Electrical Protection & Relay Coordination Study Sample

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RECORD OF REVISION

The revisions listed below have been incorporated in this copy of the document.

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TABLE OF CONTENTS

1. GENERAL 4

1.1 INTRODUCTION 4

2. OBJECTIVE 4

3. POWER SYSTEM OVERVIEW 4

4. ASSUMPTION AND CALCULATION BASIS 6

4.1 BASIS OF STUDY 6

4.2 STUDY CASES 6

5. TIME-CURRENT CURVES 7

5.1 Largest Motor Feeder Protection Setting 7

5.2 LV Switchgear Incoming ACB and Largest Static Load Feeder Protection Setting 7 Relay Coordination Between Incoming ACB with Motor Feeder and Static Load Feeder 8 5.3 MV Switchgear (RMU) Protection Setting and Coordination with Incoming ACB Relay 8

Relay Coordination between RMU with LV Switchgear ACB 9

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6.1 RMU Under/Over Voltage, Under/Over Frequency Protection 9

6.2 Transformer Protection 10

6.3 Earth Fault Protection & Monitoring 10

7. SUMMARY 11

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1.

GENERAL 1.1

Husky CNOOC (Madura) Ltd. (HCML) plans to develop the Madura BD Field gas reserves for the sale of gas to buyers in Java. This field is located offshore in the Madura Strait East Java, about 65 km east of Surabaya and about 16km south of Madura Island.

The project envisaged development of a wellhead platform (WHP); an offshore spread-moored Floating, Production, Storage and Offloading (FPSO) barge with gas processing facilities, Gas Metering Station (GMS); flexible risers from wellhead platform to FPSO and Export gas pipeline from WHP to GMS.

The facility is designed for 110 mmscf/d sales gas. The unmanned wellhead platform with four well slots and two slots for future expansion would be located at 125 meters distance from FPSO and set in 182 feet of water.

2.

OBJECTIVE

This report covers the Protection Relay Coordination Study for Madura BD Field Wellhead Platform. The purpose of carrying out the study is to determine the required settings for all main electrical protective devices to ensure proper coordination and safe operation of all equipments under fault conditions.

Software ETAP (Electrical Transient Analysis Program) version.12 have been utilized in this calculation study.

3.

POWER SYSTEM OVERVIEW

Madura BD Field Wellhead Platform electrical network system is made up of 1 unit of 6.6kV 60Hz Junction Box, 1 unit of 6.6kV 60Hz Ring Main Unit / MV Switchgear (10-RMU-6600-01), 1 unit of 6.6kV/480V 60Hz 400 kVA rating Transformer (10-TF-480-01), and 1 unit of 480V 60Hz LV Switchboard/MCC (10-MCC-480-01) to channel generated electrical power to respective electrical consumer.

Below is a sketch presenting the overall electrical power network configuration for the Madura BD Field Wellhead Platform.

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During normal operation, the electrical power of well head platform comes from Gas Turbine Generator at FPSO which is located near the well head platform. The generated power has 6.6kV voltage and 60Hz frequency. The power deliver from FPSO through 6.6 kV sub-sea cable (300 Meter Length) to 6.6kV Junction Box located at Cellar-Deck of well head platform, then goes to MV Switchgear (RMU) for isolating/connecting the power. The 6.6kV voltage is stepped down to 480V voltage by 400KVA Rating Transformer. The 480V voltage side of transformer is connected to 480V LV switchgear that will deliver electrical power to electrical loads at well head platform. During Main Power Failure at FPSO (Emergency situation), the emergency generator at FPSO will operate immediately to replace the failed Main Generator providing electrical power for electrical loads at FPSO and well head platform. All electrical loads of well head platform during normal operation can be handling by emergency generator of FPSO during Main Power Failure situation.

