HV Protection Relays Setting Calculation Rev-4



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HUBCO P60110-E-PRSC-001HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 HV Protection Relays Setting Calculation Prepared by: AREVA Date: Reviewed by: MAN Diesel & Turbo Date: Approved by: Owner Date: Confirmed by: WAPDA Date: Signature / Stamp Signature / Stamp Signature / Stamp Signature / Stamp HV Protection Relays Setting Calculation 1 of 58 Rev.4 HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 Table of Content: A. Protection Relays Setting on 132kV Transformer Relay Panels for Transformer Bays E01, E03, E06, and E08 1. Transformer Differential Protection Relay Settings-MiCOM P631 2. Transformer Backup Overcurrent Protection Relay Settings-MiCOM P122 3. Transformer CB Failure Protection Relay Settings-MiCOM P821 B. Protection Relays Setting on 132kV Line Relay Panels for Line Bays E07 (132kV NRW2) and E09 (132kV NRW-4). 1. Line Distance Protection Relay Settings-MiCOM P442 2. Line Backup Overcurrent Protection Relay Settings-MiCOM P122 3. Line CB Failure Protection Relay Settings-MiCOM P821 4. Line Synchronism Check Relay Settings-KAVS100 C. Protection Relays Setting on 132kV Line Relay Panel for Line Bay E02 (132kV Badomali Line BDL-1). 1. Line Distance Protection Relay Settings-MiCOM P442 2. Line Backup Overcurrent Protection Relay Settings-MiCOM P122 3. Line CB Failure Protection Relay Settings-MiCOM P821 4. Line Synchronism Check Relay Settings-KAVS100 D. Protection Relays Setting on 132kV Relay Panel For Line Bay E04 (132kV NRW-1) 1. Line Distance Protection Relay Settings-MiCOM P442 2. Line Backup Overcurrent Protection Relay Settings-MiCOM P122 3. Line CB Failure Protection Relay Settings-MiCOM P821 4. Line Synchronism Check Relay Settings-KAVS100 HV Protection Relays Setting Calculation 2 of 58 Rev.4 HUBCO P60110-E-PRSC-001 E. HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 Protection Relays Setting on 132kV Buscoupler Relay Panel (Bay E05) 1. High Impedance BB Diff. Protection Relay Settings-MFAC34 2. Buswire Supervision Relay Settings-MVTP31 3. Buscoupler Overcurrent Protection Settings-MiCOM P122 4. Buscoupler CB Failure Protection Relay Settings-MiCOM P821 5. Line Synchronism Check Relay Settings-KAVS100 F. WAPDA reference letters about relay settings recommendation. 1. Letter No. GM(WPPO) CE-IV/7208 Dated 31-05-2010 2. Letter No. GM(WPPO) CE-IV/13827-29 Dated 06-10-2010 Note: Protection Relay Settings on 15kV System are required to be coordinated with given below 132kV Protection Relay Settings. Comments on Rev-3: 1. Settings are revised after recommended revised settings given by WAPDA in letter Ref# GM(WPPO)/CE-IV/13827-29 for OC &EF relays of Bay E02(Badomali line BDL-1) , E04(Narowal line NRW-1) and Step up Transformer Bays E01,E03,E06 & E08. 2. Settings are revised to correct some typographical mistakes of rev-1, in OC & EF relay settings of Buscoupler Bay. Comments on Rev-4: 1. After meeting with IE of Fichtner GmbH on 25-02-2011, new setting Id>>= 8 x Iref for transformer differential relay MiCOM P631and I>= 1.0 x In with TMS= 0.27 for transformer overcurrent relay MiCOM P122 for all four transformers have been decided. HV Protection Relays Setting Calculation 3 of 58 Rev.4 HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 A. Protection Relays Setting on 132kV Transformer Relay Panels for Transformer Bays E01, E03, E06 and E08. HV Protection Relays Setting Calculation 4 of 58 Rev.4 HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 1. Transformer Differential Protection Relay: Relay Type (Similar For All 132kV Transformer Bays): MiCOM P631 Make: AREVA Location: 132kV Transformer Relay Panels: =E01+R1, E03+R1, E06+R1, E08+R1. Transformer Data (Similar For All 132kV Transformer Bays) Rated Power (ONAN/ONANF): 50/70MVA Rated Voltage: 132/15KV Rated Current (HV): 218.7/306.2A Rated Current (LV): 1924.5/2694.3A Connection: Star (HV), Delta (LV) Vector Group:YNd5 HV/LV Short Circuit Impedance base on 70MVA: 14% CT Ratios For Differential Protection (Similar For All 132kV Transformer Bays) HV 132kV Transformer Feeder CT : 400/1, 5P20 LV 15kV Transformer Feeder CT: 3000/1, 5P20 Relay Settings (Similar For All 132kV Transformer Bays): MiCOM P631 provides a very fast differential protection function. With automatic CT ratio matching and vector group compensation, makes this relay an ideal solution even for the most demanding applications. The individual reference currents for each winding of the transformer are calculated by P631 on the basis of the set reference power and the set primary nominal voltages of the transformer. Iref,a = Sref/( 3.Vnom,a) = 70MVA/( 3 x 132kV) = 306.2 Amps Iref,a= 306.2 Amps Iref,b = Sref/( 3.Vnom,b) = 70MVA/( 3 x 15kV) = 2694.3 Amps Iref,b= 2694.3 Amps Where: Sref: Reference Power Iref,a,b: reference current of winding a, b. Vnom,a,b: nominal voltage of winding a, b. The P631 calculates the matching factors on the basis of the reference currents and the set nominal currents of the system current transformers. kam,a=Inom,a/Iref,a = 400/306.2 = 1.306 kam,a= 1.306 kam,b=Inom,b/Iref,b = 3000/2694.3 = 1.113 kam,b = 1.113 HV Protection Relays Setting Calculation 5 of 58 Rev.4 05) = 0.5 x Iref ( in steps of 0.99958 x 1.b: primary nominal currents of the main current transformers.11075 x Iref LV side current = 2694.05) – (0. Inom.90865 x Iref At lowest tap position with ct multiplier = (340.1863 x Iref Differential current on lowest tap position = (1.95) .3/400) x 1.a.a.3 A Rated HV current at lowest tap position = 340.(0.306 = 0.2167 Available setting: 0.HUBCO P60110-E-PRSC-001 Where: HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 kam.0495 = 0.1 to 2. Differential Setting: 2) 3) 4) 5) 6) 7) 1) Idiff>: Differential initial setting should be set above the steady-state magnetizing current of the transformer.99958 x 0. Differential Current on highest tap position = (0.306 = 1. Rated HV current at highest tap position = 278. Unbalance current checking in regarding with the tap changer position on highest (1) and lowest (17) tap positions.3 A Secondary LV side current with selected ct multiplier = (2694.2/400) x 1.95) = 1.m2 m2 HV Protection Relays Setting Calculation 6 of 58 Rev.90865 x 0.1663-0.8632-1.01) Hence the selected setting Idiff> Idiff>> Idiff>>> m1 IR.3/3000) x 1.2 A Secondary current at highest tap & lowest tap position with selected CT multiplier: At highest tap position with ct multiplier = (278.9496 = 0.b: amplitude matching factor of winding a or b.11075 x 1.99958 x Iref Differential Current on highest and lowest tap position with selected CT Multiplier: Allowing 5% to accommodate ct errors.113 = 0.4 . 58 which is > 1.1-3.52= 3.450= 1. Maximum transformer inrush current = 4 x rated current = 4 x 306. Taking 4 times the rated current for calculation.1kA Since by exclusive case (the energizing only from the system without any transformer with generators).35)= 0. We can verify the setting if { 2-phase min short circuit current )/ Set value} >= 1. At.) Idiff>> HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 This setting is to be set just above the inrush current rms value so that blocking of the triple slope characteristic by second harmonic restraint or by saturation detector is removed. we have I gen-sc = 4350A x 3 =13. 3-phase short circuit value from 3 generators = 132000/ (1.306 = 4 x Iref In order to prevent transformer from false tripping which may be possible if inrush current is higher.482=51. we have 3-phase short circuit value = 0.1kA/ (8xIref) = 3.88kA/(8 x Iref)= 3.1 kA ( contribution from Wapda and generators both) Therefore.88/2.1 – (3 x 0.05kA at 15 kV level.4 . By operation only one transformer two phase short circuit current will be = {(Root3) x (7.732 x 1.5 Hence the selected setting has the necessary sensitivity in most possible cases .450kA=1.482kA Xgen= 132kV/1.58kA Two phase short circuit current will be = {(Root3)/2} x 3.it is in order Id>> = 8 x Iref HV Protection Relays Setting Calculation 7 of 58 Rev.22 x Iref 2.88kA x 4= 3.05 x 15)/132} = 1. For 3 Generators connected to single bus.14 x 132kV x 132kV)/70MVA= 34. 3.88)) = 3.5 + 34. 7.450 kA is recommended by Independent Engineer ( Fichtner GmbH) .88kA With all four trafo.52 kA Three phase min short circuit current at 132kv side = 7.5 ohm Xtrafo=(0. Igen-sc= {(13. Setting of 8 x Iref = 2.848 Ohm X total = 51.58 = 3.732 x 86.88kA Since 3. Normally the transformer Inrush current may go from 4-8 times the rated current.848 = 86.5 but > 1.2 = 1225 Amps Corresponding ct secondary current = (1225/400) x 1.35 Ohm Therefore .2.1kA/2. 