word The form for each output equation follows Let R Relay Word MTU mask for trip MPT mask for trip MTB mask for trip MTO mask for trip Then TRIP R MTU R MPT PT REJO REJOE P OR G R MTB NOT BT R MTO 52BT TC Close TRIP contact TRIP Open TRIP contact NOT TRIP NOT 50NG 46QL TARGET RESET button pushed Mi...

Page 45: ... a logical 1 or logical 0 1 indicates a picked up element or true logic condition 0 indicates a dropped out element or false logic condition The Logic Description defines logic conditions in the Relay Word RELAY WORD Z1P Z1G Z2PT Z2GT Z3 Z3T 3P21 32Q 67N 51NP 51NT 50NG 50P 50H IN1 REJO LOP 52BT 27S 27P 59S 59P SSC VSC The meaning of each bit of the Relay Word is explained in the Relay Word Bit Sum...

Page 46: ...t 27S Synchronizing undervoltage condition Tests VS against VLO setting 27P Polarizing undervoltage condition Tests VP1 against VLO setting 59S Synchronizing overvoltage condition Tests VS against VHI setting 59P Polarizing overvoltage condition Tests VP1 against VHI setting SSC Synchronization supervised condition set by 25DV 25T SYNCP VSC Voltage supervised condition set by PSVC for disable LSDP...

Page 47: ...ast one phase and these conditions are maintained for at least one half cycle When REJOE P the 3P50 and 3P50D elements qualify the REJO condition Section 5 APPLICATIONS discusses the uses of the REJO function settings The relay uses the REJO bit in two places as a qualifier for permissive tripping and as an indicator in the Relay Word If the REJO function is enabled REJOE G or P in the relay setti...

Page 48: ...enable EN target lamp is lit If the relay trips it illuminates the LED cor responding to the element asserted at the time of trip The target LEDs latch The target LEDs which illuminated during the last trip remain lit until one of the following occurs Next trip Operator presses front panel TARGET RESET button Operator executes TARGET R command When a new trip occurs the targets clear and the LEDs ...

Page 49: ...en the relay trips during the open interval Recloser Reset Time 79RS The relay includes a 79RS reclosing reset timer setting The relay uses this timer in several ways To limit the CLOSE contact operation time To reset the recloser after a successful closing sequence To block the recloser for a short time after any close The relay operates the CLOSE output in response to command execution Direct Cl...

Page 50: ...ltage is present and normal When the timer expires at the end of its 25T setting the SSC bit in the Relay Word is set It remains set until any one of the four conditions listed above is violated Section 5 APPLICATIONS provides a discussion of the applications and setting selections for this logic Voltage Checking VSC Four voltage elements monitor high low voltage conditions on both sides of the ci...

Page 51: ...filter eliminates dc offsets When all samples are set to the same value the filter output is zero It also eliminates ramps which you may verify by setting the samples equal to 1 2 3 and 4 Again the output is zero Every quarter cycle the relay computes a new value of P for each input The current value of P combines with the previous value renamed Q to form a Cartesian coordinate pair This pair repr...

Page 52: ...two steps First the fault type must be determined then the location can be calculated For the event reports the fault type is determined independently from the relay element operations The involved phases are determined by fault current comparison Once fault type is determined the fault locator employs the Takagi algorithm to locate the fault Using prefault and fault data it compensates for errors...

Page 53: ...ge of the circuit board To select a baud rate for PORT 1 or PORTs 2 remove the relay front panel The jumpers are visible near the center of the relay drawout assembly to the right of the target LEDs Carefully move the jumpers using needle nosed pliers Caution Do not select two baud rates for the same port as this can damage the relay baud rate generator The relay is shipped with PORT 1 set to 300 ...

Page 54: ...elf test fails When it detects certain failures the relay disables the breaker control functions and places the relay output driver port in an input mode No outputs may be asserted when the instrument is in this configuration The relay runs all self tests on power up and before enabling new settings During normal operation it performs self tests at least every few minutes Offset The relay measures...

Page 55: ... to Digital Converter The analog to digital converter A D changes voltage signals derived from power system voltages and currents into numbers for processing by the microcomputer The A D test verifies converter function by checking conversion time The test fails if conversion time is excessive or a conversion starts and never finishes There is no warning state for this test Though an A D failure d...

Page 56: ...n N O one second contact pulse N O no ALARM contact assertion N O one second contact pulse FUNCTIONAL DESCRIPTION Self Polarized Mho Elements The following settings affect mho circles positive sequence line impedances R1 X1 maximum torque angle MTA set reach Z1 Z2 and Z3 and positive sequence transmission line angle arctan X1 R1 Self polarized mho circles pass through the im pedance plane origin T...

Page 57: ...50P non directional phase overcurrent elements Set the 50P element to assert during the most remote Zone 3 fault that the relay must detect If possible set the 50P element above maximum load current to improve security of the loss of potential logic Ground distance elements are supervised by single phase 50G phase overcurrent elements and the 50N residual overcurrent element Both elements are set ...

Page 58: ... for several fault types The forward reaching mho circles extend from the source impedance Zs forward to the relay impedance setting Zr Table 2 7 shows the voltage and current combinations used to operate and polarize the six mho elements Figure 2 5 Phase Phase Element Response for a Three Phase Forward Fault Figure 2 6 Phase Phase Element Response for a Phase Phase Forward Fault Date Code 920508 ...

Page 59: ...tion factor Torque T Tag Tbg Tcg Tab Tbc Tca Each torque is a product with the following form In a microprocessor implementation the computer calculates the six torque like products and tests their signs Positive products indicate impedances inside the expanded mho circle characteristics Positive sequence memory voltage polarization provides expansion which maximizes coverage for high resistance f...

Page 60: ...polarization voltages for the BC CA and AB elements are the same as those for the AG BG and CG elements rotated 90 Rotations back 90 are simple For example if x y is the phasor for polarizing the AG element then y x is the phasor for polarizing the BC element Time Overcurrent Elements and Curves The 51N time overcurrent element provides directional forward or nondirectional ground fault protection...

Page 61: ...Figure 2 9 illustrates the concept of the programmable logic mask by comparing it to the connections of discrete relay elements At the top the figure shows relay element contacts X Y and Z connected to a common reference such as the positive pole of a battery The other ends of these contacts pass through knife switches while the other side of the switches are connected to drive an auxiliary relay ...

Page 62: ...Next it ORs all three outputs together forming the condition which drives the output relay A1 A convenient shorthand expression for this bitwise AND followed by an OR operation is where R is the Relay Word X Y Z MA1 is the mask 1 1 0 indicates the bitwise AND and indicates the OR operation While the mask elements are fixed the Relay Word is updated each quarter cycle In this example if the X or Y ...

Page 63: ...ting At each reach percentage five tests were run Tests were performed for source impedance ratios SIR of 0 1 and 1 0 The diagrams show maximum average and minimum operating times at each test point Operating times include output contact closure time No prefault load current was included System frequency is 60 Hz Figure 2 10 Phase and Ground Distance Element Speed Curves 2 38 Specifications SEL 22...

Page 64: ...ots showing operating time versus multiples of pickup current are shown on the following pages Let t operating time in seconds TD time dial setting M multiples of pickup Curve 1 Moderately Inverse Curve 2 Inverse Curve 3 Very Inverse Curve 4 Extremely Inverse Date Code 920508 Specifications SEL 221F 1 Instruction Manual 2 39 ...

Page 65: ...Multiples of Pickup Figure 2 11 Residual Time Overcurrent Element Moderately Inverse Time Characteristic Curve 1 2 40 Specifications SEL 221F 1 Instruction Manual Date Code 920508 ...

Page 66: ...Multiples of Pickup Figure 2 12 Residual Time Overcurrent Element Inverse Time Characteristic Curve 2 Date Code 920508 Specifications SEL 221F 1 Instruction Manual 2 41 ...

Page 67: ...Multiples of Pickup Figure 2 13 Residual Time Overcurrent Element Very Inverse Time Characteristic Curve 3 2 42 Specifications SEL 221F 1 Instruction Manual Date Code 920508 ...

Page 68: ...Multiples of Pickup Figure 2 14 Residual Time Overcurrent Element Extremely Inverse Time Characteristic Curve 4 Date Code 920508 Specifications SEL 221F 1 Instruction Manual 2 43 ...

Page 69: ...Date Code 920508 Specifications SEL 221F 1 Instruction Manual 2 44 ...

Page 70: ...Date Code 920508 Specifications SEL 221F 1 Instruction Manual 2 45 ...

Page 71: ...Date Code 920508 Specifications SEL 221F 1 Instruction Manual 2 46 ...