Other electrical source for well head platform is from portable generator or supply boat generator that can be connected through socket outlet at boat landing connected to 480V low voltage switchgear/MCC. This source has an interlocked scheme with main incomer from 400KVA Transformer. This source only operated when power from FPSO is cut-off and maintenance work is needed to be done at well head platform. The amount of electrical power from this socket outlet is limited (around 69.28 KVA) due to limited capacity of portable generator or supply boat generator.

Sections below provide a brief description of the expectation for the studies that is being carried out in this report.

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4.

ASSUMPTION AND CALCULATION BASIS 4.1

Protection is arranged to cover the electrical power system completely, leaving no parts unprotected. When fault occurs, the protection is required to selectively trip only the nearest circuit breaker.

The fault clearing time, the operating time of the relay and time taken for its breaker opening, shall not exceed 1.0 second of the short circuit withstand time of the MV Junction Box, RMU and LV Switchgear.

The relay current setting is selected to permit continuous equipment full load current flow through the relay without the relay operating. For main distribution transformer feeder, the current setting selected for high voltage side overcurrent relay and low voltage side overcurrent relay shall ensure that the relays do not operate during energizing of the transformer which may draw up to 12 times transformer rated full load current. For motor feeders, the current setting selected shall ensure that the relay does not operate during the starting of the motor which may draw up to 6.5 times motor rated full load current.

Transformer thermal limit curve are develop in etap using manufacturer data.

Motor starting curve and motor thermal limit curve (MEG Injection Pump Motor) are develop based on below data:

Motor starting time = depend on total inertia and load characteristic (in here, 1.2 sec, based on etap results for largest motor starting simulation study).

Motor stall time = 19-21 sec (Cold) and 22-24 sec (Hot) based on WEG motor data. The upstream protective devices will provide selectivity with the downstream feeder protective devices. In general, an attempt has been made to achieve a time margin of 0.2-0.3 sec between upstream relay and downstream relay for clearing of down-stream fault when the fault currents flow through both devices simultaneously.

4.2

1. Normal Operating Condition (power supplied from FPSO).

This scenario will represent the normal platform operating condition. The details of this scenario are listed below:

a. Normal Operating of FPSO Generators are running b. All possible motor contributing loads are running

2. Summary of fault level on each busbars / equipments can be seen at document WHP-SYE-003 (Electrical Short Circuit Study).

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5.

TIME-CURRENT CURVES

The time-current curves are modelled in the program as graphical plots of the interaction of the system overcurrent devices. These time-current curves are used to establish the recommended setting and characteristics of overcurrent devices. The time-current curves are plotted using the electrical power system study software ETAP 12.

The time-current curves (TCC) showing protective relay coordination in this power system will be describe below. First is the protective device coordination at largest motor feeder, between MCCB to protect motor and cable against overload and short-circuit current with considering motor starting current, motor thermal limit, and cable thermal limit. Second is the protective device coordination between incoming Air Circuit Breaker (ACB) of LV switchgear with largest motor feeder and largest static load feeder. The incoming ACB time current curves must be on the right-above side of time current curves of largest motor and static load. This arrangement will give selective trip sequence between downstream and upstream protection device, mean that the downstream device should operate first and if it fails then the upstream device should be operate. Third is the coordination between the incoming circuit breaker ACB of LV switchgear (low voltage side of transformer) with medium voltage circuit breaker relay of RMU (high voltage side of transformer) with considering inrush current, thermal limit of transformer and thermal limit of cables.

The setting of protection devices for above coordination are describe below. 5.1

The setting of MCCB relay of MEG Injection Pump motor are described below. Thermal Magnetic MCCB

Full Load Current : 43.9 A

Sensor Plug (In) : 100 A

Long-Time Pick-Up (LTPU) : 0.52 (52A)

Long-Time Band : 3s

Short-Time Pick-Up (STPU) : 10 (1000A)

Short-Time Band : 0.25s

Instantaneous Pick-Up : 9 (900A)

Type/Maker : T2S/ABB

The time current curve of above settings can be seen at appendix-D. From the curve can be seen that thermal part are located right side of motor full load ampere but still at left side - below of motor thermal limit and cable ampacity. The magnetic part curve are located right side of motor starting current, motor thermal limit and cable ampacity but it still at left-below of cable thermal limit curve.