132kV side.HUBCO P60110-E-PRSC-001 Idiff> = 0.5 Generator short circuit current is 4350A.26 which is less than 1. 99958)/2 = 0.2167 x Iref Restraining current on highest and lowest tap positions: Restraining current on highest tap position = (0.0551 Therefore: For highest tap position: IR = 0.5 x m1) However the suitability of this setting is verified as below.0551 x Iref & Idiff = 0.90865 + 0. Hence for fast fault clearance.9541 Restarining current on lowest tap position = (1.07 x Iref Idiff>>> should be less than 20. & Idiff = 0.HUBCO P60110-E-PRSC-001 3.4 . Such a fault involves the bus fault level as it is not limited by the winding impedances. overfluxing restraint or saturation detector. which appears as differential current. It is not influenced by restraining current (triple slope characteristics).732/2 = 6148 A Iref for Bus fault = (6148/400) x 1.11075 + 0. This is set greater than the transformer inrush current and below the fault at the transformer terminals. The differential and restraining current variables for each measurement system are calculated from the current variables after amplitude and vector group matching.2: HV Protection Relays Setting Calculation 8 of 58 Rev.1863 x Iref For Lowest tap position: IR = 1.1863 x Iref Differential current on lowest tap position = 0.99958)/2 = 1.22 and m1 = 0.100kA 2-phase minimum fault current at 132kV side = 7100 x 1.) I diff>>> HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 This is a simple instantaneous unrestrained highest differential over current setting. harmonic restraint. (Id/Iref) = m1 x (IR/Iref) + (Idiff>/Iref) x (1-0. The Following equation is used to calculate the differential and restraining current. the slope of which should correspond to the cumulative total error of the participating current transformer sets. Differential current on highest tap position = 0. but also with differential current that can be attributed to the transformation errors of the current transformer sets. so that in this section we must reckon not only with the transformer magnetizing current.306 = 20. Differential current on highest and lowest tap position with selected ct multiplier: As calculated above. Hence the selected setting Idiff>>> = 8 x Iref 4) m1 This is the second section of the tripping characteristic covers the load current range. Id>>> could be set below the current for a fault at the transformer terminals. The curve slope m1 can be set.2167 x Iref Boundary of the operating region is calculated below: With Id> = 0.9541 x Iref.07 x Iref. The second section of the tripping characteristic forms a straight line. The 3-phase minimum fault current at 132kV side = 7. 306 = 6. through fault current on highest tap position = 6.288/2 = 3.1445 = 1.597kA Corresponding ct secondary current = (2597/400) x 1.0.0.2/0.926kA Corresponding ct secondary current = (1926/400) x 1.0551 + 0.4 .0551 x Iref & Idiff = 0.22 x (1.4090 x Iref It is clear from above values that the differential current on relay during full load current on highest and lowest tap positions of the transformer is outside the operating region with selected Id>=0.4090 Therefore: For highest tap position: IR = 0.3888 x Iref For Lowest tap position: IR = 1.144x Iref Therefore 4.HUBCO P60110-E-PRSC-001 For highest tap position: HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 (Id/Iref) = m1 x (IR/Iref) + (Idiff>/Iref) x (1-0.22 x (1.2) = 0.m2 = 4.288 x Iref Max through fault current at lowest tap position = 8.2 Hence the selected setting m1= 0. The selected IR.3888 For lowest tap position: (Id/Iref) = m1 x (IR/Iref) + (Idiff>/Iref) x (1-0.24 to be set based on half the maximum through fault current.2 x 0.9541 + 0. & Idiff = 0.24 x Iref Half the max.479 x Iref Max through fault current (Limited by transformer impedance) at highest tap: Max through fault current = rated current at highest tap / % imp of trf at highest tap = 278.2) = 0.479 x Iref Max through fault current at highest tap position = 6. It is recommended to set half the maximum through fault current.3 x Iref HV Protection Relays Setting Calculation 9 of 58 Rev. Max through fault current (Limited by transformer impedance) at lowest tap: Max through fault current = rated current at lowest tap / % imp of trf at lowest tap = 340.9541 x Iref.5 x 0.5 x 0.2 5) IR.1310 = 2.22 and m1= 0.288 x Iref Half the max.3/0.5 x m1) = 0. through fault current on lowest tap position = 8.479/2 = 4.m2 setting IR.m2 This is the second knee point of the tripping characteristic determines the end of the overcurrent zone in the direction of increasing restraining current in fault free operation.306 = 8.5 x m1) = 0.2 x 1. 113 = 7.2kV/15kV) = 18. & Idiff = 1.917)/2 = 6.5 = 1.288+6.288 x Iref (as calculated above) Max through fault current at highest and lowest tap positions at LV side: LV side through fault current on highest tap position = 1926 x (145.95) .054 x Iref & Idiff = 2.630)/2 = 8.568 kA CT secondary LV through fault current on lowest tap= (20568/3000) x 1.482 x Iref The following equation is used to calculate the boundary of the operating region.054 x Iref Therefore: For highest tap position: IR = 6.482 x Iref Restraining current on highest and lowest tap positions: Restraining current on highest tap position = (6.) m2 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 The third slope m2 characteristics are to accommodate ct errors during heavy through fault conditions.05) – ( 7.5 =1.5 = 2.630 x 0.655 x Iref Differential current on lowest tap position with safety factor 1.29 x1.935 x Iref For Lowest tap position: IR = 8. It is desirable to give a safety factor 1.479 x Iref (as calculated above) Max through fault current at highest tap position = 6.263 = 1.479+7.917 x Iref LV side through fault current on lowest tap position = 2597 x (118. Id/Iref = m2 x IR/Iref + Idiff>/Iref x (1-0.917 x 1.6025 x Iref Restraining current on lowest tap position = (8. There is no specific advantage in setting the slope m2 very closer to the through fault operating conditions.m2/Iref ) x (m1-m2) HV Protection Relays Setting Calculation 10 of 58 Rev.903-7.935 x Iref Differential current on lowest tap position = ( 8.HUBCO P60110-E-PRSC-001 6.5 = 1.05) = 5. Differential current on highest tap position = (6.248 = 1.5 x m1) + (IR.29 x Iref Differential current on highest tap position with safety factor 1.113 = 6.630 x Iref Differential currents on highest and lowest tap positions: Allowing 5% to accommodate CT errors and assuming worst case.288 x 0.4 . Max through fault current at lowest tap position = 8.95) = 8.(6.479 x 1.644 kA CT secondary LV through fault current on highest tap= (18644/3000) x 1.973-7.6025 x Iref.655 x1.8kV/15kV) = 20.5 for the differential current. 22 and m1 = 0.5 x 0.4: For highest tap position: Id/Iref = m2 x IR/Iref + Idiff>/Iref x (1-0. Assignm. Assignm.Fct.Fct.Mode K905: Follower -Oper.Mode K902: Follower Rst on Flt -Oper. Hence the selected m2 setting m2=0.4) = 2.2 and m2 = 0.Mode K901: Follower -Oper.6025 + 0.Fct. Assignm.m2/Iref ) x (m1-m2) = 0.5 x m1) + (IR.2) + 3.4) = 2. Assignm.5 x 6.2-0.m2/Iref ) x (m1-m2) = 0.4 x 8.22 and m1 = 0.2) + 3.2 and m2 = 0. K905: Diff Trip Signal . Output relay assignment and operating mode configuration (OUTP) .m2/Iref ) x (m1-m2) = 0.2-0. Assignm.5 x 0.Fct. K907: Diff Trip Signal . Assignm.5 x 8.22 x (1-0.5 x 0.5.054 + 0.5 Operating region should be away from the differential current region. K902: Diff Trip Signal .76 As the boundary is very close to actual operating differential current at max.Fct.3 x (0.Fct.Fct. K901: Diff Trip Signal .2) + 3. With Id> = 0.3 x (0.179 For lowest tap position: Id/Iref = m2 x IR/Iref + Idiff>/Iref x (1-0.6025 + 0.22 x (1-0.2) + 3.Mode K903: Follower Rst on Flt -Oper.4 .5 to recalculate for suitability of setting as given below. Assignm.22 x (1-0. K904: Diff Trip Signal . K906: Diff Trip Signal . Assignm. K908: Without function -Oper.3 x (0.2-0.5) = 2.Mode K906: Follower HV Protection Relays Setting Calculation 11 of 58 Rev.5: For highest tap position: Id/Iref = m2 x IR/Iref + Idiff>/Iref x (1-0. K903: Blocked/Faulty . the slope is set to 0.22 x (1-0.5 x 0.HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 Boundary of the operating region is calculated below: With Id> = 0.5 