Page 72: ...Date Code 920508 Specifications SEL 221F 1 Instruction Manual 2 47 ...

Page 73: ...Command Descriptions 3 7 SEL 221F Distance Relay Fault Locator Command Summary 3 24 TABLES Table 3 1 Serial Port Connector Pin Assignments 3 3 Table 3 2 Hexadecimal Binary Conversion 3 14 Table 3 3 Target LED Assignment 3 15 FIGURES Figure 3 1 Nine Pin Connector Pin Number Convention 3 2 Date Code 961208 Table of Contents i SEL 221F 1 Instruction Manual ...

Page 74: ...bold uppercase OTTER Keys to press appear in bold uppercase brackets ENTER Relay output appears boxed and in the following format SERIAL PORT CONNECTIONS AND CONFIGURATIONS The relay is equipped with two EIA RS 232 C serial communications ports PORT 2 has 9 pin connectors on both the front and rear panels designated PORT 2F and PORT 2R respectively PORT 2R located on the relay rear panel is typica...

Page 75: ...not select two baud rates for the same port as this can damage the relay baud rate generator The relay is shipped with PORT 1 set to 300 baud and PORT 2F 2R set to 2400 baud The baud rates of the ports are set by jumpers located near the front of the main board They are accessible by removing the top cover or the front panel Available rates are 300 600 1200 2400 4800 and 9600 baud The serial data ...

Page 76: ...d monitor RTS usually with their CTS input and stop transmission whenever the line deasserts If transmission continues data may be lost 8 CTS CTS The SEL 221F relay monitors CTS and transmits characters only if CTS is asserted 9 GND GND Ground for ground wires and shields COMMUNICATIONS PROTOCOL Communications protocol consists of hardware and software features Hardware protocol includes the contr...

Page 77: ... 11 and asserts the RTS output when the buffer drops below full The relay transmits XOFF ASCII hex 13 when the buffer is over full The relay deasserts the RTS output when the buffer is approximately 95 full Automatic trans mission sources should monitor for the XOFF character so they do not overwrite the buffer Transmission should terminate at the end of the message in progress when XOFF is receiv...

Page 78: ...such as SET operate only in Access Level 2 You may enter Access Level 2 with the 2ACCESS command and second password The Level 2 password is factory set to TAIL and may be changed with the PASSWORD command Startup Immediately after power is applied the relay transmits the following message to the port s designated automatic The ALARM contacts should open The represents the Access Level 0 prompt Th...

Page 79: ...nter the second password the relay opens access to Level 2 as indicated by the following message and Level 2 prompt Any Level 2 or Level 1 command can now be executed Command Format Commands consist of three or more characters only the first three characters of any com mand are required You may use upper or lower case characters without distinction except in passwords You must separate arguments f...

Page 80: ...rds during three consecutive attempts the relay pulses the ALARM contact closed for one second This feature can alert personnel to an unauthorized access attempt if the ALARM contact is connected to a monitoring system Access Level 1 Commands 2ACCESS 2ACCESS allows you to enter Access Level 2 The password is required unless you install jumper JMP103 The second password is set to TAIL at the factor...

Page 81: ...o display an event report for the nth event The parameter n ranges from 1 for the newest event through 12 for the oldest event stored in the relay memory If n is not specified the default value is 1 and the relay displays the newest event report You can control transmissions from the relay with the following keystrokes CTRL S Pause transmission CTRL Q Continue transmission CTRL X Terminate transmi...

Page 82: ...e difference between the first report generated at fault inception and the second report generated at the TRIP The TYPE column provides an abbreviated indication of the event type This is the same data presented for EVENT in the event summary automatically generated for each fault For faults the indication includes zone and phase involvement information The zone is determined from the relay elemen...

Page 83: ...example For event reports triggered by the assertion of the TRIP output the TYPE designation is further appended with a T This aids the determination of clearing times for faults which persist beyond the end of the first event report For example if the SEL 221F relay trips for a 3BG fault after the initial report was completed the second report shows 3BGT for TYPE For events other than faults TYPE...

Page 84: ... input at J201 on the rear panel if a time code signal is input If the relay reads the time code successfully it updates the internal clock calendar time and date to the time code reading and the relay transmits a message with relay ID string date and time If no IRG B signal is present or the code cannot be read successfully the relay sends the error message IRIGB DATA ERROR Note Normally it is no...

Page 85: ... TAR 0 The command displays the relay I D date and time of QUIT command execution Use this command when you finish communicating with the relay to prevent unauthorized access Control returns to Access Level 0 automatically after a settable interval of no activity see the TIME1 and TIME2 settings of the SET command SHOWSET SHOWSET displays the current relay and logic settings Settings cannot be ent...

Page 86: ... of any column Row 3 of any column The logic settings are shown in hexadecimal format Table 3 2 shows the equivalencies between hexadecimal hex and binary numbers to assist you in examining the logic settings display in event reports and the SHOWSET display Date Code 930830 Communications 3 13 SEL 221F 1 Instruction Manual ZIP ZIG Z2PT Z2GT Z3 Z3T 3P21 32Q 67N 51NP 51NT 50NG 50P 50H IN1 REJ0 L0P 5...

Page 87: ...A4 to binary gives A4 1010 0100 Now build the Relay Word for row 2 of mask MTO as follows 67N 51NP 51NT 50NG 50P 50H IN1 REJ0 1 0 1 0 0 1 0 0 A 4 STATUS STATUS allows inspection of self test status The relay automatically executes the STATUS command whenever a self test enters a warning or failure state If this occurs the relay transmits a STATUS report from the port s designated automatic see SET...

Page 88: ...est warnings and failures TARGET n k This command selects the information to be displayed on the front panel target LEDs and also communicates the state of the selected LEDs When the relay power is turned on the LED display indicates the functions marked on the front panel That is the LEDs default to displaying fault information shown in the row labelled RELAY TARGETS in the table on the next page...

Page 89: ...lowing When finished type TAR 0 ENTER to return to fault targets so field personnel do not misinterpret displayed data Also if the relay sends an automatic message to a timed out port it clears the target display and displays the TAR 0 data Press the front panel TARGET RESET button to clear the TAR 0 data and illuminate all target LEDs for a one second lamp test You can reset front panel targets t...

Page 90: ...n event record After command entry the relay responds Triggered and displays a record summary Use TRIGGER to inspect the input voltages For example when the relay is first installed execute the TRIGGER command draw the phasors Section 4 EVENT REPORTING gives an example of how to do this and check for the proper polarity and phase sequence of the inputs Access Level 2 Commands While all commands ar...

Page 91: ...ts aborts the closing operation with the message Aborted Install jumper JMP104 to enable the CLOSE command LOGIC n The LOGIC command programs the masks which control outputs and event report triggering The parameter n specifies a mask to program MTU Mask for trip unconditional MPT Mask for trip with permissive trip asserted MTB Mask for trip with block trip deasserted MTO Mask for trip with breake...

Page 92: ...ou must re enter all eight members even if some remain the same The relay repeats logic settings and the question mark prompt after entry of each row to allow corrections When all data are entered for each row the relay displays the new settings and prompts for approval to enable the relay with them Y ENTER enters the new data pulses the ALARM contacts closed momentarily and clears the event buffe...

Page 93: ...IP output relay closes in response to the OPEN command The TRIP relay remains closed until the 50NG and 46QL overcurrent elements have dropped out In all cases the TRIP output remains asserted at least TDUR cycles If TDUR 0 the OPEN command is aborted To open the power circuit breaker by command type OPEN ENTER The prompt Open BREAKER Y N is transmitted Answering Y ENTER yields a second prompt Are...

Page 94: ...tion install JMP103 on the main board With no password protection you may gain access without knowing the passwords and view or change current passwords and settings SET SET allows entry of relay settings At the setting procedure prompts enter new data or press ENTER to indicate no change The SET command prompts you for each setting The relay checks new settings against established limits twice If...

Page 95: ...nchronization voltage transformer ratio 1 10 000 MTA Maximum torque angle for mho elements 47 90 79OI Reclosing relay open interval 0 to 8 000 cycles 0 disables reclosing 79RS Reclosing relay reset time 60 to 8 000 cycles PSVC Polarizing and Synchronizing voltage checks N none S LSDP P LPDS or E either 27VLO Dead voltage threshold 0 2000 kV 59VHI Live voltage threshold 0 2000 kV 25DV Difference vo...

Page 96: ...on Y N 1 2 3 4 TIME1 Timeout for PORT 1 0 30 minutes TIME2 Timeout for PORT 2 0 30 minutes AUTO Autoport PORT 1 2 or 3 RINGS The number of rings after which the modem answers 1 30 rings Refer to the functional description and be sure the settings you choose result in relay performance appropriate to your application The AUTO setting selects PORT 1 PORT 2 or both serial ports for automatically tran...