5.2

Largest static load feeder is the heat tracing control panel, which is 40 KVA. The protection setting is described below.

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Thermal Magnetic MCCB

Long-Time Band : 3s

Short-Time Band : 0.1s

Type/Maker : T2S/ABB

The protection setting of incoming ACB is described below. Over Current Device - 50 & 51

Long-Time Band : Curve A

Short-Time Band : Curve B

Type/Maker : SACE PR111/ABB

The time current curve of coordination relay/protection device settings between Incoming ACB with motor feeder and static load feeder can be seen at appendix-E. From the curve can be seen that Incoming ACB relay is located at right side above of motor feeder relay and static load feeder relay. Mean that, any fault happened at motor feeder or static load feeder, will trip first the motor feeder relay or static load feeder relay, if these relay fails, then the incoming ACB relay will trip.

5.3

The protection setting of RMU relay is described below. Over Current Device 50 & 51

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CT Ratio : 75:5

Curve Type : Extremely Inverse

Pickup : 0.92 (0.05-20 x CT Sec)

Time Dial : 11.94, 3x =7.87 s, 5x=2.95s, 8x=1.5s Instantaneous Pick-Up : 20 (0.05-20 x CT Sec)

Time Delay : 0.25 s

Type/Maker : Multilin 750/760/GE

The relay coordination between RMU with LV Switchgear ACB can be seen at appendix-F. The time current curve show the ACB relay curve is located right-above of transformer full load current and inrush current curve but left-below of LV cable ampacity, LV cable thermal limit and transformer thermal limit curve. The RMU relay curve is also located right-above of transformer full load current and inrush current but left-below of MV cable ampacity, MV cable thermal limit and transformer thermal limit curve. The ACB relay curve is located left-below of RMU relay curve with some time margin. At the instantaneous part, the time margin between ACB relay and RMU relay curve is 0.25 S. It is mean that when a fault located at LV side happened, the ACB relay will operate instantaneously, and if this relay fails to operate, the RMU relay will be operated after 0.25 S delay time.

6.1

Under Voltage / Over Voltage Protection Device 27/59 VT Ratio: 6600V /110V

The under-voltage relay is to be set at 80% with time delay so that to ride through the momentary voltage dip during the starting of large motors.

- Set alarm level at 85% = (85/100) x 110V = 93.5V - Set trip time delay at 6 seconds.

- Set trip pickup level at 80% = (80/100) x 110V = 88V - Set trip time delay at 3 seconds.

The overvoltage relay is set at 110% of the rated transformer voltage to protect the transformer against continuous overvoltage due to transients.

- Set trip 1 pickup level at 110% = (110/100) x 110V = 121V - Set trip 1 time delay at 3 seconds

- Set trip 2 pickup level at 125% = (125/100) x 110V = 137.5V - Set trip 2 time delay at 0.5 seconds

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- Set under frequency alarm at 2.5% of rated frequency = 97.5% x 50 = 48.75 Hz - Set alarm time delay at 10 seconds.

- Set trip under frequency pickup at 5% of rated frequency = 95% x 50 = 47.5 Hz - Set trip time delay at 10 seconds.

6.2

6.3

The 480V system is high resistance earthed at transformer LV side star point. The resistance value is 55.5 ohm and can limit earth/ground fault to 5A. When earth fault happened, the earth fault will not trip the protection system, but it will be detect / monitored by relay meter at grounding panel. The relay meter will send alarm to PCS for annunciation. The grounding panel also equipped with pulsation circuit with can detect the location of the ground fault. Therefore, the faulted line can be isolated.