x m1) + (IR.5 Configuration: 1.3 x (0.509 For lowest tap position: Id/Iref = m2 x IR/Iref + Idiff>/Iref x (1-0.2-0.5) = 3.Fct.5 x m1) + (IR. and minimum tap positions.4 x 6.235 It is clear from above values that the differential current on relay during maximum through fault current on highest and lowest tap positions of the transformer is outside the operating region with selected m2=0.054 + 0.5 x m1) + (IR.Mode K904: Follower -Oper. therefore we take m2=0.m2/Iref ) x (m1-m2) = 0. end a: 132kV -Vn prim.25 sec -Latching trip Cmd.Assign. end b: 3000A -In Device. Main Common Settings (MAIN) -Vn prim. Setting group selection(GROUP) -Control via USER: Yes -Setting Grp Sel USER: Setting Group SG1 -Hold Timer: Blocked 3.00 In -Minimum I2 Meas’mt: 0. Assig Trip Cmd.HUBCO P60110-E-PRSC-001 -Oper.. Assig Trip Cmd.00 In -Time Const Iph Dem. Settg.. Ends b-a: 5 -Idiff>: 0.1 to 3: Differential Trip Signal -Fct. Block USER: No -Fct.Mode K908: Follower 2..00 In -Minimum IN Meas’mt: 0. end b: 15kV -Hold Time Dyn. end a: 400A -In CT. b: Standard -Minimum Iph Meas’mt: 0. end a: 1A -In Device.4: Manual Trip Signal -tDWELL trip Cmd..00 In -Minimum IY Meas’mt: 0.Block1 to 4: Disabled -Trip Cmd.0Iref (Revised setting as per recommendation of Independent Engineer of Fichtner GmbH) -Idiff>>>: 8. prim. Main Global Settings(MAIN) -Protection Enabled: Yes -User Test Mode: No -Frequency fn: 50Hz -Phase Rotation: A-B-C -In CT.: 15 min -Fct. : Blocked 4) Differential Protection Common Settings (DIFF) -General Enable User: Yes -Rated Ref Power Sref: 70MVA -Minimum Id Meas’mt: 0. Enabling differential protection (DIFF) -Differential PR (87): Enabled Function Settings: HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 1. 1 to 4: No -Fct Assign Fault: Disabled 2.4 .000Iref 5) Setting Group SG1 -Enable SG1: Yes -Vec. a: Standard -CT Orientation Iph.000 Iref -Minimum IR Meas’mt: 0.00 In -Minimum I1 Meas’mt: 0.22 Iref .Mode K907: Follower -Oper. Gr.Idiff>>: 8. prim. end b: 1A -CT Orientation Iph.0 Iref HV Protection Relays Setting Calculation 12 of 58 Rev. 1 to 4: 0. .HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 -m1: 0.trip sig: 0.00s -Hyst.2 -m2: 0. m2: 4.4 . Effective: No HV Protection Relays Setting Calculation 13 of 58 Rev.5 -IR.del. Mode Inrush: Not phase-Selective nd -Inrush 2 Harmon: 20% -I0 filt a Enab: Yes -I0 filt b Enab: No -O/Flux Blk Enab: No -O/Flux 5th Harmon :20% -Op.3 Iref -Op. 187kA at 132kV side. The 132kV-OC protection is set to operate with a delay of about 1.14 / (2187/120) -1] =0.187kA at 132kv side.4 .1sec (950ms+150ms) on the maximum through fault current of 2. Required Instantaneous setting I>>= Ie>>=1.4 = 2.2A.14 / (2187/400) -1] =0. The time multiplier setting can be calculated from the formula: Tms =Required trip time ‘t’/ [0.02 =1. As recommended by independent engineer of Fichner GmbH.88 kA < 6.47 The instantaneous protection is set to 120% of the max 132kV through fault current.624 kA.1 sec ( 950ms+150ms) on the maximum through fault current of 2. possible overload of transformer) is selected. E06+R1. The 132kV earth fault protection at the transformer neutral is set to operate with a delay of about 1. this stage of overcurrent protection is selective with all line protections. HV Protection Relays Setting Calculation 14 of 58 Rev.02 -1] 0.1 / [0.02 -1] 0. Make: Areva Location: 132kV Transformer Relay Panels: =E01+R1.14 / (I/Is)0.1/ [0. Normal inverse curve is selected.HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 2.2 x 306. Required earth fault setting Ie>= 20% of 306.14 / (I/Is)0. 5P20 Relay Settings( Similar For All 132kV Transformer Bays): MiCOM P122 serves as backup protection for 132kV side transformer winding. Required phase overcurrent setting I>=1. setting of 400 A (taking into account the max.2= 0. The O/C Pickup setting is usually 115% of the maximum overload acceptable. E03+R1. Since the max. Transformer Backup Overcurrent Protection Settings: Relay Type (Similar For All 132kV Transformer Bays): MiCOM P122.56 x 0.2 = 352A This is slightly above the maximum current at end tap position of 340.15 x 306.2= 61A Recommended setting for Ie>= 120A The time multiplier setting can be calculated from the formula: Tms =Required trip time ‘t’/ [0.2A.27 The 132kV earth fault stage is set to 20% of the rated transformer current of 306. CT Ratio For Backup O/C Protection (Similar For All 132kV Transformer Bays): HV 132kV Transformer Feeder CT : 400/1. possible contribution from all generators connected to this transformer by fault at the 132 kV side is I gen sum = 0. E08+R1.02 =1.2x2187= 2624A. 4 .3 x In (Revised setting as per WAPDA Lettter GM(WPPO)/CE-IV/13827-29 Dated 06Delay Type=IDMT Curve = Standard Inverse Time Multiplier= 0.1 sec stabilizes the I>> stage against any kind of transient phenomena.HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 The time delay of 0. [50/51] Phase OC Setting: I> = YES I> = 400/400= 1.56xIn Delay Type= DMT Curve: DT Time Delay: 0.47 (Revised setting as per WAPDA Lettter GM(WPPO)/CE-IV/13827-29 Dated 06- 10-2010) t Reset=60 ms Ie>>=Yes Ie>> =2624/400= 6.1 sec I>>>= Not Enable [50N/51N] E/Gnd OC Setting: le >=YES le >=120/400=0.1 sec Ie>>>= Not Enable 10-2010) HV Protection Relays Setting Calculation 15 of 58 Rev. Definite time curve is selected.0 x In (Revised setting as per recommendation of Independent Engineer of Fichtner GmbH) Delay Type = IDMT Curve = Standard Inverse Time Multiplier = 0.27 (Revised time multiplier setting due to chane in I> setting above) t Reset=60 ms I>>=Yes I>> =2624/400= 6.56xIn Delay Type= DMT Curve: DT Time Delay: 0. CT Ratio For CB Failure Protection (Similar For All 132kV Transformer Bays): HV 132kV Transformer Feeder CT : 400/1. E08+R1. CB FAIL EARTH:YES Description: Enable/Disable the Circuit Breaker Failure protection on earth. 5P20 Relay Settings (Similar For All 132kV Transformer Bays): CB FAIL FUNCT : YES Description: Enable/Disable the Circuit Breaker Failure protection.HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 3. I> BF: 0. Delay Stage2: 280 ms Description: Set the general back-trip delay. CB FAIL PHASE: YES Description: Enable/Disable the Circuit Breaker Failure protection by phase.4 .15 x In Description: Select the earth current threshold. Make: Areva Location: 132kV Transformer Relay Panels: =E01+R1. Ie> BF: 0. E03+R1. HV Protection Relays Setting Calculation 16 of 58 Rev. External Reset: YES Description: Reset configuration of tBF1 after drop off of the external tripping. E06+R1. Delay Stage1: 150 ms Description: Set the retrip delay.5 x In Description: Select the phase current threshold. Transformer Circuit Breaker Failure Protection Settings: Relay Type (Similar For All 132kV Transformer Bays): MiCOM P821. HV Protection Relays Setting Calculation 17 of 58 Rev.4 .HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 B. Protection Relays Setting on 132kV Line Relay Panels for Line Bays E07 (132kV NRW-2) and E09 (132kV NRW-4). 2461+j1.3246+j1.422Km. Line Distance Protection Settings: Relay Type (Similar For Both Line Bays): MiCOM P442. Make: Areva Location: 132kV Line Relay Panels: =E07+R1 and =E09+R1 System and Line Data (Similar For Both Line Bays): Transmission Line: 132kV NRW-2 and NRW-4 System Voltage: 132KV.4004 Ohms/Km R0+jX0= 0. on Rail conductor Line Impedance: Positive Sequence ZL1 = (0. -Zone 3: Impedance of protected line + 120% of impedance of adjacent longest T/L and trip delay time 700ms delay. -Zone 2: Impedance of protected line + 50% of impedance of adjacent shortest T/L and trip delay time 350ms delay.422 KM.3921 Ohms/Km R0+jX0= 0. Min KA=7. Impedance: Zero Seq. Impedance: Zero Seq. Lynx conductor (132kV Narowal to 132kV Shakargarh) T/L Conductor data at ambient temperature: Lynx conductor: Positive Seq. Impedance: R1+jX1= 0.228 Ohms/Km Distance Zone Reach Calculation (Similar For Both Line Bays): The distance zone reach is determined according to the following principles: -Zone 1: 85% of impedance of protected line and trips independently with 0s delay.1583+j0.06+j0.1 At Narowal Grid Station: Max KA= 8.9.1248) Ohm/Km Rated current carrying capacity of each line = 884A Opposite End Grid Station Shortest and Longest Lines Data: Shortest Line: 10.06+j0.7.6 Line Length: 10. Min KA= 6.1248 Ohms/Km R1+jX1= 0.732) Fault Levels: At HUBCO Narowal: Max KA= 9. Impedance: Rail conductor: Positive Seq. HV Protection Relays Setting Calculation 18 of 58 Rev. 50Hz CT Ratio: 1200/1 VT Ratio: (132KV/1.3921) Ohm/Km Zero Sequence ZL0 = (0. Rail conductor (132kV HUBCO to 132kV Narowal) Longest Line: 36Km.4 .HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 1.732)/(110V/1.2461+j1. 