Schweitzer Engineering Laboratories SEL-300G Instruction Manual Download

Page: 281 / 728

Installation

5-29

SEL-300G Instruction Manual

Date Code 20060731

ALARM

OUT106

OUT105

OUT104

OUT107

OUT103

OUT102

OUT101

OLA

INP

OUT

DWG: M300G096

JMP23

SERI

-4

)

-2

)

-2

)

JMP1

JMP2

-2

)

PUSH

TTO

R-I/O

CONNE

ANA

NNECT

CD CO

RAST

ADJUST

J10

CLO

J8/

Figure 5.26: Jumper, Connector, and Major Component Locations on the

SEL-300G Relay Main Board (All Models)

Summary of Contents for SEL-300G

Page 1: ...SEL 300G Multifunction Generator Relay Instruction Manual 20060731 PM300G 01 NB ...

Page 2: ...ement CAUTION There is danger of explosion if the battery is incorrectly replaced Replace only with Ray O Vac no BR2335 or equivalent recommended by manufacturer Dispose of used batteries according to the manufacturer s instructions ATTENTION Il y a un danger d explosion si la pile électrique n est pas correctement remplacée Utiliser exclusivement Ray O Vac No BR2335 ou un équivalent recommandé pa...

Page 3: ...RATION SECTION 10 SERIAL PORT COMMUNICATIONS AND COMMANDS SECTION 11 EVENT REPORTS AND SER FUNCTIONS SECTION 12 MAINTAIN AND TROUBLESHOOT RELAY SECTION 13 DIFFERENTIAL ELEMENT SETTINGS SECTION 14 APPENDICES Appendix A Firmware and Manual Versions Appendix B Firmware Upgrade Instructions Appendix C SEL Distributed Port Switch Protocol Appendix D Configuration Fast Meter and Fast Operate Commands Ap...

Page 4: ......

Page 5: ...upply and Optoisolated Input DC Voltages 1 11 Serial Communication Connections typical 1 12 SEL 5801 Cable Selector Software 1 13 Relay Specifications and Options 1 13 General 1 13 Processing Specifications 1 15 Relay Element Setting Ranges and Accuracies 1 15 TABLES Table 1 1 SEL 300G Relay Instruction Manual Task Map 1 1 Table 1 2 SEL 300G Relay Models 1 4 Table 1 3 SEL 300G Relay Hardware Model...

Page 6: ......

Page 7: ...on Example AC and DC Connection Diagrams Appendix H Differential Connection Diagrams Calculate Relay Element Settings Section 2 Relay Element Settings Section 13 Differential Element Settings Section 6 Enter Relay Settings Setting Sheets Create SELOGIC Control Equations Settings Tripping Closing and Synch Check Settings Section 4 SELOGIC Control Equations Create Demand Meter DC Monitor Setting Gro...

Page 8: ...lose logic Synchronism checking function Local and remote control switches Front panel display configuration Inadvertent energization settings Protection alarms Relay self test alarms Breaker failure protection Tables detailing all Relay Word bits their definitions and applications Section 5 Installation describes How to mount and wire the SEL 300G Connections for numerous applications Explanation...

Page 9: ...1 Event Reports and SER Functions describes Standard 15 30 60 and 180 cycle event reports Sequential Events Recorder SER report Synchronism checking reports Section 12 Maintain and Troubleshoot Relay describes Relay maintenance testing philosophy Relay troubleshooting Section 13 Differential Element Settings describes Generator differential protection elements Logic and operating characteristics S...

Page 10: ...tion manual are shown in bold italics Section 1 Introduction and Specifications SEL 300G RELAY MODELS This instruction manual covers the following SEL 300G models Table 1 2 SEL 300G Relay Models Model Synch Check Differential Protection SEL 2600 Series Compatible Modbus Protocol Voltage Inputs Current Inputs 0300G0 No 87N No Optional VA VB VC VN or VAB VCB VN IA IB IC IN 0300G1 No 87 Optional Opti...

Page 11: ...U 6 8 Connectorized standard 5 1 5 2 5 8 5 11 0300G_W3 Panel 2U 6 8 Connectorized standard 5 1 5 3 5 8 5 11 0300G_YH Rack 3U 6 8 Connectorized standard 5 1 5 2 5 8 5 11 8 12 Connectorized standard or high current interrupting 0300G_Y3 Panel 3U 6 8 Connectorized standard 5 1 5 3 5 8 5 11 8 12 Connectorized standard or high current interrupting a Number of Optoisolated Input Output Contacts The mode...