The 208/120V system is solidly earthed at transformer star point. The 208/120V Small Power & Lighting and 208/120V UPS are using Neutral and protective earth conductor separate (TN-S grounding system).The earth Leakage Relay (ELR) protection is provided in following circuit / feeder:

- Lighting and Socket circuits in Lighting and Small Power Distribution Board. - Socket Outlet Circuits in UPS Distribution Board.

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7.

SUMMARY

Summary of the recommended protective device settings are shown from Appendix B to Appendix C.

Relay coordination from Largest Motor Feeder (MEG Injection Pump Motor), Largest Static Load Feeder (Heat Tracing Control Panel) to LV Incoming ACB is shown in Appendix E.

Relay coordination from RMU to ACB is shown in Appendix F. .

8.

APPENDIXES

1) APPENDIX A - OVERALL ONE LINE DIAGRAM

2) APPENDIX B - RELAY SETTING TABLE RMU, ACB & TRANSFORMER

3) APPENDIX C - RELAY SETTING TABLE MOTOR FEEDER & STATIC LOAD FEEDER 4) APPENDIX D - TIME CURRENT CURVES FOR LARGEST MOTOR FEEDER

5) APPENDIX E - TIME CURRENT CURVES COORDINATION ACB, MOTOR & STATIC LOAD FEEDER

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APPENDIX E - TIME CURRENT CURVES COORDINATION ACB, MOTOR & STATIC LOAD FEEDER