Page 97: ... data and set target lights as follows TAR 0 Relay Targets TAR 1 Relay Word 1 TAR 2 Relay Word 2 TAR 3 Relay Word 3 TAR 4 Internal Elements TAR 5 Contact Inputs TAR 6 Contact Outputs TAR R Returns to TAR 0 and clears Be sure to return to TAR 0 when done so LEDs display fault targets TIME h m s Show or set time TIM 13 32 00 sets clock to 13 32 00 PM This setting is overridden when IRIG B synchroniz...

Page 98: ...nt Report 4 5 Example Event Reports 4 9 Firmware Identification 4 15 TABLES Table 4 1 Event Report Triggering Actions 4 1 Table 4 2 Non Event Report Triggering Actions 4 1 FIGURES Figure 4 1 Example System Single Line Diagram 4 11 Date Code 920508 Table of Contents i SEL 221F 1 Instruction Manual ...

Page 99: ...ut assertion PERMISSIVE TRIP input assertion BLOCK TRIP input assertion EXTERNAL TRIGGER input assertion TRIP output contact assertion The relay generates a second summary and long event report for the same fault if the trip occurs after the end of the first report Actions listed in Table 4 2 do not trigger an event report Table 4 2 Non Event Report Triggering Actions CLOSE command execution DIREC...

Page 100: ...issions are monitored by a dedicated channel or printed on a dedicated printer enter a timeout setting of zero for the appropriate port Due to the length of the full report it is not automatically transmitted You can display the full report with the EVENT command The summary event report includes Relay identifier Date and time Event type Fault location Secondary ohms from relay location to fault D...

Page 101: ...Zone 2 time delay expired or Zone 1 picked up 6 For 67N pickup but not Zone 3 2 or 1 5 For 51N pickup but not 67N Zone 3 2 or 1 H For 50H pickup but not 67N 51N or Zone 3 2 or 1 For none of the above picked up at mid fault The relay determines phase involvement independently of the relay element operations based upon a phase current magnitude comparison Compared currents are taken from two rows at...

Page 102: ...e faults For B C Two Phase faults For C A Two Phase faults For A B Two Phase to Ground faults For B C Two Phase to Ground faults For C A Two Phase to Ground faults For Three Phase faults The zone and phase involvement data are joined into a single string completing the TYPE designation as in 3BG for a Zone 3 B phase to ground fault For event reports triggered by TRIP output assertion TYPE designat...

Page 103: ...teristic Fault Duration The event summary contains a fault duration calculated from the first pickup of a fault detecting element until the last fault detecting element drops out or the event report ends Maximum Phase Current The relay displays the maximum phase current magnitude calculated in the same event report row where fault data was gathered for the fault locating calculation This data help...

Page 104: ...ify why we refer to the older data as the leading component of the phasor Consider a sinewave having zero phase shift with respect to t 0 and a peak amplitude of 1 Now consider two samples one taken at t 0 the other taken 90 later They have values 0 and 1 respectively By the above rules the phasor components are X Y 1 0 Now consider a cosine function Its samples taken at t 0 and t 90 are 1 and 0 i...

Page 105: ...timer expired 3 Zone 2 or 3 picked up 50P Phase overcurrent elements H 50H P 50P G 50G 51N Residual time overcurrent P 51NP T TRIP high set picked up picked up picked up 51N element picked up 51N element time out 50NG Sensitive residual or phase overcurrent element P 50NG 67N Residual overcurrent units P 67N 27S Synchronism checking ndervoltage detection S 27S 27P Polarizing undervoltage condition...

Page 106: ...mary Event Report Section TRIP output T TRIP contact closed CLOSE output C CLOSE contact closed Programmable output 1 1 Al contact closed Programmable output 2 2 A2 contact closed Programmable output 3 3 A3 contact closed Programmable output 4 4 A4 contact closed ALARM output A ALARM contact closed IN1 Programmable input I IN1 input asserted PERMISSIVE TRIP input P PT input asserted BLOCK TRIP inp...

Page 107: ...ote that the line breaker is closed as signified by the 5 in the 52A column Event report data for the voltages and currents is displayed in rectangular format You can easily convert these rectangular values to polar format as described under Interpretation of Voltage and Current Data Section 6 INSTALLATION includes a blank form for plotting voltage and current phasors A completed SEL Direction and...

Page 108: ...NO EQUIPMENT SEL 221F Relay INSTALLATION ROUTINE X OTHER LOAD CONDITIONS STATION READINGS MW OUT IN MVAR OUT IN VOLTS AMPS SEL READINGS M W 155 27 MVAR USE THE VALUES IN ROWS 1 AND 2 ABOVE TO DRAW PHASOR DIAGRAMS BELOW CURRENTS VOLTAGES 4 10 Event Reporting SEL 221F 1 Instruction Manual Date Code 920423 ...

Page 109: ...he top of the event report are referenced to this row of data The relay labelled the event a Zone 1 AG fault and calculated a fault location 75 86 miles from the relay terminal The relay is expected to trip for this fault The fault detecting element is the Zone 1 ground distance element set in the MTU logic mask Figure 4 1 Example System Single Line Diagram Date Code 920423 Event Reporting SEL 221...

Page 110: ...Example Event Report 2 4 12 Event Reporting SEL 221F 1 Instruction Manual Date Code 930830 ...

Page 111: ...idents shown in Example Event Report 2 by quarter cycle Quarter Cycle Event Report Shows 1 14 Prefault conditions No protective relay elements are picked up 5 in 52A Inputs column verifies breaker closure as does load current flow 15 Fault Inception G in 50P column shows phase current reached 50G element pickup threshold P in 50NG column shows phase current reached 50N element pickup threshold 16 ...

Page 112: ...output is asserted indicating assertion of a reclose initiating condition in this case Z1G 20 32 Fault detecting elements and output contacts remain asserted Fault locating event type and fault current information is calculated from data in this area of the event report The relay tripped in event report row 19 due to assertion of the Zone 1 ground distance element Z1G The A3 contact asserted to in...

Page 113: ...e polarizing voltage input is picked up No protective relay elements are picked up T in TP Outputs column shows that trip is still asserted The 9 0 cycle TDUR setting ensures that the trip contacts remain closed for at least nine cycles The event summary shows that the fault was an A G fault in Zone 1 at approximately 75 miles from the relay location The fault duration was 6 25 cycles and maximum ...

Page 114: ...ifier Meaning Z 1 2 1 stop bit 2 stop bits Power System Frequency Nominal Amps per Phase Nominal Volts per Phase Fault Locator Distance Units Phase Sequence of Power System Recloser Logic Main Board Configuration 52BT or Trip in Relay Word Time Overcurrent Curves Option Description Communications Protocol Stop Bits Please contact Schweitzer Engineering Laboratories Inc for more information concern...

Page 115: ...GURES Figure 5 1 230 kV Setting Example System Single Line Diagram 5 3 Figure 5 2 Sync Check Window 5 11 Figure 5 3 52A Input and 52BT Timing Diagram 5 22 Figure 5 4 Faulted Line With All Sources In 5 23 Figure 5 5 Faulted System with Breakers 1 and 2 Closed 5 24 Figure 5 6 Faulted System with Breaker 2 Open 5 24 Figure 5 7 Single Shot Unsupervised Reclose Sequence 5 37 Figure 5 8 Reclosing Cancel...

Page 116: ...elay includes a single shot recloser with user selectable initiate and cancel conditions The recloser can be supervised using an independent synchronism checking relay included in the SEL 221F relay Also included is a voltage checking function which can be set to supervise reclosing using live bus dead line dead bus live line conditions or either The synchronism checking and voltage checking relay...

Page 117: ...ustment of relay settings to meet virtually any contingency Its application also offers the benefits of event reporting and fault locating Replacement of Outdated Protective Relays The relay is an ideal replacement for aging or obsolete electromechanical relays Compact size and simple field wiring make replacing electromechanical relays with this relay especially convenient in crowded substations ...

Page 118: ...sequence Branch Line Impedances Positive sequence Zero sequence Source Impedances Source S Source R Current Transformer Ratio Potential Transformer Ratio 230 kV 132 8 kV line neutral 100 miles Z1 81 16 80 1 13 90 j79 96 Z0 252 01 80 5 41 50 j248 57 Z1AB Z1C D 40 58 80 1 6 95 j39 98 Z0AB Zl CD 126 01 80 5 20 75 j124 29 Z1S Z1R 20 29 80 14 Z0S Z0R 3 x Z1S 1000 5 200 1 2000 1 primary Ω primary Ω prim...