0864) + 0. is assumed 5m.5º (Set for kZ1. The maximum power flow is calculated from the ampacity of the conductor of 884A at nominal 1. Z2 = (0.3º 4. kZ3) 6. <kZ0 = <((ZL0-ZL1)/ 3.9379+j6.514<81. thus the resistive reach (RPh) is set independent of the impedance reach along the protected line.5º Therefore: kZ0 Res.4 .06+j0.85 x (0. RPh must be set greater than the maximum fault arc resistance for a phase-phase fault.422 x (0.5 {10.2 {36 x (0.6253+j4. Z1 = 0.3921) = 0.65<70.75º/(3 x 4. Residual Compensation for Earth Fault Elements: Residual Compensation. is taken 7.6 RPh >=Ra Where: Ra = Arc resistance L = Maximum phase conductor separation.06+j0.HUBCO P60110-E-PRSC-001 1.422 x (0.3837 Z3 = 22. If = Minimum expected phase-phase fault current.4638+j21.732)}=1 Line impedance ZL1= 10. Line Impedance: HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 Ratio of secondary to primary impedance = (1200/1)/{(132000/1.58 = 0.061 kZ0 Angle = <-5. Resistive Reach -Phase Fault Elements The P442 relay have quadrilateral distance elements. kZ3) (Set for kZ1.756<75. The minimum load impedance can be calculated on the basis of the maximum permitted power flow over the protected line. calculated from van Warrington formula as follows: Ra = (28710 x L) / If = (28710 x 5) / (7100) = 0.1296 Z2 = 6.3º 2.06+j0.1248) .1583+j0.6253+j4.3921)} = 0.5315+j3.4004)} = 7. Zone 2 Reach : Zone 2 is set to 100% of protected line impedance + 50% impedance of the adjacent shortest transmission line. In general.75º kZ0 = 0.6253+j4.ZL1 Set as ratio kZ0 Angle.4734 Z1 = 3. Comp = 0.0864 ZL1= 4. Zone 3 Reach : Backup Zone 3 is set to 100% of the protected line impedance + 120% impedance of the adjacent longest transmission line.ZL1 Set as degrees ZL0-ZL1 = (0.134<81.0864) + 1.3º) = 0.4 1.2461+j1.134<81.6253+j4. kZ2.061<-5.(0.732)/(110/1.4 HV Protection Relays Setting Calculation 19 of 58 Rev.3921) = 0.7º 5. kZ2. |kZ0| = (ZL0-ZL1)/ 3. Z3 = (0.1kA.0864) = 0.3º 3.756<75. Zone 1 Reach : Zone 1 is set to 85% of the protected line impedance.2<81. Therefore: Earth (RG) Minimum 40 Maximum 44 Zone-1 30 Zone-2 35 Zone-3 40 Relay Settings (Similar For Both Line Bays): Functions Configuration: -Setting Group: Select via menu -Active Settings: Group 1 -Setting Group 1: Enabled -Setting Group 2: Disabled -Setting Group 3: Disabled -Setting Group 4: Disabled -Distance: Enabled -Power Swing: Enabled -Back-up I>: Disabled -Neg.This allows max phase resistive reach = 0.8 x 132kV)²/202MVA = 55 Typically. -Supervision: Enabled -System Checks: Enabled -Internal A/R: Enabled -Setting values: Secondary HV Protection Relays Setting Calculation 20 of 58 Rev. Resistive Reach Calculation-Earth Fault Elements: Typically. that the maximum power flow is transferred under worst condition at a minimum system voltage of 80%.A typical resistive reach coverage would be 40 on the primary side. Earth fault distance zones would avoid the minimum load impedance by a margin of >= 20%. for best zone reach accuracy. phase fault distance zones would avoid the minimum load impedance by a margin of >= 40%.4 . Therefore the minimum load impedance is ZLoad(min) = (0.This allows max phase resistive reach = 0. Sequence O/C: Disabled -Broken Conductor: Disabled (This setting is disabled similar to settings of Line Bay E02 and E04 which was disabled as per wapda advise during commissioning at site) -Earth Fault O/C: Disabled -Aided DEF: Disabled -Volt Protection: Disabled -CB Fail & I<: Disabled. the resistive reach of each zone would not normally be set greater than 10 times the corresponding zone reach.8 x 55 = 44 Fault resistance would comprise arc resistance and tower footing resistance. In addition. the resistive reach of any zone of the relay would not normally be greater than 10 times the corresponding earth loop reach.6 Maximum 33 Zone-1 15 Zone-2 20 Zone-3 30 8. It is assumed. which is 202MVA.6 x 55 =33 A setting between the calculated minimum and maximum should be applied for all zones. Therefore: Phase (RPh) Minimum 0. For best zone reach accuracy.HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 system voltage of 132kV. 061 -kZ2: Angle: -5. -Trip Mode: Force 3 poles HV Protection Relays Setting Calculation 21 of 58 Rev.061 -kZ3/4 Angle: -5.061 -kZ1 Angle: -5.42 km -Line Impedance: 4.4 .0s -kZ2 Res Comp: 0.5º -Z2: 6.HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 CT and VT Ratios: -Main VT Primary: 132kV -Main VT Secondary: 110V -C/S VT Primary: 132kV -C/S VT Secondary: 110V -Phase CT Primary: 1200A -Phase CT Secondary: 1A -MComp CT Primary: 1200A -MComp CT Secondary: 1A -C/S Input: A-B -Main VT Location: Line -CT Polarity: Standard or Inverse (To be set at site) CB Control: -CB Control by: Disabled -A/R Single Pole: Disabled -A/R Three Pole: Enabled OPTO Configuration: -Global Nominal Voltage: 110/125V -Opto Filter Cntl: Select All Distance Element: Line Setting: -Line Length: 10.3º Zone Setting: -Zone Status: 01010 -kZ1 Res Comp: 0.65 -R3G-R4G: 40 -R3Ph-R4Ph: 30 -tZ3:700ms Fault Locator: -kZm Mutual Comp: 0 -KZm Angle:0º Distance Schemes: -Program Mode: Standard Scheme -Standard Mode: PUP Z2 -Fault Type: Both Enabled.5º -Z1: 3.134 -Line Angle: 81.514 -R1G:30 -R1Ph:15 -tZ1:0.2 -R2G: 35 -R2Ph: 20 -tZ2:350ms -kZ3/4 Res Comp: 0.5º -Z3: 22. 5sec -Reclaim Time: 180 sec -Close Pulse Time: 0.2 (N/A) -I2/I1 Time Delay: 60 s (N/A) -I2/I1 Trip: Enabled (N/A) Supervision: -VTS Time Delay: 5sec -VTS I2 & I0 Inhibit: 0.0 x In (A) -Unblocking delay: 30 sec -Blocking zones: Select all Broken Conductor: -Broken Conductor: Disabled (This setting is disabled similar to settings of Line Bay E02 and E04 which was disabled as per wapda advise during commissioning at site) -I2/I1: 0.1sec -A/R Inhibit Wind: 5 sec -C/S 3P Rcl DT1: Enabled -Block A/R: Select all HV Protection Relays Setting Calculation 22 of 58 Rev.): 40% -I2> status: Enabled -I2> (% Imax.4 .HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 -tReversal Guard: 20.2 sec Autoreclose: -3P Trip Mode:3/3 -3P Dead Time1: 0.0s -Z1Ext Fail: Disabled -WI Mode Status: Disabled -LoL Mode Status: Disabled Power Swing: -Delta R: 6 -Delta X: 6 -IN> status: Enabled -IN> (% Imax.): 30% -ImaxLine> status: Enabled -ImaxLine>: 4.05 x In -Detect 3Pole: Enabled -Threshold 3Pole: 30V -Delta I>: 0.05Hz -Diff Phase: 20º -Bus-Line Delay: 0.1 x In -CTS Status: Disabled -CVTS Status: Disabled Systemchecks: -Check Scheme for A/R: Select all -Check Scheme for ManCB: None -V<Dead Line: 13V -V>Live Line: 32V -V<Dead Bus: 13V -V>Live Bus: 32V -Diff Voltage: 5V -Diff Frequency: 0.0ms -Unblocking Logic: None -SOTF/TOR Mode: SOTF/TOR all zones -SOTF Delay: 110. For definite time o/c.e 100ms is added to backup o/c time to coordinate with zone-3 operating time of 700ms).4 .e.3 x In = 1560A (primary) Recommended earth fault setting Ie>= 0.8s t Reset=60 ms I>> =Not Enable I>>>= Not Enable [50N/51N] E/Gnd OC Setting: le >=YES le >=120/1200=0. the proposed setting is 800msec.8s t Reset=60 ms Ie>> =Not Enable Ie>>>= Not Enable HV Protection Relays Setting Calculation 23 of 58 Rev. earth fault setting as 120A for all other line bays and transformer bays.3 x In Delay Type = DMT Curve = DT Time Delay= 0. therefore recommended setting for earth fault is 120A. (i. 700ms) of distance protection relay. Line Backup Overcurrent Protection Settings: Relay Type (Similar For Both Line Bays): MiCOM P122.07 x In = 84A (primary) (Note: WAPDA again revised in letter ref# GM(WPPO)/CE-IV/13827-29 .1 x In ( Revised as per Wapda recommendations for other line and trafo bays letter ref# GM(WPPO)/CE-IV/13827-29) Delay Type=DMT Curve = DT Time Delay= 0. [50/51] Phase OC Setting: I> = YES I> = 1560/1200= 1.) Overcurrent operation time should be greater than zone-3 operation time (i. Make: Areva Location: 132kV Line Relay Panels: =E07+R1 and =E09+R1 CT Ratio For Backup O/C Protection (Similar For Both Line Bays): 1200/1 Relay Settings (Similar For Both Line Bays): The time delayed overcurrent protection relay MiCOM P122 serves as backup protection and is delayed against the distance zone timers. Recommended phase overcurrent setting I>= 1.HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 2. Delay Stage2: 280 ms Description: Set the general back-trip delay. Delay Stage1: 150 ms Description: Set the retrip delay.HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 3. I> BF: 0. Make: Areva Location: 132kV Line Relay Panels: =E07+R1 and E09+R1 CT Ratio For CB Failure Protection (Similar For Both Line Bays): 1200/1 Relay Settings (Similar For Both Line Bays): CB FAIL FUNCT : YES Description: Enable/Disable the Circuit Breaker Failure protection. CB FAIL EARTH:YES Description: Enable/Disable the Circuit Breaker Failure protection on earth. Ie> BF: 0. Line Circuit Breaker Failure Protection Settings: Relay Type (Similar For Both Line Bays): MiCOM P821.5 x In Description: Select the phase current threshold. External Reset: YES Description: Reset configuration of tBF1 after drop off of the external tripping. CB FAIL PHASE: YES Description: Enable/Disable the Circuit Breaker Failure protection by phase. HV Protection Relays Setting Calculation 24 of 58 Rev.15 x In Description: Select the earth current threshold.4 . Make: Areva Location: 132kV Line Relay Panel: =E07+R1. Line Synchronism Check Relay Settings: Relay Type (Similar For Both Line Bays): KAVS100. Voltage= 5V HV Protection Relays Setting Calculation 25 of 58 Rev. Ratio= 132000: 110 -CSS Phase Angle=20° -CSS Slip Freq.B/L Live= 32V -CSS V.732)/(110V/1. Timer=1 Second -CSS Split Angle=170° -CSS Split Timer=1 Second -CSS System Angle=20° -CSS System Slip Freq.732) Bus VT Ratio: (132kV/1.= 50mHz -CSS System Timer=1 Second -CSS V. 50Hz Line VT Ratio: (132kV/1.4 .732) Relay Settings (Similar For Both Line Bays): Check Synchronism Settings (CSS) -CSS V.HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 4.T.732)/(110V/1.B/L Dead= 13V -CSS Under voltage= 80V -CSS Diff. and =E09+R1 System Data (Similar For Both Line Bays): System Voltage: 132kV.= 50mHz -CSS Synch. 4 .HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 C. HV Protection Relays Setting Calculation 26 of 58 Rev. Protection Relays Setting on 132kV Line Relay Panel for Line Bay E02 (132kV Badomali Line BDL-1). 3 Line Length: 11.732)/(110V/1.228)Ohm/Km Rated current carrying capacity of the line = 488A Opposite End Grid Station Shortest and Longest Lines Data: Shortest Line: 21Km. Min kA=4.1583+j0.7 KM on Lynx conductor Line Impedance: Positive Sequence ZL1 = (0. HV Protection Relays Setting Calculation 27 of 58 Rev.228 Ohms/Km Distance Zone Reach Calculation : The distance zone reach is determined according to the following principles: -Zone 1: 85% of impedance of protected line and trips independently with 0s delay.1 Fault Levels at Badomali Grid Stn: Max kA=7. 50Hz CT Ratio: 1200/1 VT Ratio: (132kV/1.1248 Ohms/Km R1+jX1= 0.4004 Ohms/Km R0+jX0= 0.7. Min kA=7. Impedance: Zero Seq.2461+j1.732) Fault Levels at HUBCO Narowal: Max kA= 9. -Zone 3: Impedance of protected line + 120% of impedance of adjacent longest T/L and trip delay time 700ms delay.3246+j1.3. Line Distance Protection Settings: Relay Type: MiCOM P442. Lynx conductor (132kV Badho Mali to 132kV Narang) Longest Line: 21Km.HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 1. Make: AREVA Location: 132kV Relay Panel: = E02+R1 System Data: Transmission Line: 132kV Badomali BDL-1 System Voltage: 132kV. -Zone 2: Impedance of protected line + 50% of impedance of adjacent shortest T/L and trip delay time 350ms delay. Impedance: Rail conductor: Positive Seq.4 .3246+j1.06+j0. Lynx conductor (132kV Badho Mali to 132kV Narang) T/L Conductor data at ambient temperature: Lynx conductor: Positive Seq.4004)Ohm/Km Zero Sequence ZL0 = (0. Impedance: Zero Seq. Impedance: R1+jX1= 0.3921 Ohms/Km R0+jX0= 0.1583+j0. Line Impedance: HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 Ratio of secondary to primary impedance = (1200/1)/{(132000/1.282<68.4004)= 1.7747 Z3 = 15.638º)/(3 x 5.8521+j4.6847)+0. kZ3) 6.8521+j4. If = Minimum expected phase-phase fault current.(0.6 RPh >=Ra Where: Ra = Arc resistance L = Maximum phase conductor separation. Resistive Reach -Phase Fault Elements The P442 relay have quadrilateral distance elements.HUBCO P60110-E-PRSC-001 1. Zone 3 Reach : Backup Zone 3 is set to 100% of the protected line impedance + 120% impedance of the adjacent longest transmission line. RPh must be set greater than the maximum fault arc resistance for a phase-phase fault. |kZ0| = (ZL0-ZL1)/ 3.3246+j1.037<68.4 1.8521+j4.8889 Z2 = 9.4º 4.5{21(0.558<68.ZL1 Set as degrees ZL0-ZL1 = (0.6847) =1. is taken 7. Residual Compensation for Earth Fault Elements: Residual Compensation. Z2 = (1.228) .43º) = 0.6847)+1.2º Therefore: kZ0 Res.056<10. Z3 = (1.4004)}=5. is assumed 5m.4004)} =3. The minimum load impedance can be calculated on the basis of the maximum permitted power flow over the protected line.9819 Z1 = 4.1583+j0. In general.2{21(0. thus the resistive reach (RPh) is set independent of the impedance reach along the protected line.732)}=1 Line impedance ZL1= 11.4004)= 0. calculated from van Warrington formula as follows: Ra = (28710 x L) / If = (28710 x 5) / (7100) = 0.5743+j3.8521+j4.1583+j0.5142+j8.6847 ZL1= 5. Zone 1 Reach : Zone 1 is set to 85% of the protected line impedance.4º 5.1kA.1583+j0.7 x (0.85(1.056 kZ0 Angle = <10.2º (Set for kZ1.4º 3. Z1 = 0.887<68.844<78. kZ3) (Set for kZ1.1583+j0. Comp = 0.844<78.4 .732)/(110/1.8412+j14.638º kZ0 = (0. <kZ0 = <((ZL0-ZL1)/ 3.ZL1 Set as ratio kZ0 Angle. kZ2.58 = 0.4 HV Protection Relays Setting Calculation 28 of 58 Rev.4º 2.037<68. kZ2. Zone 2 Reach : Zone 2 is set to 100% of protected line impedance + 50% impedance of the adjacent shortest transmission line. The maximum power flow is calculated from the ampacity of the conductor of 488A at nominal 1. for best zone reach accuracy. Therefore: Phase (RPh) Minimum 0. which is 111. Resistive Reach Calculation-Earth Fault Elements: Typically.8 x 100 = 80 Fault resistance would comprise arc resistance and tower footing resistance. -Supervision: Enabled -System Checks: Enabled -Internal A/R: Enabled -Setting values: Secondary Minimum 40 Maximum 80 Zone-1 30 Zone-2 40 Zone-3 60 HV Protection Relays Setting Calculation 29 of 58 Rev. Therefore the minimum load impedance is ZLoad(min)= (0.6 Maximum 60 Zone-1 20 Zone-2 30 Zone-3 45 8. It is assumed. In addition. Earth fault distance zones would avoid the minimum load impedance by a margin of >= 20%.6 x 100 =60 A setting between the calculated minimum and maximum should be applied for all zones.8 x 132kV)²/111. Sequence O/C: Disabled -Broken Conductor: Disabled (This setting is disabled as per wapda advise during commissioning at site ) -Earth Fault O/C: Disabled -Aided DEF: Disabled -Volt Protection: Disabled -CB Fail & I<: Disabled.57 MVA.This allows max phase resistive reach = 0. phase fault distance zones would avoid the minimum load impedance by a margin of >= 40%.A typical resistive reach coverage would be 40 on the primary side.57MVA=100 Typically. Therefore: Earth (RG) Relay Settings: Functions Configuration: -Setting Group: Select via menu -Active Settings: Group 1 -Setting Group 1: Enabled -Setting Group 2: Disabled -Setting Group 3: Disabled -Setting Group 4: Disabled -Distance: Enabled -Power Swing: Enabled -Back-up I>: Disabled -Neg. that the maximum power flow is transferred under worst condition at a minimum system voltage of 80%. For best zone reach accuracy.4 . the resistive reach of any zone of the relay would not normally be greater than 10 times the corresponding earth loop reach. the resistive reach of each zone would not normally be set greater than 10 times the corresponding zone reach.HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 system voltage of 132kV.This allows max phase resistive reach = 0. 056 -kZ1 Angle: 10. -Trip Mode: Force 3 poles HV Protection Relays Setting Calculation 30 of 58 Rev.282 -R1G:30 -R1Ph:20 -tZ1:0.HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 CT and VT Ratios: -Main VT Primary: 132kV -Main VT Secondary: 110V -C/S VT Primary: 132kV -C/S VT Secondary: 110V -Phase CT Primary: 1200A -Phase CT Secondary: 1A -MComp CT Primary: 1200A -MComp CT Secondary: 1A -C/S Input: A-B -Main VT Location: Line -CT Polarity: Standard or Inverse (To be set at site) CB Control: -CB Control by: Disabled -A/R Single Pole: Disabled -A/R Three Pole: Enabled OPTO Configuration: -Global Nominal Voltage: 110/125V -Opto Filter Cntl: Select All Distance Element: Line Setting: -Line Length: 11.2º -Z2: 9.4º Zone Setting: -Zone Status: 01010 -kZ1 Res Comp: 0.056 -kZ2: Angle: 10.0s -kZ2 Res Comp: 0.4 .056 -kZ3/4 Angle: 10.2º -Z1: 4.037 -Line Angle: 68.558 -R2G: 40 -R2Ph: 30 -tZ2:350ms -kZ3/4 Res Comp: 0.2º -Z3: 15.7 km -Line Impedance: 5.89 -R3G-R4G: 60 -R3Ph-R4Ph: 45 -tZ3:700ms Fault Locator: -kZm Mutual Comp: 0 -KZm Angle:0º Distance Schemes: -Program Mode: Standard Scheme -Standard Mode: PUP Z2 -Fault Type: Both Enabled. 