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1 1 5 1 2 5 % F L C L T P ic k -u p L T B a n d S T P ic k u p S T B a n d In s P ic k -u p M C C B T yp e M C C B F ra m e R a te d M C C B R a te d C u rr e n t L V S W IT C G E A R /M C C ( 1 0-M C C -4 8 0 -0 1 ) 1 G -1 0 0 3 A O p e n D ra in S u m p P u m p A M o to r 3 .7 0 6 .5 4 7 .5 M 0 .8 (8 0 A ) 3s 10 (1 0 0 A ) 0. 2 5 s 10 (1 0 0 A ) T 2 S 1 6 0 1 0 2 G -1 0 0 3 B O p e n D ra in S u m p P u m p B M o to r 3 .7 0 6 .5 4 7 .5 M 0 .8 (8 0 A ) 3s 10 (1 0 0 A ) 0. 2 5 s 10 (1 0 0 A ) T 2 S 1 6 0 1 0 3 1 0 -N C C P -2 4 0 -0 1 N a v A id s B a tt e ry C h a rg e r 2 .0 0 2 .6 7 3 .1 F 0 .4 (4 A ) 3s 1( 1 0 A ) 0. 1 s 1( 1 0 A ) T 2 S 1 6 0 1 0 4 G -1 0 0 2 A P P D I n je ct io n P um p A M o to r 0 .7 5 1 .5 0 1 .7 3 M M a g n e tic T ri p = f ix ed (2 5 A ) T 2 S -T M D 1 6 0 3 .2 5 G -1 0 0 2 B P P D I n je ct io n P um p B M o to r 0 .7 5 1 .5 0 1 .7 3 M M a g n e tic T ri p = f ix ed (2 5 A ) T 2 S -T M D 1 6 0 3 .2 6 G -1 0 0 5 A H yd ra u lic P um p M o to r A 6 .0 0 1 0 .3 7 1 1 .9 3 M 0. 4 8 (1 2 A ) 3s 1( 2 5 A ) 0. 1 s 7. 5 (1 8 7 .5 A ) T 2 S 1 6 0 2 5 7 G -1 0 0 5 B H yd ra u lic P um p M o to r B 6 .0 0 1 0 .3 7 1 1 .9 3 M 0. 4 8 (1 2 A ) 3s 1( 2 5 A ) 0. 1 s 7. 5 (1 8 7 .5 A ) T 2 S 1 6 0 2 5 8 G -1 0 0 5 C H yd ra u lic P um p M o to r C 6 .0 0 1 0 .3 7 1 1 .9 3 M 0. 4 8 (1 2 A ) 3s 1( 2 5 A ) 0. 1 s 7. 5 (1 8 7 .5 A ) T 2 S 1 6 0 2 5 9 G -1 0 0 5 D H yd ra u lic P um p M o to r D 6 .0 0 1 0 .3 7 1 1 .9 3 M 0. 4 8 (1 2 A ) 3s 1( 2 5 A ) 0. 1 s 7. 5 (1 8 7 .5 A ) T 2 S 1 6 0 2 5 1 0 G -1 0 0 4 C L iq u id P u m p M o to r A 1 8 .7 0 3 2 .3 2 3 7 .1 7 M 0. 6 (3 7 .8 A ) 3s 10 (6 3 0 A ) 0. 2 5 s 10 (6 3 0 A ) T 2 S 1 6 0 6 3 1 1 G -1 0 0 4 D L iq u id P u m p M o to r B 1 8 .7 0 3 2 .3 2 3 7 .1 7 M 0. 6 (3 7 .8 A ) 3s 10 (6 3 0 A ) 0. 2 5 s 10 (6 3 0 A ) T 2 S 1 6 0 6 3 1 2 G -1 0 0 7 A M E G I n je ct io n P u m p M o to r A 2 5 .4 0 4 3 .9 0 5 0 .5 M 0. 5 2 (5 2 A ) 3s 10 (1 0 0 0 A ) 0. 2 5 s 9( 9 0 0 A ) T 2 S 1 6 0 1 0 0 1 3 G -1 0 0 7 B M E G I n je ct io n P u m p M o to r B 2 5 .4 0 4 3 .9 0 5 0 .5 M 0. 5 2 (5 2 A ) 3s 10 (1 0 0 0 A ) 0. 2 5 s 9( 9 0 0 A ) T 2 S 1 6 0 1 0 0 1 4 1 0 -U U -2 0 8 -0 1 A 2 0 8 V A C U P S A 2 0 .0 0 3 3 .3 0 3 8 .3 F 0. 6 4 (4 0 .3 A ) 3s 1( 6 3 A ) 0. 1 s 1( 6 3 A ) T 2 S 1 6 0 6 3 1 5 1 0 -U U -2 0 8 -0 1 B 2 3 0 V A C U P S B 2 0 .0 0 3 3 .3 0 3 8 .3 F 0. 6 4 (4 0 .3 A ) 3s 1( 6 3 A ) 0. 1 s 1( 6 3 A ) T 2 S 1 6 0 6 3 1 6 1 0 -U T -2 0 8-0 1 2 3 0 V A C U P S ( B yp a ss T ra n sf o rm e r) 2 0 .0 0 3 3 .3 0 3 8 .3 F 0. 6 4 (4 0 .3 A ) 3s 1( 6 3 A ) 0. 1 s 1( 6 3 A ) T 2 S 1 6 0 6 3 1 7 H C P -7 7 1 0 H e a t T ra ci n g C on tr o l P a n e l 4 0 .0 0 5 9 .4 0 6 8 .3 F 0 .6 8 ( 6 8 A ) 3s 1 (1 0 0 A ) 0. 1 s 1( 1 0 0 A ) T 2 S 1 6 0 1 0 0 N o . T a g N u m b e r D e s c ri p ti o n R a ti n g (k W ) T h e rm a l T ri p = 7 0 % ( 2 .2 4A ) T h e rm a l T ri p = 7 0 % ( 2 .2 4A ) R e m a rk F e e d e r T yp e R e la y S e tt in g F u ll L o a d C u rr e n t A

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R e q u ir e d R a ti n g O L /C B A P h as e F a u lt P ro te c ti o n R e la y / P ro te c ti o n D e vi c e D a ta

(21)

1 1 5 1 2 5 % F L C L T P ic k -u p L T B a n d S T P ic k u p S T B a n d In s P ic k -u p M C C B T yp e M C C B F ra m e R a te d M C C B R a te d C u rr e n t L V S W IT C G E A R /M C C ( 1 0-M C C -4 8 0 -0 1 ) N o . T a g N u m b e r D e s c ri p ti o n R a ti n g (k W ) R e m a rk F e e d e r T yp e R e la y S e tt in g F u ll L o a d C u rr e n t A