Page 119: ...rectional instantaneous overcurrent element Relay Settings The following information presents considerations for selecting each relay setting value Use this information to help improve your understanding of the relay functions Select relay settings appropriate to your applications Fault voltages and currents in this example were derived from a fault study of the system in Figure 5 1 Values entered...

Page 120: ... line are entered as relay settings R1 X1 R0 and X0 Values entered for R1 and X1 are the positive sequence resistance and reactance for the protected transmission line section The R0 value is transmission line zero sequence resistance the X0 value is transmission line zero sequence reactance Enter all impedances in primary ohms The relay fault locator uses the line length setting to scale the calc...

Page 121: ...nsformer to deliver a reliable secondary representation of the primary current during a fault condition The potential transformer ratio PTR setting should be selected to match the primary voltage ratio l n to approximately 67 V l n The synch check potential transformer ratio SPTR setting should be selected to allow the synch check voltage input to range between 67 Vl n and 120 Vl n The current tra...

Page 122: ... extends the amount of resistive coverage provided by the mho elements MTA selected for this example is 80 1 Note that this value matches the positive sequence line impedance angle of 80 1 Setting Limit Check The primary setting range check allows MTA settings from 47 90 The secondary check for this setting checks the sum of the MTA setting and the angle of the residual compensation factor K The s...

Page 123: ... fault logic enabled for the line test shot see 52BT Setting for details Close Supervision Settings PSVC 27VLO 59VHI 25DV SYNCP 25T VCT The SEL 221F relay includes two functions which can supervise close operations including reclosures and external close operations The voltage condition checking function supervises closures based upon hot bus dead line hot line dead bus or either condition The syn...

Page 124: ...he synchronizing voltage VS This difference voltage is then compared against the 25DV setting When the phasor difference between VP and VS is less than the 25DV setting for 25T time the relay asserts the SSC bit in the Relay Word The relay calculates V1 from the positive sequence voltage presented to the relay polarizing inputs The relay checks the magnitudes of V1 and VS to ensure that both volta...

Page 125: ...that 25DV is determined from the known angle ø The 25DV setting is approximated with the equation The value of ø should be the maximum angle across the breaker to allow closing Figure 5 2 Sync Check Window For our example for a maximum angle of 30 and 59VHI equal to 80 of nominal phase neutral voltage on a 230 kV system The slip frequency is the maximum allowed frequency difference between VP and ...

Page 126: ...ronism an external close is not allowed For the 27VLO setting we assume that the line is dead for reclosing purposes if line voltage is below 20 of nominal voltage For the 59VHI setting we assume that the line is live for reclosing purposes if line voltage is above 80 of nominal voltage For sync check purposes we use the 25DV voltage value calculated above The VS input is taken from a bus side PT ...

Page 127: ...within specified VS ranges The relay allows SYNCP settings of A B or C to indicate the phase which the VS input is attached to If VS is not connected in your application you may use A B or C for a SYNCP setting The primary setting range check allows 25T and VCT timer settings of 0 8 000 cycles Other Settings Affected 79OI open interval timer A1 Programmable Output Time Delayed Pickup and Dropout S...

Page 128: ...each for the Zone 1 three phase and phase phase elements is 80 of the positive sequence impedance of Line 2 The reach settings for the phase distance elements are a percentage of the positive sequence line impedance settings along the line angle When the MTA setting differs from the positive sequence line angle the relay calculates the mho circle diameter with the following equation For this examp...

Page 129: ...the effects of infeed This point must be verified using a fault study to calculate the apparent ohms at the local terminal for a fault at the remote end of the transmission line In the example system 120 is selected for the Zone 2 elements with assurance that all phase faults on Line 2 are detectable even with infeed from the remote terminals Assuming Breaker 5 Zone 1 reach is set for 80 of the li...

Page 130: ...lay Word Bits and Other Settings Affected Zone 2 must be less than Zone 3 The Z2PT and Z2GT bits in the Relay Word depend on the Z2 setting Zone 3 Reach Setting Z3 The Zone 3 elements time delayed outputs can serve as remote backup for faults beyond the far bus For the relay at Breaker 3 Setting Limit Check The primary limit check allows Zone 3 percent reach settings of 0 3200 with the require men...

Page 131: ...Bits and Other Settings Affected Z2PT and Z2GT bits in the Relay Word Zone 3 Phase and Ground Time Delay Z3D The Z3D timer adds a settable delay to the instantaneous outputs of the Zone 3 phase and ground distance elements The time delayed output of the Zone 3 distance elements is represented by the Z3T bit in the Relay Word Time delayed Zone 3 elements provide time step protection The Zone 3 phas...

Page 132: ... Relay Word Bits and Other Settings Affected None Phase and Residual Overcurrent Element Setting 50NG The 50NG setting selects pickup thresholds for the 50N and 50G ground distance element fault detector overcurrent elements Before any ground distance element can pickup the relay must detect phase and residual current greater than the 50NG setting Calculate the phase and residual current for the m...

Page 133: ...t when REJOE G Low Set Phase Overcurrent Element Setting 50P The 50P element provides fault detector supervision of the phase distance elements and must pick up for all fault conditions where a phase distance element is expected to operate The ideal setting for the 50P element is above load but below minimum fault duty for the most remote Zone 3 phase fault that the relay must detect Although it i...

Page 134: ...tch onto fault logic If a line breaker is closed into a close in three phase bolted fault where line side potential transformers are used polarizing voltage for the three phase distance elements is never established In this situation the distance elements do not operate The 50H element is provided to help prevent a failure to trip the line breaker in this instance The 50H element measures current ...

Page 135: ...consider only faults in front of the line terminal for coordinating purposes For the relay at Breaker 3 a single line to ground fault at Bus C dictates the sensitivity required for the residual time overcurrent pickup The residual current magnitude for this fault is 540 A primary To allow for ground fault resistance a value of 50 of 540 A is selected as the residual time overcurrent element pickup...

Page 136: ... 120 of this maximum EOL single line to ground SLG fault duty This prevents the instantaneous element from overreaching the forward bus The maximum residual current measured at Breaker 3 for a fault at Bus C equals 545 A To ensure that the instantaneous element does not overreach Bus C the 67NP setting should be 120 of 545 A This 120 factor accounts for differences between the modeled and actual s...

Page 137: ...ed in the MTO logic mask causes the relay to close the TRIP output contacts This logic provides Switch Onto Fault SOTF protection Figure 5 2 illustrates the timing relationship of the 52A input and 52BT element Figure 5 3 52A Input and 52BT Timing Diagram MTO logic is enabled during the time period shown for Regions 1 and 2 During Region 1 the MTO logic is enabled to protect the open line breaker ...

Page 138: ...onger than the open interval timer by the maximum expected breaker opening time If the 52BT timer does not expire before the breaker recloses switch onto fault protection is not enabled for that reclose If high speed reclosing is not required typical 52BT settings are 15 20 cycles Figure 5 4 Faulted Line With All Sources In For the relay at Breaker 3 in Figure 5 1 we enable the Zone 3 instantaneou...

Page 139: ...ssion applications the cost of communication equipment for line protection is not justifiable In these installations it is still possible to achieve accelerated trip times We can do this because certain system conditions indicate in section faults In the system shown in the figures below we know that after Breaker 2 clears its contribution to the fault the only current that is permitted to flow th...

Page 140: ... 50BG 50CG 3G50D 3G50 2 cycle TDDO 50P 50AP 50BP 50CP 3P50 50AP 50BP 50CP 3P50D 3P50 2 cycle TDDO 50G asserts when any phase current is above the 50NG setting 3G50 asserts when all three phase currents are above the 50NG setting 3G50D is an instantaneous pickup two cycle time delayed dropout 3G50 element 50P asserts when any phase current is above the 50P setting 3P50 asserts when all three phase ...

Page 141: ...ng The permissive tripping REJO portion of the output equation for the TRIP contact is Where R Relay Word MPT Mask for Permissive or REJO Tripping Used in this way the REJO condition permits tripping for the relay elements set in the logic mask for Permissive Tripping MPT in the same manner as asserting the Permissive Trip input of the relay You may set the MPT mask as if the relay were being used...

Page 142: ...ive sequence overcurrent detector 47P Low set positive sequence overvoltage detector 50P Low set phase overcurrent element For one or more blown PT fuses the relay declares a loss of potential condition when the measured negative sequence voltage exceeds 14 V of V2 and measured negative sequence current is below 0 083 A secondary For three blown PT fuses the relay declares an LOP condition when th...