1 x In -CTS Status: Disabled -CVTS Status: Disabled Systemchecks: -Check Scheme for A/R: Select all -Check Scheme for ManCB: None -V<Dead Line: 13V -V>Live Line: 32V -V<Dead Bus: 13V -V>Live Bus: 32V -Diff Voltage: 5V -Diff Frequency: 0.HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 -tReversal Guard: 20.4 .5sec -Reclaim Time: 180 sec -Close Pulse Time: 0.0ms -Unblocking Logic: None -SOTF/TOR Mode: SOTF/TOR all zones -SOTF Delay: 110.2 (N/A) -I2/I1 Time Delay: 60 s (N/A) -I2/I1 Trip: Enabled (N/A) Supervision: -VTS Time Delay: 5sec -VTS I2 & I0 Inhibit: 0.): 40% -I2> status: Enabled -I2> (% Imax.1sec -A/R Inhibit Wind: 5 sec -C/S 3P Rcl DT1: Enabled -Block A/R: Select all HV Protection Relays Setting Calculation 31 of 58 Rev.): 30% -ImaxLine> status: Enabled -ImaxLine>: 4x In (A) -Unblocking delay: 30 sec -Blocking zones: Select all Broken Conductor: -Broken Conductor: Disabled (This setting is disabled as per wapda advise during commissioning at site ) -I2/I1: 0.0s -Z1Ext Fail: Disabled -WI Mode Status: Disabled -LoL Mode Status: Disabled Power Swing: -Delta R: 9 -Delta X: 9 -IN> status: Enabled -IN> (% Imax.2 sec Autoreclose: -3P Trip Mode:3/3 -3P Dead Time1: 0.05Hz -Diff Phase: 20º -Bus-Line Delay: 0.05 x In -Detect 3Pole: Enabled -Threshold 3Pole: 30V -Delta I>: 0. [50/51] Phase OC Setting: I> = YES I> = 960/1200= 0.8s t Reset=60 ms Ie>> =Not Enable Ie>>>= Not Enable 10-2010) 10-2010) HV Protection Relays Setting Calculation 32 of 58 Rev.e 100ms is added to backup o/c time to coordinate with zone-3 operating time of 700ms).4 .8 x In = 960A Recommended earth fault setting Ie>= 0.8s t Reset=60 ms I>> =Not Enable I>>>= Not Enable [50N/51N] E/Gnd OC Setting: le >=YES le >=120/1200=0. Recommended phase overcurrent setting I>= 0.8 x In (Revised setting as per WAPDA Lettter GM(WPPO)/CE-IV/13827-29 Dated 06Delay Type = DMT Curve = DT Time Delay= 0.e. the proposed setting is 800msec. 700ms) of distance protection relay. Make: Areva Location: 132kV Line Relay Panel: = E02+R1 CT Ratio For Backup O/C Protection: 1200/1 Relay Settings: The time delayed overcurrent protection relay MiCOM P122 serves as backup protection and is delayed against the distance zone timers.1 x In = 120 A Overcurrent operation time should be greater than zone-3 operation time (i. (i. For definite time o/c. Line Backup Overcurrent Protection Settings: Relay Type: MiCOM P122.HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 2.1 x In (Revised setting as per WAPDA Lettter GM(WPPO)/CE-IV/13827-29 Dated 06Delay Type=DMT Curve = DT Time Delay= 0. Delay Stage2: 280 ms Description: Set the general back-trip delay. External Reset: YES Description: Reset configuration of tBF1 after drop off of the external tripping. Ie> BF: 0.15 x In Description: Select the earth current threshold. CB FAIL EARTH:YES Description: Enable/Disable the Circuit Breaker Failure protection on earth. Make: Areva Location: 132kV Line Relay Panel: = E02+R1 CT Ratio: 1200/1 Relay Settings: CB FAIL FUNCT : YES Description: Enable/Disable the Circuit Breaker Failure protection.HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 3. Delay Stage1: 150 ms Description: Set the retrip delay. Line Circuit Breaker Failure Protection Settings: Relay Type: MiCOM P821. HV Protection Relays Setting Calculation 33 of 58 Rev.5 x In Description: Select the phase current threshold. CB FAIL PHASE: YES Description: Enable/Disable the Circuit Breaker Failure protection by phase.4 . I> BF: 0. 732)/(110V/1. Line Synchronism Check Relay Settings: Relay Type: KAVS100.4 .= 50mHz -CSS Synch. 50Hz Line VT Ratio: (132kV/1. Ratio= 132000: 110 -CSS Phase Angle=20° -CSS Slip Freq.HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 4. Timer=1 Second -CSS Split Angle=170° -CSS Split Timer=1 Second -CSS System Angle=20° -CSS System Slip Freq.732)/(110V/1.= 50mHz -CSS System Timer=1 Second -CSS V.732) Relay Settings: Check Synchronism Settings (CSS) -CSS V.B/L Dead= 13V -CSS Under voltage= 80V -CSS Diff.T.732) Bus VT Ratio: (132kV/1. Make: Areva Location: 132kV Line Relay Panel: = E02+R1 System Data: System Voltage: 132kV. Voltage= 5V HV Protection Relays Setting Calculation 34 of 58 Rev.B/L Live= 32V -CSS V. 4 .HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 D. Protection Relays Setting on 132kV Relay Panel for Line Bay E04(132kV NRW-1). HV Protection Relays Setting Calculation 35 of 58 Rev. 9.228)Ohm/Km Rated current carrying capacity of the line = 488A Opposite End Grid Station Shortest and Longest Lines Data: Shortest Line: 10.3921 Ohms/Km R0+jX0= 0. Impedance: Zero Seq.1248 Ohms/Km R1+jX1= 0.1583+j0.4 . Impedance: R1+jX1= 0. -Zone 2: Impedance of protected line + 50% of impedance of adjacent shortest T/L and trip delay time 350ms delay.4004)Ohm/Km Zero Sequence ZL0 = (0.6 Line Length: 10.3246+j1. Impedance: Rail conductor: Positive Seq.3246+j1.2461+j1. 50Hz CT Ratio: 1200/1 VT Ratio: (132kV/1.50 KM on Lynx conductor Line Impedance: Positive Sequence ZL1 = (0. HV Protection Relays Setting Calculation 36 of 58 Rev. Line Distance Protection Settings: Relay Type: MiCOM P442.1583+j0.HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 1.7.422Km. Make: AREVA Location: 132kV Relay Panel: = E04+R1 System Data: Transmission Line: 132kV Narowal NRW-1 System Voltage: 132kV. -Zone 3: Impedance of protected line + 120% of impedance of adjacent longest T/L and trip delay time 700ms delay. Impedance: Zero Seq. Lynx conductor (132kV Narowal to 132kV Shakargarh) T/L Conductor data at ambient temperature: Lynx conductor: Positive Seq.06+j0.4004 Ohms/Km R0+jX0= 0. Min KA=7.1 At Narowal Grid Station: Max KA= 8. Min KA= 6.732) Fault Levels: At HUBCO Narowal: Max KA= 9.228 Ohms/Km Distance Zone Reach Calculation : The distance zone reach is determined according to the following principles: -Zone 1: 85% of impedance of protected line and trips independently with 0s delay. Rail conductor (132kV HUBCO to 132kV Narowal) Longest Line: 36Km.732)/(110V/1. 062<10.422(0.4 = (28710 x 5) / (7100) 1. <kZ0 = <((ZL0-ZL1)/ 3.2042)=1.4004)= 1.43º 5.844<78.062 kZ0 Angle = <10.1583+j0. Zone 3 Reach : Backup Zone 3 is set to 100% of the protected line impedance + 120% impedance of the adjacent longest transmission line.6621+j4.6621+j4.5{10.5014 Z3 = 23. |kZ0| = (ZL0-ZL1)/ 3. Z3 = (1.12<68.ZL1 Set as degrees ZL0-ZL1 = (0.9747+j6.638º kZ0 = (0.2474 Z2 = 6.46º 4.06+j0. In general.4º 3.732)}=1 Line impedance ZL1= 10.4127+j3.ZL1 Set as ratio kZ0 Angle.1kA. If = Minimum expected phase-phase fault current.3921)} = 1.2042)+1.521<68.HUBCO P60110-E-PRSC-001 1.228) – (0.638º)/(3 x 4. Zone 1 Reach : Zone 1 is set to 85% of the protected line impedance.4004) = 0. kZ2.5735 Z1 = 3.58 = 0.6621+j4.2º Therefore: kZ0 Res. Line Impedance: HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 Ratio of secondary to primary impedance = (1200/1)/{(132000/1. kZ3) 6.1583+j0. HV Protection Relays Setting Calculation 37 of 58 Rev.85 x (1. Comp = 0.521<68. kZ2.2º (Set for kZ1. RPh must be set greater than the maximum fault arc resistance for a phase-phase fault.6 RPh >=Ra Where: Ra = Arc resistance L = Maximum phase conductor separation.55<72. Residual Compensation for Earth Fault Elements: Residual Compensation. thus the resistive reach (RPh) is set independent of the impedance reach along the protected line. Resistive Reach -Phase Fault Elements The P442 relay have quadrilateral distance elements. Z1 = 0.43º) = 0.4 = 0.844<78.843<68.4 . is taken 7.2042 ZL1= 4. Zone 2 Reach : Zone 2 is set to 100% of protected line impedance + 50% impedance of the adjacent shortest transmission line.732)/(110/1. Z2 = (1.2{36(0. calculated from van Warrington formula as follows: Ra = (28710 x L) / If 1.6621+j4.4º 2.1583+j0.500 x (0. kZ3) (Set for kZ1. is assumed 5m.2042)+0.5006+j21.4004)} = 8.3246+j1. 