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R e q u ir e d R a ti n g O L /C B A P h as e F a u lt P ro te c ti o n R e la y / P ro te c ti o n D e vi c e D a ta 1 8 D B -7 7 1 0 L ig h tin g & S m a ll P o w e r D B 1 7 .3 4 2 5 .7 5 2 9 .6 F 0. 4 8 (3 0 .2 A ) 3s 1( 6 3 A ) 0. 1 s 1( 6 3 A ) T 2 S 1 6 0 6 3 1 9 D B -7 7 3 0 M O V D is tr ib ut io n B o a rd 2 4 .6 2 2 9 .6 1 3 4 .1 F 0. 5 6 (3 5 .3 A ) 3s 1( 6 3 A ) 0. 1 s 1( 6 3 A ) T 2 S 1 6 0 6 3 2 0 1 0 -W O -4 8 0-0 01 W e ld in g O ut le t-0 1 2 5 .0 0 3 7 .5 9 4 3 .2 F 0. 7 2 (4 5 .4 ) 3s 1( 6 3 A ) 0. 1 s 1( 6 3 A ) T 2 S 1 6 0 6 3 2 1 1 0 -W O -4 8 0-0 02 W e ld in g O ut le t-0 2 2 5 .0 0 3 7 .5 9 4 3 .2 F 0. 7 2 (4 5 .4 ) 3s 1( 6 3 A ) 0. 1 s 1( 6 3 A ) T 2 S 1 6 0 6 3 2 2 1 0 -W O -4 8 0-0 03 W e ld in g O ut le t-0 3 2 5 .0 0 3 7 .5 9 4 3 .2 F 0. 7 2 (4 5 .4 ) 3s 1( 6 3 A ) 0. 1 s 1( 6 3 A ) T 2 S 1 6 0 6 3 2 3 G -1 0 0 1 A D ie se l P u m p M o to r A 1 .1 0 2 .2 1 2 .5 4 M 0 .4 ( 4 0 A ) 3s 1 (1 0 A ) 0. 1 s 7. 5 ( 7 5 A ) T 2 S 1 6 0 1 0 2 4 G -1 0 0 1 B D ie se l P u m p M o to r B 1 .1 0 2 .2 1 2 .5 4 M 0 .4 ( 4 0 A ) 3s 1 (1 0 A ) 0. 1 s 7. 5 ( 7 5 A ) T 2 S 1 6 0 1 0 2 5 A C C U -0 1 A ir C o o le d C o n de n si n g U n it-A 3 .0 0 5 .3 1 6 .1 1 M 0 .7 ( 7 0 A ) 3s 1 (1 0 A ) 0. 1 s 7. 5 ( 7 5 A ) T 2 S 1 6 0 1 0 2 6 A C C U -0 2 A ir C o o le d C o n de n si n g U n it-B 3 .0 0 5 .3 1 6 .1 1 M 0 .7 ( 7 0 A ) 3s 1 (1 0 A ) 0. 1 s 7. 5 ( 7 5 A ) T 2 S 1 6 0 1 0 2 7 A C C U -0 3 A ir C o o le d C o n de n si n g U n it-C 3 .0 0 5 .3 1 6 .1 1 M 0 .7 ( 7 0 A ) 3s 1 (1 0 A ) 0. 1 s 7. 5 ( 7 5 A ) T 2 S 1 6 0 1 0 2 8 A C C U -0 4 A ir C o o le d C o n de n si n g U n it-D 3 .0 0 5 .3 1 6 .1 1 M 0 .7 ( 7 0 A ) 3s 1 (1 0 A ) 0. 1 s 7. 5 ( 7 5 A ) T 2 S 1 6 0 1 0 2 9 A C C U -0 5 A ir C o o le d C o n de n si n g U n it-E 3 .0 0 5 .3 1 6 .1 1 M 0 .7 ( 7 0 A ) 3s 1 (1 0 A ) 0. 1 s 7. 5 ( 7 5 A ) T 2 S 1 6 0 1 0 3 0 F C U -0 1 F a n C o il U n it-A 0 .3 0 0 .6 0 0 .6 9 M M a g n e tic T ri p = f ix ed (1 1 .2 A ) T 2 S -T M D 1 6 0 1 .6 3 1 F C U -0 2 F a n C o il U n it-B 0 .3 0 0 .6 0 0 .6 9 M M a g n e tic T ri p = f ix ed (1 1 .2 A ) T 2 S -T M D 1 6 0 1 .6 3 2 F C U -0 3 F a n C o il U n it-C 0 .3 0 0 .6 0 0 .6 9 M M a g n e tic T ri p = f ix ed (1 1 .2 A ) T 2 S -T M D 1 6 0 1 .6 3 3 F C U -0 4 F a n C o il U n it-D 0 .3 0 0 .6 0 0 .6 9 M M a g n e tic T ri p = f ix ed (1 1 .2 A ) T 2 S -T M D 1 6 0 1 .6 3 4 F C U -0 5 F a n C o il U n it-E 0 .3 0 0 .6 0 0 .6 9 M M a g n e tic T ri p = f ix ed (1 1 .2 A ) T 2 S -T M D 1 6 0 1 .6 T h e rm a l T ri p = 7 0 % ( 1 .1 2A ) T h e rm a l T ri p = 7 0 % ( 1 .1 2A ) T h e rm a l T ri p = 7 0 % ( 1 .1 2A ) T h e rm a l T ri p = 7 0 % ( 1 .1 2A ) T h e rm a l T ri p = 7 0 % ( 1 .1 2A )