Page 143: ...f potential condition is detected Distance and directional elements are not blocked Relay asserts ALARM contact to indicate the LOP condition The following table summarizes the available LOPE settings and their results LOPE Block 21 52A supervises LOP setting on LOP Relay Word bit Close ALARM contact on LOP bit assertion N No No No Y Yes No No 1 Yes Yes No 2 Yes No Yes 3 Yes Yes Yes 4 No No Yes LO...

Page 144: ... to prevent accumulation of toll charges if an operator does not hang up PORT 2 is to be connected to an SEL DTA and should never time out This allows the SEL DTA to receive any automatic message trans mitted by the relay Setting Limit Check The TIME1 and TIME2 limit check allows settings of 0 30 minutes A zero setting signifies that the port never times out There is no secondary limit check for t...

Page 145: ...lows for the modem to answer between 1 and 30 rings Other Settings Affected None Full Example Setting Group The following table shows all relay settings calculated above R1 13 90 CTR 200 00 790I 40 00 PSVC S 25T 300 00 A1TP 0 00 Z1 80 00 Z2DP 30 00 50NG 250 00 51NP 270 00 67NP 650 00 TIME1 5 Table 5 1 Settings for Bus B 230 kV Breaker 3 X1 79 96 RO 41 50 X0 248 57 LL 100 00 PTR 2000 00 SPTR 2000 0...

Page 146: ... required to interface with the communications equipment Each mask is independent from the other masks This allows multiple schemes to function simultaneous ly The following guideline shows typical usage of bits in each mask Please note that each application requires a careful study of bits used in each mask This guideline is included as a reference of typical Relay Word bit uses MTU Mask for Trip...

Page 147: ...ermissive Trip Input Asserted The relay closes the TRIP output when the Permissive Trip PT input is asserted or the REJO condition is enabled and asserted and elements selected in the MPT mask pick up As with the MTU logic mask it is not advisable to mask non directional elements in the MPT logic mask unless your application permits Typical bits masked in the MPT logic mask include Zone 3 instanta...

Page 148: ... delayed inverted follower of the 52A input see switch onto fault logic explanation for a detailed timing explanation of the 52BT bit This tripping mask differs from the MTU MPT and MTB tripping masks because it is acceptable to mask sensitive nondirectional elements into MTO in certain applications Such masking is advisable except in applications where the line breaker is closed into a line energ...

Page 149: ...the SSC bit asserts The SSC bit asserts when the relay detects that the sync check and polarizing voltages are in synchronism Using this setting contact A1 may be used to supervise reclosures or external close signals Mask for the A2 Output Contact MA2 Z1P Z1G Z2PT Z2GT Z3 Z3T 3P21 32Q 0 0 0 0 0 0 0 0 67N 51NP 51NT 50NG 50P 50H IN1 REJO 0 0 0 0 0 0 0 0 LOP 52BT 27S 27P 59S 59P SSC VSC 0 0 0 0 0 0 ...

Page 150: ...P Z1G Z2PT Z2GT Z3 Z3T 3P21 32Q 1 1 1 1 0 0 0 0 67N 51NP 51NT 50NG 50P 50H IN1 REJO 1 0 0 0 0 0 0 0 LOP 52BT 27S 27P 59S 59P SSC VSC 0 0 0 0 0 0 0 0 Event Report Hexadecimal Code F0 80 00 The example mask for reclose initiation selects the Zone 1 instantaneous elements 67N Z1P ZlG and the time delayed Zone 2 phase and ground distance elements Z2PT Z2GT MRC Mask for Reclose Cancellation If an eleme...

Page 151: ...Also there is one example of a cancelled reclosing shot Section 2 SPECIFICATIONS provides detailed reclosing logic descriptions The table below outlines the reclosing examples in this section Table 5 2 Reclosing Relay Timing Examples Example 1 Single Shot Unsupervised Reclose Sequence Example 2 Reclosing Cancelled Due to RC Assertion Example 3 Live Bus Dead line Supervised Reclose Example 4 Sync c...

Page 152: ...eclose cancel condition can occur Table 5 3 shows the recloser settings used for Examples 1 and 2 Settings not shown in Table 5 3 are identical to the example settings calculated earlier in this section Figure 5 7 shows the timing of Example 1 Settings marked N A are not applicable to the example Table 5 3 Recloser Settings for Examples 1 and 2 PSVC N A 27VLO N A 59VHI N A 25DV N A SYNCP N A 25T N...

Page 153: ...osure of the breaker auxiliary contact When the breaker closes the phase phase fault is reenergized The relay Z1P element picks up causing the relay to TRIP and the RI bit to assert Again the breaker opens and the 52A input deasserts Because the available reclosing shot has operated when the relay trips a second time the recloser is locked out and the breaker remains open Example 2 Reclosing Cance...

Page 154: ...7VLO 26 6 59VHI 106 2 25DV N A SYNCP A 25T N A VCT 30 cycles 79OI 40 cycles 79RS 240 cycles TDUR 9 cycles Figure 5 9 Live Bus Dead Line Supervised Reclose Referring to Figure 5 9 at t 0 a permanent phase ground fault occurs within the relay Zone 1 reach The relay detects the fault and asserts the TRIP outputs fulfilling the first requirement to initiate the reclosing sequence Because the Z1G Zone ...

Page 155: ...es The relay issues the CLOSE signal Because the A1 contact wired in series with the CLOSE contact is also closed the breaker close coil is energized and the breaker recloses The 52A input is asserted by closure of the breaker auxiliary contact When the breaker closes the phase ground fault is reenergized The relay Z1G element picks up causing the relay to TRIP and the RI bit to assert Again the b...

Page 156: ...RIP drops out When the line breaker opens normal bus voltages are restored In cycle six the 59S element asserts indicating that VS is above the 59VHI setting The bus is live for reclosing purposes In cycle 60 remote breaker has reclosed the line is reenergized and the 59P element asserts The line is live for reclosing purposes The magnitude of the difference voltages falls below the relay 25DV set...

Page 157: ...E 1 OF 6 DATE SUBSTATION CIRCUIT BREAKER DEVICE NO FUNCTION MAKE C T SETTING MODEL STYLE NO P T SETTING PART SOFTWARE VERSION SERIAL POWER SUPPLY VOLTS ac dc LOGIC INPUT Vdc SECONDARY INPUTS V ø 67L N NOMINAL AMPS 5 Hz 60 Date Code 921110 ...

Page 158: ...SETTINGS SHEET FOR SEL 221F RELAY PAGE 2 OF 6 DATE Date Code 921110 ...

Page 159: ...ing SPACE COMMA SEMI COLON and SLASH LEVEL 0 ACCESS ENTER PASSWORD 2ACCESS ENTER PASSWORD LEVEL 1 LEVEL 2 ENTER SETTINGS PER MATRIX TABLE NOTE FOR NEW RELAYS BEGIN WITH LEVEL 1 PASSWORD OTTER AND LEVEL 2 PASSWORD TAIL WHEN IN LEVEL 2 MODIFY PASSWORDS VIA PASSWORD 1 AND 2 COMMANDS Date Code 921110 ...

Page 160: ...SETTINGS SHEET PAGE 4 OF 6 FOR SEL 221F RELAY DATE Date Code 930601 ...

Page 161: ...SETTINGS SHEET PAGE 5 OF 6 FOR SEL 221F RELAY DATE Date Code 961208 ...

Page 162: ...ull distance in miles or kilometers between stations Zones 2 and 3 are limited as follows ohmic range is 0 125 to 64 ohms secondary Zone 1 Zone 2 Zone 3 Comments Settings recommended by Settings approved by Settings approved by Settings performed by Test printout required Yes No Substation Date Code 921110 ...

Page 163: ...sions Panel Cutout and Drill Plan 6 8 Figure 6 4 Communications and Clock Connections One Unit at One Location 6 9 Figure 6 5 Communications and Clock Connections Multiple Unit at Once Location 6 9 Figure 6 6 SEL Relay Communications Diagram for Connection to the SEL DTA 6 10 Figure 6 7 External Current and Voltage Connection 6 10 Figure 6 8 Dc External Connection Diagram Typical 6 11 SEL Directio...

Page 164: ...le switch if installed The power continues through a surge filter and connects to the switching power supply The control power circuitry is isolated from the frame ground Secondary Circuits The relay presents a very low burden to the secondary potential and current circuits It requires four wire wye potentials and three currents from the power system current trans former secondaries Control Circui...

Page 165: ...ircuit wiring If these wires are bundled switching spikes and surges can cause noise in the communications wiring This noise may exceed the communications logic thresholds and introduce errors The IRIG B clock cable should also be routed away from the control wiring and secondary circuits Jumper Selection All jumpers are on the front edge of the main board They are easily accessed by removing the ...