6 Maximum 60 Zone-1 20 Zone-2 30 Zone-3 45 8.57MVA=100 Typically.57 MVA. the resistive reach of each zone would not normally be set greater than 10 times the corresponding zone reach. which is 111. Therefore: Earth (RG) Relay Settings: Functions Configuration: -Setting Group: Select via menu -Active Settings: Group 1 -Setting Group 1: Enabled -Setting Group 2: Disabled -Setting Group 3: Disabled -Setting Group 4: Disabled -Distance: Enabled -Power Swing: Enabled -Back-up I>: Disabled -Neg. -Supervision: Enabled -System Checks: Enabled -Internal A/R: Enabled -Setting values: Secondary Minimum 40 Maximum 80 Zone-1 30 Zone-2 40 Zone-3 60 HV Protection Relays Setting Calculation 38 of 58 Rev.This allows max phase resistive reach = 0. It is assumed. The maximum power flow is calculated from the ampacity of the conductor of 488A at nominal system voltage of 132kV. that the maximum power flow is transferred under worst condition at a minimum system voltage of 80%.8 x 100 = 80 Fault resistance would comprise arc resistance and tower footing resistance.A typical resistive reach coverage would be 40 on the primary side. phase fault distance zones would avoid the minimum load impedance by a margin of >= 40%. In addition. Therefore: Phase (RPh) Minimum 0. the resistive reach of any zone of the relay would not normally be greater than 10 times the corresponding earth loop reach. For best zone reach accuracy.HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 The minimum load impedance can be calculated on the basis of the maximum permitted power flow over the protected line. Sequence O/C: Disabled -Broken Conductor: Disabled (This setting is disabled by wapda during commissioning ) -Earth Fault O/C: Disabled -Aided DEF: Disabled -Volt Protection: Disabled -CB Fail & I<: Disabled. Therefore the minimum load impedance is ZLoad(min)= (0.This allows max phase resistive reach = 0. Resistive Reach Calculation-Earth Fault Elements: Typically. Earth fault distance zones would avoid the minimum load impedance by a margin of >= 20%.8 x 132kV)²/111.4 .6 x 100 =60 A setting between the calculated minimum and maximum should be applied for all zones. for best zone reach accuracy. 062 -kZ3/4 Angle: 10. -Trip Mode: Force 3 poles HV Protection Relays Setting Calculation 39 of 58 Rev.0s -kZ2 Res Comp: 0.521 -Line Angle: 68.12 -R3G-R4G: 60 -R3Ph-R4Ph: 45 -tZ3:700ms Fault Locator: -kZm Mutual Comp: 0 -KZm Angle:0º Distance Schemes: -Program Mode: Standard Scheme -Standard Mode: PUP Z2 -Fault Type: Both Enabled.HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 CT and VT Ratios: -Main VT Primary: 132kV -Main VT Secondary: 110V -C/S VT Primary: 132kV -C/S VT Secondary: 110V -Phase CT Primary: 1200A -Phase CT Secondary: 1A -MComp CT Primary: 1200A -MComp CT Secondary: 1A -C/S Input: A-B -Main VT Location: Line -CT Polarity: Standard or Inverse (To be set at site) CB Control: -CB Control by: Disabled -A/R Single Pole: Disabled -A/R Three Pole: Enabled OPTO Configuration: -Global Nominal Voltage: 110/125V -Opto Filter Cntl: Select All Distance Element: Line Setting: -Line Length: 10.843 -R1G:30 -R1Ph:20 -tZ1:0.50 km -Line Impedance: 4.55 -R2G: 40 -R2Ph: 30 -tZ2:350ms -kZ3/4 Res Comp: 0.4º Zone Setting: -Zone Status: 01010 -kZ1 Res Comp: 0.2º -Z2: 6.062 -kZ2: Angle: 10.2º -Z1: 3.2º -Z3: 23.062 -kZ1 Angle: 10.4 . 2 (N/A) -I2/I1 Time Delay: 60 s (N/A) -I2/I1 Trip: Enabled (N/A) Supervision: -VTS Time Delay: 5sec -VTS I2 & I0 Inhibit: 0.): 40% -I2> status: Enabled -I2> (% Imax.1 x In -CTS Status: Disabled -CVTS Status: Disabled Systemchecks: -Check Scheme for A/R: Select all -Check Scheme for ManCB: None -V<Dead Line: 13V -V>Live Line: 32V -V<Dead Bus: 13V -V>Live Bus: 32V -Diff Voltage: 5V -Diff Frequency: 0.1sec -A/R Inhibit Wind: 5 sec -C/S 3P Rcl DT1: Enabled -Block A/R: Select all HV Protection Relays Setting Calculation 40 of 58 Rev.4 .05 x In -Detect 3Pole: Enabled -Threshold 3Pole: 30V -Delta I>: 0.0ms -Unblocking Logic: None -SOTF/TOR Mode: SOTF/TOR all zones -SOTF Delay: 110.0s -Z1Ext Fail: Disabled -WI Mode Status: Disabled -LoL Mode Status: Disabled Power Swing: -Delta R: 9 -Delta X: 9 -IN> status: Enabled -IN> (% Imax.5sec -Reclaim Time: 180 sec -Close Pulse Time: 0.): 30% -ImaxLine> status: Enabled -ImaxLine>: 4.HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 -tReversal Guard: 20.0 x In (A) -Unblocking delay: 30 sec -Blocking zones: Select all Broken Conductor: -Broken Conductor: Disabled (This setting is disabled by wapda during commissioning ) -I2/I1: 0.05Hz -Diff Phase: 20º -Bus-Line Delay: 0.2 sec Autoreclose: -3P Trip Mode:3/3 -3P Dead Time1: 0. the proposed setting is 800msec. 700ms) of distance protection relay. Recommended phase overcurrent setting I>= 0. Line Backup Overcurrent Protection Settings: Relay Type: MiCOM P122.4 .8s t Reset=60 ms Ie>> =Not Enable Ie>>>= Not Enable 10-2010) 10-2010) HV Protection Relays Setting Calculation 41 of 58 Rev. For definite time o/c. [50/51] Phase OC Setting: I> = YES I> = 960/1200= 0.1 x In (Revised setting as per WAPDA Lettter GM(WPPO)/CE-IV/13827-29 Dated 06Delay Type=DMT Curve = DT Time Delay= 0. Make: Areva Location: 132kV Line Relay Panel: = E04+R1 CT Ratio For Backup O/C Protection: 1200/1 Relay Settings: The time delayed overcurrent protection relay MiCOM P122 serves as backup protection and is delayed against the distance zone timers.HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 2.1 x In = 120A Overcurrent operation time should be greater than zone-3 operation time (i.8 x In (Revised setting as per WAPDA Lettter GM(WPPO)/CE-IV/13827-29 Dated 06Delay Type = DMT Curve = DT Time Delay= 0.e 100ms is added to backup o/c time to coordinate with zone-3 operating time of 700ms). (i.8 x In = 960A Recommended earth fault setting Ie>= 0.e.8s t Reset=60 ms I>> =Not Enable I>>>= Not Enable [50N/51N] E/Gnd OC Setting: le >=YES le >=120/1200=0. Line Circuit Breaker Failure Protection Settings: Relay Type: MiCOM P821. HV Protection Relays Setting Calculation 42 of 58 Rev. I> BF: 0.5 x In Description: Select the phase current threshold.HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 3. External Reset: YES Description: Reset configuration of tBF1 after drop off of the external tripping. Delay Stage1: 150 ms Description: Set the retrip delay. Make: Areva Location: 132kV Line Relay Panel: = E04+R1 CT Ratio: 1200/1 Relay Settings: CB FAIL FUNCT : YES Description: Enable/Disable the Circuit Breaker Failure protection. Ie> BF: 0. CB FAIL PHASE: YES Description: Enable/Disable the Circuit Breaker Failure protection by phase.15 x In Description: Select the earth current threshold.4 . CB FAIL EARTH:YES Description: Enable/Disable the Circuit Breaker Failure protection on earth. Delay Stage2: 280 ms Description: Set the general back-trip delay. T.732) Relay Settings: Check Synchronism Settings (CSS) -CSS V. Line Synchronism Check Relay Settings: Relay Type: KAVS100.HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 4.= 50mHz -CSS System Timer=1 Second -CSS V.4 . Make: Areva Location: 132kV Line Relay Panel: = E04+R1 System Data: System Voltage: 132kV.B/L Dead= 13V -CSS Under voltage= 80V -CSS Diff. 50Hz Line VT Ratio: (132kV/1.B/L Live= 32V -CSS V. Ratio= 132000: 110 -CSS Phase Angle=20° -CSS Slip Freq.732) Bus VT Ratio: (132kV/1. Timer=1 Second -CSS Split Angle=170° -CSS Split Timer=1 Second -CSS System Angle=20° -CSS System Slip Freq.= 50mHz -CSS Synch.732)/(110V/1.732)/(110V/1. Voltage= 5V HV Protection Relays Setting Calculation 43 of 58 Rev. HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 E. HV Protection Relays Setting Calculation 44 of 58 Rev. Protection Relays Setting on 132kV Buscoupler Relay Panel for Buscoupler Bay E05.4 . 54Volts The relay plug setting voltage VR must be set to the nearest tap above this value. Discriminating Feature: Relay voltage setting = (Fault current/CT Ratio ) x ( Rct + 2x Rlead) = {9.4 . The available tap is 75 volt.737 Ohm Relay Settings: (Applicable For Discriminating Zone-1. there are 2-discriminating zones for bus-1 and bus-2 and a check zone. The relay may be used for any type of high impedance circulating current protection.1 CT ratios of all bays for Busbar Protection: 2400/1 CT secondary winding resistance: 14 Ohm CT Knee Point Voltage: Approx.737) = 62.685 Ohm/Km = 0.7kA / (2400/1)} x (14 + 2 x 0. Min KA=7. 50Hz Busbar Current Rating: 1600A. Zone-2 and Check Zone Relay): MFAC34 is a voltage operated relay having seven equally spaced settings which may be selected by means of a plug bridge. As per scheme. Make: Areva Location: 132kV Buscoupler Relay Panel: = E05+R1 System Data: System Voltage: 132kV.7. 40kA/1sec Fault Levels at HUBCO Narowal: Max KA= 9.HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 1. Therefore: VR= 75 volts Knee point voltage of the current transformers should not be less than twice the relay setting voltage. 