(22)

1 1 5 1 2 5 % F L C L T P ic k -u p L T B a n d S T P ic k u p S T B a n d In s P ic k -u p M C C B T yp e M C C B F ra m e R a te d M C C B R a te d C u rr e n t L V S W IT C G E A R /M C C ( 1 0-M C C -4 8 0 -0 1 ) N o . T a g N u m b e r D e s c ri p ti o n R a ti n g (k W ) R e m a rk F e e d e r T yp e R e la y S e tt in g F u ll L o a d C u rr e n t A

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R e q u ir e d R a ti n g O L /C B A P h as e F a u lt P ro te c ti o n R e la y / P ro te c ti o n D e vi c e D a ta 3 5 P U -0 1 P re ss u ri ze F a n A 1 .5 0 3 .0 1 3 .4 6 1 5 M 0 .4 ( 4 0 A ) 3s 1 (1 0 A ) 0. 1 s 7. 5 ( 7 5 A ) T 2 S 1 6 0 1 0 3 6 P U -0 2 P re ss u ri ze F a n B 1 .5 0 3 .0 1 3 .4 6 1 5 M 0 .4 ( 4 0 A ) 3s 1 (1 0 A ) 0. 1 s 7. 5 ( 7 5 A ) T 2 S 1 6 0 1 0 3 7 D H -0 1 D u ct H e a te r 2 .0 0 2 .6 7 3 .1 F 0 .4 (4 A ) 3s 1( 1 0 A ) 0. 1 s 1( 1 0 A ) T 2 S 1 6 0 1 0 3 8 E F -0 1 E xh a u st F a n 0 .7 5 1 .5 0 1 .7 3 M M a g n e tic T ri p = f ix ed (2 5 A ) T 2 S -T M D 1 6 0 3 .2 T h e rm a l T ri p = 7 0 % ( 2 .2 4A )

(23)

Mtr1-starting

Mtr1-Hot

Cable5

Ampacity

Cable5 - P

CB3

ABB SACE PR221 (T2)

Sensor = 100

LT Pickup = 0.52 (52 Amps)