Page 166: ...m SEL Cable configuration sheets are also available at no charge for a large number of devices Contact the factory for more information female chassis connector as viewed from outside panel Figure 6 1 Nine Pin Connector Pin Number Convention EIA RS 232 C Cables SEL 221F 9 Pin DTE DEVICE GND 5 5 GND TXD 3 2 RXD RXD 2 3 TXD SEL CABLE 234 RTS 7 Jumper CTS 8 1 DCD 4 DTR Jumper 6 DSR 8 CTS 9 RI SEL 221...

Page 167: ...ual IRIG B input circuit is a 56 ohm resistor in series with a opto coupler input diode The input diode has a forward drop of about 1 5 volts Driver circuits should put approx imately 10 mA through the diode when on The IRIG B serial data format consists of a one second frame containing 100 pulses and divided into fields The relay decodes the second minute hour and day fields and sets the internal...

Page 168: ...tation Execute the METER command and make sure the readings are accurate If they are not be sure the correct PT ratio was entered Remember that displayed values are in primary line to neutral and line to line kV 3 Use the TRIGGER command to generate an event record Type EVENT 1 ENTER and examine the event record Refer to the top row of data as the Y components and the next row as the X components ...

Page 169: ...loses for all of these conditions if the 52A input is not asserted indicating the circuit breaker is open and no trip condition is present The CLOSE relay opens when the 52A input is asserted or the 79RS timer expires whichever occurs first If the Permissive Trip and Block Trip inputs are used check them for proper operation see the LOGIC MPT and LOGIC MTB settings in Section 3 COMMUNICA TIONS An ...

Page 170: ...Figure 6 2 Horizontal Front and Rear Panel Drawings Date Code 920508 Installation 6 7 SEL 221F 1 Instruction Manual ...

Page 171: ... ALL INSTRUMENTS MAY BE MOUNTED HORIZONTALLY AS SHOWN ABOVE OR VERTICALLY DWG 1005 104 Figure 6 3 Relay Dimensions Panel Cutout and Drill Plan 6 8 Installation Date Code 930601 SEL 221F 1 Instruction Manual ...

Page 172: ...6 4 Communications and Clock Connections One Unit at One Location Figure 6 5 Communications and Clock Connections Multiple Units at One Location Date Code 920508 Installation SEL 221F 1 Instruction Manual 6 9 ...

Page 173: ...Figure 6 6 SEL Relay Communications Diagram for Connection to the SEL DTA Figure 6 7 External Current and Voltage Connections 6 10 Installation SEL 221F 1 Instruction Manual Date Code 920508 ...

Page 174: ...Figure 6 8 Dc External Connection Diagram Typical Date Code 920508 Installation SEL 221F 1 Instruction Manual 6 11 ...

Page 175: ... VOLTS AMPS AS SEEN ON SCREEN COMPANY NOTATION 1st LINE CHOSEN Y COMPONENT la lb l l lc l Va V Vb V Vc V 2nd LINE CHOSEN X COMPONENT CALCULATED R W O MAGNITUDE 1 ANGLE IN DEGREES ARCTAN Y X VALUE OF Va DEGREES TO SUBTRACT TO OBTAIN Va DEGREES 0 Va DEGREES 0 ANGLE USED TO DRAW PHASOR DIAGRAM R O W 2 USE THE VALUES IN ROWS 1 AND 2 ABOVE TO DRAW PHASOR DIAGRAMS BELOW CURRENTS VOLTAGES ...

Page 176: ...NGS MW MVAR AS SEEN ON SCREEN COMPANY NOTATION 1st LINE CHOSEN Y COMPONENT Ia I Ib Ic I I Va V Vb V Vc V 2nd LINE CHOSEN X COMPONENT CALCULATED MAGNITUDE R O W 1 ANGLE IN DEGREES ARCTAN Y X VALUE OF Va DEGREES TO SUBTRACT TO OBTAIN Va DEGREES 0 Va DEGREES 0 ANGLE USED TO DRAW PHASOR DIAGRAM USE THE VALUES IN ROWS 1 AND 2 ABOVE TO DRAW PHASOR DIAGRAMS BELOW R O W 2 CURRENTS VOLTAGES ...

Page 177: ...rent Element Tests 7 31 Loss Of Potential Test 7 32 Z2DG and Z3DG Timer Tests 7 33 Z2DP Timer Test 7 34 Remote End Just Opened Tests 7 35 Switch Onto Fault Tests 7 36 Recloser Test 7 37 Synchronizing and Polarizing Voltage Element Tests 7 38 Voltage Checking Logic Tests 7 38 Synchronism Checking Logic Tests 7 39 Input Circuits Test 7 40 Serial Ports Test 7 41 IRIG B Time Code Input Test 7 41 Power...

Page 178: ... FIGURES Figure 7 1 Relay Part Number and Hardware Identification Sticker 7 4 Figure 7 2 Communication Interface Setup 7 5 Figure 7 3 METER Test Connections 7 14 Figure 7 4 Example ONEBUS Input Data for Phase Phase and Ground Faults 7 16 Figure 7 5 Example ONEBUS Result Screen for Phase Phase and Ground Faults 7 16 Figure 7 6 Example ONEBUS Input Data for Three Phase Faults 7 17 Figure 7 7 Example...

Page 179: ...t panel LEDs Once target LEDs are reassigned from the default targets the front panel targets are no longer latching This means the targets follow the pickup and dropout condition in much the same manner as an output contact See Section 3 COMMUNICATIONS for more infor mation about the TARGET command By using the target LEDs for testing you need not change the relay settings during testing The rela...

Page 180: ...serts the left most LED illuminates Using LED illumination as an indicator you can measure the element operating characteristics When the TARGET command sets the target LED output to a level other than 0 Relay Targets the front panel target markings are no longer relative to illuminated LEDs and the LEDs do not latch If you place the relay in service with the target level other than Level 0 it aut...

Page 181: ...edure should familiarize you with the relay and ensure that all functions are operational For a complete understanding of the relay capabilities study Functional Specification and Description in Section 2 SPECIFICATIONS command descrip tions in Section 3 COMMUNICATIONS and Section 4 EVENT REPORTING Minimum Equipment Required The following equipment is necessary for initial checkout 1 Terminal with...

Page 182: ...g power to the relay or starting tests Be sure your dc supply is correctly adjusted for the control and logic input requirements Figure 7 1 Relay Part Number and Hardware Identification Sticker Step 3 Purpose Verify the communications interface setup Connect a computer terminal to PORT 2F on the relay front panel The terminal should be configured to 2400 baud eight data bits and no parity The term...

Page 183: ...Setup Step 4 Purpose Establish control power connections Method Connect a frame ground to terminal 46 on the rear panel and connect rated control power to terminals 44 and 45 Polarity is unimportant Relays supplied with 125 or 250 V power supplies may be powered from a 115 Vac wall receptacle for testing In the final installation we recommend that the relay receive control power from the station d...

Page 184: ...mmunications on Access Level 1 Note If you are using a battery simulator be sure the simulator voltage level is stabilized before turning the relay on Step 6 Purpose Establish Access Level 1 communications Method Step 7 Purpose Method Type ACCESS and press ENTER At the prompt enter the Access Level 1 password OTTER and press ENTER The prompt should appear indicating that you have established commu...

Page 185: ...ed with demonstration settings type SHOWSET ENTER to view the settings The terminal should display the following The SET and LOGIC command descriptions in Section 3 COMMUNICA TIONS include a complete explanation of the settings Date Code 930830 Maintenance Testing SEL 221F 1 Instruction Manual 7 7 ...

Page 186: ... dotted A and B current input terminals 29 and 31 respectively 9b Connect both undotted A and B current input terminals 30 32 to the undotted C current input terminal 34 9c Connect the dotted C current input terminal 33 to both the A and B current source returns 9d Set the A phase current source to 2 amperes at the same angle as the A phase voltage Set the B phase current source to 2 amperes at th...

Page 187: ...If you inadvertently switched or rolled a pair of voltage or current connections the MW reading should be incorrect Step 12 Purpose Method Test the fault locator Test the fault locator using the voltages and currents in Table 7 1 These voltages and currents were obtained for various locations and fault types assuming a radial line with a source impedance of 0 75 times the total 100 mile line imped...

Page 188: ...ile positive sequence line impedance see Z1 in the settings Faults at 85 miles are beyond Zone 1 but within the 120 setting of Zone 2 see 22 in the settings Faults at 135 miles are beyond Zones 1 and 2 but within Zone 3 set to 150 see Z3 in the settings Faults listed in Table 7 1 cause certain combinations of output relays to close and front panel LEDs to illuminate Table 7 2 shows the results Ple...