800Volts CT Exciting current at 75Volt: Approx 3mA (approximated from curve) Cable size used for CT secondary circuit: 6mm2 Lead length: Approx 200M Lead resistance: 3. High Impedance Differential Protection of 132kV Busbar: Relay Type: 3-Nos. VK 2 VR HV Protection Relays Setting Calculation 45 of 58 Rev. MFAC34. it may be increased by the addition of a shunt resistor RSH to give a current of Taking: RSH = 625 ISH = VR / RSH = 75 volts/625 = 0. The primary current for relay operation is given by: Ip = CT Ratio (IRelay + n IE ) Where. Taking full load current of single 70MVA transformer =306 Amps The primary operating current = 1.HUBCO P60110-E-PRSC-001 VK VK 2 x 75 150 volts HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 Therefore current transformers VK of approx.4 . n = max.e 130% of the full load current. number of current transformers in parallel with the relay = 9 IE = ct exciting current at relay setting voltage = approx 3mA at 75volts Therefore: Ip = 2400 ( 0. This provides a shunt circuit for high internal fault currents and prevents a high voltage being developed across the CT and relay circuits.12}=398 Amps Each MFAC relay is applied with an external metrosil which must be wired across the relay circuit.019 + 9 x 0.003) Ip = 110 Amps It is desirable that the primary effective setting should not exceed 30% of the minimum fault current i.e. 30% of 7. Where 30% of the minimum fault current is more than the full load current of the largest circuit.1KA= 2130Amps.12 Amps Therefore the new increased value of primary current: Ip = CT Ratio (IRelay + n IE + ISH) Ip = 2400 {0.003) + 0. HV Protection Relays Setting Calculation 46 of 58 Rev.019 + 9(0.3 x 306 = 398 Amps Since the resultant value of ‘Ip=110 Amps’ is too low. 800 volts is OK. the primary operating current should be made more than the full load current i. RSH = 625 HV Protection Relays Setting Calculation 47 of 58 Rev.003) = 103A As the difference in number of parallel circuit for check and discrimination zone is not significant.019 + 8 x 0. of ct circuits = 8 Relay Current IRelay = 19mA HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 Therefore Primary Operating Current = Ip = 2400 ( 0.HUBCO P60110-E-PRSC-001 Check Feature: Relay setting Voltage VR= 75 volts No.4 . therefore same value of RSH = 625 is taken for increased operating value of primary current. HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 2. in one volt steps. Make: Areva Location: 132kV Buscoupler Relay Panel: = E05+R1 Relay Settings: (Applicable For Discriminating Zone-1 and Zone-2 ‘MVTP31’ Relays): The MVTP31 provides continuous supervision of buswires in high impedance type busbar protection schemes. the magnetizing impedance will be: . MVTP relays have setting rang 1-16V. the magnetizing current of ct is approx.. Assuming one ct is open circuit out of 9.. VSP= I x {(R x Zm)/(R + Zm)} = (25/2400) x {(3947 x 3125)/(3947+3125)} = 18 volt As the maximum available setting is 16volt. Voltage setting of Supervision Relay VSP= I x {(R x Zm)/(R + Zm)} Where. Open circuit connections between CT’s and relay circuit result in unbalance currents which may operate the protection. R= 75/. Operating current at 16 volt will be. I= Supervision Operating Current R= Resistance of High Impedance Relay Zm= Parallel impedance of CT magnetizing impedances assuming 1 CT is open circuit. relay operating current is 19mA. therefore: Voltage Setting of Supervision Relay VSP= 16 Volt. and a fixed operating time of 3-seconds. Zm= (75/0. Supervision Relay For High Impedance Type Busbar Protection Scheme Relay Type: MVTP31.4 . Supervision is applied by a voltage relay across differential relay circuit.019= 3947 Hence.003)/8= 25000 /8= 3125 At 75 volt setting. whichever is greater. Whenever possible. the supervision primary operating current should not be more than 25Amps primary or 10% of the smallest circuit.. Assuming I = 25A At 75 volt.. = 3mA. . I= 16/{(3947 x 3125)/(3947+3125)} x 2400 I= 22 amps primary HV Protection Relays Setting Calculation 48 of 58 Rev. Make: Areva Location: 132kV Buscoupler Relay Panel: = E05+R1 CT Ratio: 1200/1 Relay Settings: Recommended setting for I> = 1. GM(WPPO)/CE-IV/7208 Dated 31-05-2010.6 x In = 1920A Recommended setting for Ie> = 0.075 x In = 90A A 150ms delay at maximum current should be allowed for an instantaneous line protective relay to actuate and a line circuit breaker to trip and to allow margin for uncertainty. It was mistakenly wrongly typed in revision-1 and has been corrected now in rev-2.HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 3. Buscoupler Overcurrent Protection Settings: Relay Type: MiCOM P122. It was mistakenly wrongly typed in revision-1 and has been corrected now in rev-2.) [50N/51N] E/Gnd OC Setting: le >=YES le >=90/1200=0. GM(WPPO)/CE-IV/7208 Delay Type=DMT Curve = DT Time Delay= 950ms ( This setting is in accordance with WAPDA letter ref.) t Reset=60 ms Ie>> =Not Enable Ie>>>= Not Enable HV Protection Relays Setting Calculation 49 of 58 Rev. GM(WPPO)/CE-IV/7208 Dated Dated 31-05-2010. Therefore the proposed setting for time delay is: tI> = 800ms +150ms = 950ms [50/51] Phase OC Setting: I> = YES I> = 1920/1200 = 1.) t Reset=60 ms I>> =Not Enable I>>>= Not Enable Delay Type = DMT Curve = DT Time Delay= 950ms ( This setting is in accordance with WAPDA letter ref.) 31-05-2010. It was mistakenly wrongly typed in revision-1 and has been corrected now in rev-2.6 x In ( This setting is in accordance with WAPDA letter ref. It was mistakenly wrongly typed in revision-1 and has been corrected now in rev-2. GM(WPPO)/CE-IV/7208 Dated 31-05-2010.075 x In ( This setting is in accordance with WAPDA letter ref.4 . HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 4.15 x In Description: Select the earth current threshold. CB FAIL PHASE: YES Description: Enable/Disable the Circuit Breaker Failure protection by phase. Make: Areva Location: 132kV Buscoupler Relay Control Panel: =E05+R1 CT Ratio: 1200/1 Relay Settings: CB FAIL FUNCT : YES Description: Enable/Disable the Circuit Breaker Failure protection. External Reset: YES Description: Reset configuration of tBF1 after drop off of the external tripping. Delay Stage2: 280 ms Description: Set the general back-trip delay. Ie> BF: 0.5 x In Description: Select the phase current threshold. Buscoupler Circuit Breaker Failure Protection Settings: Relay Type: MiCOM P821.4 . CB FAIL EARTH:YES Description: Enable/Disable the Circuit Breaker Failure protection on earth. Delay Stage1: 150 ms Description: Set the retrip delay. I> BF: 0. HV Protection Relays Setting Calculation 50 of 58 Rev. = 50mHz -CSS Synch.B/L Live= 32V -CSS V. 50Hz Line VT Ratio: (132kV/1.= 50mHz -CSS System Timer=1 Second -CSS V.732) Bus VT Ratio: (132kV/1. Make: Areva Location: 132kV Buscoupler Relay Control Panel: = E05+R1 System Data: System Voltage: 132kV.4 . Voltage= 5V HV Protection Relays Setting Calculation 51 of 58 Rev.HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 5.732)/(110V/1. Buscoupler Synchronism Check Relay Settings: Relay Type: KAVS100. Timer=1 Second -CSS Split Angle=170° -CSS Split Timer=1 Second -CSS System Angle=20° -CSS System Slip Freq. Ratio= 132000: 110 -CSS Phase Angle=20° -CSS Slip Freq.B/L Dead= 13V -CSS Under voltage= 80V -CSS Diff.732)/(110V/1.T.732) Relay Settings: Check Synchronism Settings (CSS) -CSS V. WAPDA reference letters about relay settings recommendation.HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 F. HV Protection Relays Setting Calculation 52 of 58 Rev.4 . HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 1. Letter No.4 . GM(WPPO) CE-IV/7208 Dated 31-05-2010 HV Protection Relays Setting Calculation 53 of 58 Rev. HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 HV Protection Relays Setting Calculation 54 of 58 Rev.4 . HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 HV Protection Relays Setting Calculation 55 of 58 Rev.4 . HUBCO P60110-E-PRSC-001 2. GM(WPPO) CE-IV/13827-29 Dated 06-10-2010 HV Protection Relays Setting Calculation 56 of 58 Rev.4 . HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 Letter No. HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 HV Protection Relays Setting Calculation 57 of 58 Rev.4 . HUBCO P60110-E-PRSC-001 HNP Hubco Narowal Project Switch-Yard-System Status: 2011-02-25 HV Protection Relays Setting Calculation 58 of 58 Rev.4 .
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