LT Band = 3s

ST Pickup = 10 (1000 Amps)

ST Band = 0.25s (I^x)t = IN

Inst. Pickup = 9 (900 Amps)

10K

.5 1 3 5 10 30 50 100 300 500 1K 3K 5K

Amps X 10 Bus7 (Nom. kV=0.48, Plot Ref. kV=0.48)

.01 .1 1 10 100 .03 .05 .3 .5 3 5 30 50 300 500

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ETAP Star 12.0.0C

Star488

Project:

Location:

Contract:

Engineer:

Filename: C:\ETAP 1200\star1\star2.OTI

Date: 11-20-2013

SN:

PT-BIRU

Rev: Base

Fault: Phase

CB3

Cable5

1-3/C 16

Mtr1

34 HP

Mtr1

34 HP

Cable5

1-3/C 16

CB3

(24)

CB3

ABB SACE PR221 (T2)

Sensor = 100

LT Pickup = 0.52 (52 Amps)

LT Band = 3s

ST Pickup = 10 (1000 Amps)

ST Band = 0.25s (I^x)t = IN

Inst. Pickup = 9 (900 Amps)

CB2

ABB SACE PR111

Sensor = 800

LT Pickup = 0.7 (560 Amps)

LT Band = Curve A

ST Pickup = 1 (800 Amps)

ST Band = Curve C (I^x)t = OUT

Inst. Pickup = 12 (9600 Amps)

CB4

ABB SACE PR221 (T2)

Sensor = 100

LT Pickup = 0.68 (68 Amps)

LT Band = 3s

ST Pickup = 1 (100 Amps)

ST Band = 0.1s (I^x)t = IN

Inst. Pickup = 1 (100 Amps)

10K

.5 1 3 5 10 30 50 100 300 500 1K 3K 5K

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.01 .1 1 10 100 .03 .05 .3 .5 3 5 30 50 300 500

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ETAP Star 12.0.0C

Star495

Project:

Location:

Contract:

Engineer:

Filename: C:\ETAP 1200\star1\star2.OTI

Date: 11-20-2013

SN:

PT-BIRU

Rev: Base

Fault: Phase

Bus6 CB2 CB3 CB4 Bus6 CB3 CB2 CB4

(25)

Cable4

Ampacity

Cable4 - P

OC1

GE Multilin 750/760 CT Ratio 75:5 Inst = 20 (0.05 - 20 xCT Sec) Time Delay = 0.25 s

Relay2 - P - 51

OC1

GE Multilin 750/760 CT Ratio 75:5

ANSI - Extremely Inverse

Pickup = 0.92 (0.05 - 20 xCT Sec) Time Dial = 11.94 3x = 7.87 s, 5x = 2.95 s, 8x = 1.5 s

T1

400 kVA (Secondary) 4 %Z Delta-Wye Resistor Grd Curve Shift = 1

Cable3 - P

T1

Inrush

CB2

ABB SACE PR111 Sensor = 800 LT Pickup = 0.7 (560 Amps) LT Band = Curve A ST Pickup = 1 (800 Amps) ST Band = Curve C (I^x)t = OUT Inst. Pickup = 12 (9600 Amps)

10K

.5 1 3 5 10 30 50 100 300 500 1K 3K 5K

Amps X 10 Bus3 (Nom. kV=6.6, Plot Ref. kV=6.6)

.01 .1 1 10 100 .03 .05 .3 .5 3 5 30 50 300

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ETAP Star 12.0.0C Star494 Project: Location: Contract: Engineer:

Filename: C:\ETAP 1200\star1\star2.OTI

Date: 11-20-2013 SN: PT-BIRU Rev: Base Fault: Phase ± Bus3 CB1 Cable3 1-3/C 70 T1 400 kVA Cable4 2-3/C 150 CB2 I> Relay2 Bus3 CB1 Cable3 1-3/C 70 Cable4 2-3/C 150 T1 400 kVA Relay2 CB2