Page 189: ...ound fault at 85 miles should illuminate the G2 target G3 The AG ground fault at 135 miles should illuminate only the G3 target ø1 The Zone 1 BC fault at 75 miles should illuminate the ø1 target ø2 The Zone 2 BC fault at 85 miles should illuminate only the ø2 target ø3 The Zone 3 BC fault at 135 miles should illuminate only the ø3 target Note The target level must be at Level 0 to display the faul...

Page 190: ...described below In general these tests assure that the relay settings match your application rather than checking relay performance For commissioning purposes your company policy may require you to perform the full functional test For maintenance purposes a quick test of selected fault types and zones should suffice For example test a Zone 1 AG fault Zone 2 BC fault and a Zone 3 ABC fault SETTING ...

Page 191: ...ure 4 Use the SHOWSET command to inspect settings Make sure your change was accepted Type SHOWSET and press ENTER 5 Use SET and SHOWSET again to restore the initial values and check the settings 6 Type LOG MTU and press ENTER 7 Change one bit in the MTU logic mask For example remove the Z3T bit from the first row of the Relay Word as shown in the following example Date Code 920508 Maintenance Test...

Page 192: ... shown in Figure 7 3 SINGLE VOLTAGE AND CURRENT TEST SOURCE Figure 7 3 METER Test Connections 3 Apply a voltage of 50 Vac between the paralleled voltage inputs to the neutral point and a current of five amperes through the three inputs The phase angle of the voltage and current source should be set to 0 4 Use the METER command to inspect measured voltages currents and power Voltages VA VB and VC s...

Page 193: ... it is included in the manual as a test aid During mho element tests we recommend disabling the loss of potential LOP logic by setting LOPE N in the setting procedure This prevents an LOP condition from blocking mho distance elements You must enable the LOP feature during LOP testing A Determining Fault Simulation Values Phase Phase and Phase Ground Faults All line impedance entries for the ONEBUS...

Page 194: ...ence impedance for the entire transmission line Separate each value with a comma Line 2 On the second line enter the real and reactive values of the secondary zero sequence impedance for the entire transmission line Line 3 The RF FOR GROUND FAULTS input allows you to introduce ground fault resistance into the line ground fault cases In most instances RF will be zero Line 4 The DIST SOURCE TO BUS i...

Page 195: ...rrent source It is desirable to keep the source impedance ratio as realistic as possible Line 5 The final input is the DIST BUS TO FAULT This is the distance from the relay terminal to the fault location To obtain the voltages and currents for a fault at 80 of the line enter 0 80 for the per unit distance from the bus to fault C Determining Fault Simulation Values Three Phase Faults You can calcul...

Page 196: ...e Determine the pickup of each phase phase distance element for three phase faults at three points on the mho characteristic MTA MTA 45 and MTA 45 Method 1 Program the desired programmable output contact Al A4 to follow the appropriate instantaneous phase distance element using the LOGIC command Select one of the phase distance elements from the first row of the Relay Word as indicated below Z1P Z...

Page 197: ...From this you can see why two current sources are adequate for three phase element testing 3I0 IA IB IC 0 Therefore IC IA IB This has the same effect as performing the following steps a Connect the dotted output of A and B current sources to the dotted IA and IB inputs of the relay Terminals 29 and 31 respectively b Jumper together the undotted IA and IB current inputs of the relay Terminals 30 an...

Page 198: ...ee Phase Voltage and Two Phase Current Source Test Connections for Three Phase Fault Test 3 Determine the voltages and currents required to simulate a fault at the boundary of the desired relay reach using ONEBUS or similar method Table 7 4 shows currents and voltages required to test the example Zone 1 reach at MTA These quantities were calculated using ONEBUS Table 7 4 Zone 1 Three Phase Fault T...

Page 199: ...ondary secondary along the MTA In primary ohms Zone 1 reach primary along the MTA primary Where PTR 2000 and CTR 200 7 Obtain two other convenient test points Consider a square inscribed in a mho circle with one diagonal being the diameter along the MTA The two corners of that square on the other diagonal are reached by increasing the current by a factor of 1 414 at angles of 45 away from the angl...

Page 200: ...element 2 Connect the sources of voltage and current to the relay rear panel terminals see Figure 7 9a or b Note that two current sources are employed in Figure 7 9a while only one current source is used in Figure 7 9b The single current source method yields the same results as the two current source method Single current source method also assures that the phase angle of the two involved currents...

Page 201: ...ctions for Phase Phase Mho Test 3 Determine the voltages and currents required to simulate a phase phase fault at the boundary of the desired relay reach using ONEBUS or similar method Currents and voltages required to test the Zone 1 phase phase element reach of the example settings appear in Table 7 6 Date Code 920508 Maintenance Testing SEL 221F 1 Instruction Manual 7 23 ...

Page 202: ...To calculate the phase phase element reach first calculate the resultant test voltage VBC and current IBC BC Fault VB 44 93 V 138 2 VC 44 93 V 138 2 VBC VB VC 59 90 V 90 IB 4 61 A 170 1 IC 4 61 A 9 9 IBC IB IC 9 22 A 170 1 Zone 1 reach secondary along the MTA secondary In primary ohms Zone 1 reach primary along the MTA primary Where PTR 2000 and CTR 200 7 Find two other convenient test points Cons...

Page 203: ...iate instantaneous ground distance element Select a ground element from the Relay Word as indicated below Z1G Zone 1 Instantaneous Ground Distance Element Z2GT Zone 2 Time Delayed Ground Distance Element Z3 Zone 3 Instantaneous Phase and Ground Distance Element Please note the Z2GT element includes any delay set by the Z2DG timer The following example outlines the test procedure for the Zone 1 gro...

Page 204: ...ble 7 8 Zone 1 Ground Element Test Quantities AG Fault VA VB VC IA IB IC 34 58 74 65 74 53 3 13 0 00 0 00 Volts Amps 0 0 128 9 129 0 80 4 0 0 0 0 Degrees 4 Adjust the test set voltages and currents to the values in Table 7 8 Do not turn on the currents at this point 5 Turn on the voltage sources VA VB and VC 6 Apply current to the relay and ramp the current source magnitudes together until the mon...

Page 205: ...ong the MTA In primary ohms Zone 1 reach primary along the MTA primary Where PTR 2000 and CTR 200 7 Find two other convenient test points Consider a square inscribed in a mho circle with one diagonal being the diameter along the MTA The two corners of that square on the other diagonal are reached by increasing the current by a factor of 1 414 at angles of 45 from the angle obtained using the ONEBU...

Page 206: ...rd row 1 Use the SET command to disable the LOP scheme This prevents test condition voltages from setting the loss of potential condition and defeating the directional sensing ability of the relay Purpose 1 Apply the following voltages to the relay Table 7 10 32Q Test Voltages VA VB VC 30 00 0 00 0 00 0 0 0 0 0 0 Volts Degrees For the voltages shown in Table 7 10 the resulting negative sequence vo...

Page 207: ...plicity this test uses the single voltage and current method The relay declares ground faults in the forward direction when I2 leads V2 90 from the MTA I2 LEADS V2 I2 LAGS V2 I0 LEADS V0 I0 LAGS V0 Figure 7 11 Three Voltage vs One Voltage for Directional Tests 2 Apply IA 3 amperes corresponding to negative sequence currents of one ampere IB and IC are zero for this test 3 Move the phase angle of t...

Page 208: ... time Method 1 Disable all directional functions for this test Set 51NTC and LOPE N 2 Set a programmable output A1 A4 to follow the 51NP time overcurrent pickup element Use the assertion of this output open to close to start an external timer 3 Set another programmable output to follow the timeout of the time overcurrent element timeout via the 51NT bit in the Relay Word Use the assertion of this ...

Page 209: ...TD 1 5 and 10 for each of the four curve indexes PHASE OVERCURRENT ELEMENT TESTS Purpose Verify the pickup thresholds of the 50NG 50P and 50H phase overcurrent elements Method 1 Using the LOGIC command set the desired programmable output A1 A4 to follow the appropriate non directional instantaneous phase overcurrent element Select one of the phase overcurrent elements from the Relay Word as indica...

Page 210: ...d to create SET LOP and CLEAR LOP conditions Table 7 12 Conditions To Test the SET LOP and CLEAR LOP Logic SET LOP VA VB VC IA IB IC 0 00 67 00 67 00 0 00 0 00 0 00 Volts Amps 0 0 120 0 120 0 0 0 0 0 0 0 Degrees CLEAR LOP VA VB VC IA IB IC 67 00 67 00 67 00 0 00 0 00 0 00 Volts Amps 0 0 120 0 120 0 0 0 0 0 0 0 Degrees Note The relay may use LOP detection in a number of different ways Check your LO...

Page 211: ...ees 4 Repeat steps 1 to 3 substituting Z3T for Z2GT in the appropriate programm able output Table 7 14 shows a standard Zone 3 AG fault Apply this 3AG fault for a duration which exceeds the Z3D setting Table 7 14 Standard Zone 3 AG Fault Using Factory Relay Settings 3AG Fault VA VB VC IA I B IC 43 07 72 49 72 39 2 31 0 00 0 00 Volts Amps 0 0 126 7 126 8 80 4 0 0 0 0 Degrees Note If an external tim...

Page 212: ...ay Word into one of the available outputs A1 A4 to start an external timer 2 Program the Z2PT bit into a different programmable output to stop the timer 3 Apply the Zone 2 BC fault shown in Table 7 15 for a duration which exceeds the Z2PT setting Table 7 15 Standard Zone 2 BC Fault Using Factory Relay Settings 2BC Fault VA VB VC IA IB IC 67 00 45 52 45 52 0 00 4 47 4 47 Volts Amps 0 0 137 4 137 4 ...

Page 213: ...G apply balanced three phase current above the 50NG setting Remove current from two phases at the same time leaving one current on The relay should trip when the REJO bit asserts and generate an event report Examine the event report to ensure that the REJO bit asserted for 1 5 cycles approximately 0 5 cycles following dropout of the two phase currents Remove the REJO bit from the MTU logic mask Ne...

Page 214: ... timer 4 Compare the timer value to the 52BT setting 5 To make sure the elements in the MTO logic mask are only enabled when 52BT 1 apply a fault to pick up an element masked into the MTO logic mask but not the MTU mask 6 Table 7 16 contains prefault and fault voltage and current quantities for a Zone 2 AG fault Prefault Table 7 16 Zone 2 AG Fault Quantities VA VB VC IA IB IC 67 00 67 00 67 00 0 0...

Page 215: ...Reclose Cancel 2 Program the MTU Mask for Unconditional Trip with the Z1G bit also 3 Apply a Zone 1 AG fault as shown in Table 7 16 Make certain the 52A input is energized for 79RS cycles prior to applying the fault The TRIP output contact closure should result in the circuit breaker simulator deenergizing the 52A input and removal of current inputs to the relay Table 7 17 1AG Fault Prefault VA VB...

Page 216: ...available output contact logic mask Decrease the applied voltage until the 27P bit asserts causing the output contact to close Note the voltage applied 4 Connect a single voltage source to the relay synch check voltage input VS and VSN Set the 59S bit in an available output contact logic mask Apply voltage to the synch check voltage input below the 59VHI setting Increase the applied voltage until ...

Page 217: ...tting When the 59P bit asserts the external timer should start When the voltage conditions of hot pol dead synch have been valid for VCT time the VSC bit should assert stopping the external timer Verify that the timer reading is equal to the VCT timer setting SYNCHRONISM CHECKING LOGIC TESTS Purpose Method 1 2 3 4 Verify operation of the relay synchronism checking function Using the SHOWSET comman...

Page 218: ...qual to the 25T timer setting Figure 7 12 Voltage Connections When SYNCP A INPUT CIRCUITS TEST Purpose Verify that logic inputs assert when control voltage is applied across the respective terminal pair Method 1 Set target LEDs to display the contact inputs by typing TAR 5 ENTER The front panel LEDs should now follow the contact inputs 2 Apply control voltage to each input and make sure the corres...

Page 219: ... Now move the connector cable to PORT 2R Be sure you can communicate through this port IRIG B TIME CODE INPUT TEST Purpose Verify operation of the IRIG B clock input port Method 1 Connect a source of demodulated IRIG B time code to the relay Auxiliary Port in series with a resistor to monitor the current Adjust the source to obtain an ON current of about 10 mA 2 Execute the IRIG command Make sure ...

Page 220: ...lies using three terminal regulators The following pins are the read points Pin 1 5 Vdc Pin 4 12 Vdc Pin 6 12 Vdc female connector as viewed from panel Figure 7 13 Nine Pin Connector Pin Number Convention 3 Compare the 5 volt readings from the status report and voltmeter The voltage difference should be less than 50 MV and both readings should be within 0 15 volts of five volts The 12 volt supplie...

Page 221: ...nications ports and be sure a communications device is connected to at least one communications port Troubleshooting Table All Front Panel LEDs Dark 1 Power is off 2 Blown fuse 3 Input power not present 4 Self test failure 5 Target command improperly set Note For 1 2 3 and 4 the ALARM relay contacts should be closed System Does Not Respond to Commands 1 Communications device not connected to syste...

Page 222: ...minal improperly connected to system 4 Other port designated AUTO in the relay settings 5 Port timeout interval set to a value other than zero System Does Not Respond to Faults 1 Relay improperly set Review your settings with the SHOWSET command 2 Improper test settings 3 PT or CT input cable wiring error 4 Check self test status with STATUS command 5 Check input voltages and currents with METER c...

Page 223: ...ts 1 Power supply 15 volt output out of tolerance See STATUS command 2 A D converter failure Self Test Failure Offset 1 Offset drift Adjust offsets 2 A D converter drift Self Test Failure ROM Checksum 1 EPROM failure Replace EPROM s Self Test Failure RAM 1 Static RAM IC failure Replace RAM s Self Test Failure A D Converter 1 A D converter failure 2 RAM error not detected by RAM test Date Code 9312...

Page 224: ...he unit to you within a few days Warning This procedure requires that you handle electrostatic discharge sensitive com ponents If your facility is not equipped to work with these components we recommend that you return the relay to SEL for firmware installation Upgrade Instructions 1 If the relay is in service disable its control functions Turn off control power to the relay 2 Remove the relay fro...

Page 225: ...assembly into the relay chassis Using your fingers push the assembly in until the front of the assembly is flush with the front of the relay chassis Reconnect the power supply and transformer secondary cables to the receivers on the underside of the drawout assembly Replace the relay front panel 8 With breaker control disabled turn relay power on and enter your settings Execute the STATUS METER an...

Page 226: ...u may enter fault resistance which is used in the ground fault computations Enter source impedance as a per unit value with a base of the previously entered transmission line data For example if the radial system has a source impedance of about ten percent of the entered line impedance enter 0 1 for the per unit distance from the source to the bus Specify the distance from the bus to the fault as ...

Page 227: ...I AI J BR S RI BI S S1 GOSUB 1000 AR RR AI RI BR O BI SQR 3 GOSUB 1000 635 TR RR TS RI 640 UB 67 0 5 TR 650 VB 67 SQR 3 2 TS 660 UC 67 0 5 TR 670 VC 67 0 5 SQR 3 TS 675 FF B C 680 GOSUB 4041 900 INPUT IMP BUS FAULT OR QUIT I B F Q A 910 IF A I THEN GOT0 50 920 IF A B THEN GOT0 75 930 IF A F THEN GOT0 120 ELSE GOT0 999 999 END 1000 REM MULT SUBROUTINE 1010 REM AR AI BR BI RR RI 1020 RR AR BR AI BI ...

Page 228: ...APPENDICES TABLE OF CONTENTS Parts Placement Diagram Date Code 920508 Table of Contents SEL 221F 1 Instruction Manual i ...

Page 229: ...SEL 200 Series Relay Main Board Troubleshooting Test Points and Jumper Locations ...

Page 230: ... data and set target lights as follows TAR 0 Relay Targets TAR 1 Relay Word l TAR 2 Relay Word 2 TAR 3 Relay Word 3 TAR 4 Internal Elements TAR 5 Contact Inputs TAR 6 Contact Outputs TAR R Returns to TAR 0 and clears Be sure to return to TAR 0 when done so LEDs display fault targets TIME h m s Show or set time TIM 13 32 00 sets clock to 13 32 00 PM This setting is overridden when IRIG B synchroniz...

Page 231: ... data and set target lights as follows TAR 0 Relay Targets TAR 1 Relay Word l TAR 2 Relay Word 2 TAR 3 Relay Word 3 TAR 4 Internal Elements TAR 5 Contact Inputs TAR 6 Contact Outputs TAR R Returns to TAR 0 and clears Be sure to return to TAR 0 when done so LEDs display fault targets TIME h m s Show or set time TIM 13 32 00 sets clock to 13 32 00 PM This setting is overridden when IRIG B synchroniz...

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