Page 12: ...n and metering functions When differential protection is included three additional phase current measurements are required Neutral voltage for 100 percent stator ground protection is taken from the secondary of the grounding transformer The SEL 300G neutral voltage input is rated for application up to 300 Vac which means that for most applications an auxiliary voltage transformer will not be neces...

Page 13: ...ransformer Protection for Small and Medium Sized Machines With or without the differential elements you get large machine protection monitoring and control that is priced for application on nearly any size machine The SEL 300G offers you the freedom to benefit from integrated protection SER and event reporting high accuracy metering and breaker and dc monitoring functions without the installation ...

Page 14: ...re thresholds SEL 2600 Series SEL 300G Relay Generator Prime Mover Fiber Optic Port built into SEL 2600 Series SEL 2800 plugged on to any DB 9 connector As many as 12 RTD inputs plus one contact DWG M300G258b Up to 500 meters via single fiber optic cable SEL part number C805Z010VVX0003 3 meters Refer to the Model Option Table for additional cable choices Figure 1 4 Generator Thermal Protection Wit...

Page 15: ...IELD FIELD GND SEL 2812MR Fiber Optic Transceiver Fiber Optic Port ST Fiber Optic cable with ST connectorsa Exciter Vdc Rotor Iron Field Breakers Brushes Field Winding a Refer to the Model Option Table for cable choices Figure 1 5 Field Ground Protection With the SEL 300G Relay SEL 300G RELAY GENERATOR PROTECTION FEATURES The SEL 300G offers a full range of elements for generator protection such a...

Page 16: ...unctions outlined above the SEL 300G offers advanced measuring and monitoring capabilities not found on other generator relays Extensive High Accuracy Metering Capabilities Configurable Front Panel Display Replaces Separate Panel Meters Event Report and SER Reporting Advanced SELOGIC Control Equations Contact Inputs and Outputs Breaker Monitor Station Battery Monitor Two Independent Setting Groups...

Page 17: ...nterrupting Output Contacts SEL 300G purchased with the additional I O board may be further specified to include high current interrupting output contacts These contacts use an integrated gate bipolar junction transistor to interrupt contact current in a controlled manner This increases the contact interrupt rating prevents contact arcing and prevents the inductive voltage spike which occurs when ...

Page 18: ...ommunications Processor SEL 300G Relay 2 SEL 300G Relay 32 DATA AND TIME SYNCHRONIZATION CONNECTIONS PORT 2 Fiber Optic Cable C273AFZ or C273AF0 SEL 2810 Optical Cable Connection Metallic Cable Connection EIA 485 CONNECTIONS PORT 1 PORT 1 PORT 1 LOCAL CONNECTIONS Connect to the SEL Communications Processor once and communicate with any connected SEL Relay PORT 2 PORT 2 PORT F PORT F or Connect to ...

Page 19: ...nectorized Minimum 4 4 in lb 0 5 Nm Maximum 8 8 in lb 1 0 Nm Terminals or stranded copper wire Ring terminals are recommended Minimum temperature rating of 105 C AC Current Inputs 5 A Nominal 15 A continuous linear to 100 A symmetrical 500 A for 1 second 1250 A for 1 cycle Burden 0 27 VA 5 A 2 51 VA 15 A 1 A Nominal 3 A continuous linear to 20 A symmetrical 100 A for 1 second 250 A for 1 cycle Bur...

Page 20: ...ithin 5 ms of time source input Dimensions See Figure 5 1 for exact relay dimensions Operating Temperature 40 to 85 C 40 to 185 F Note LCD contrast impaired for temperatures below 20 C Weight 2U Rack Unit Minimum 13 5 lbs 6 2 kg Maximum 15 lbs 6 8 kg 3U Rack Unit Minimum 16 5 lbs 7 5 kg Maximum 18 5 lbs 8 4 kg Certifications ISO Relay is designed and manufactured using ISO 9001 certified quality p...

Page 21: ... loss of field and RTD elements Loss of field and out of step elements are processed two times per power system cycle and the RTD elements once in two seconds Relay Element Setting Ranges and Accuracies Phase Distance Element 21 5 A Model Reach 0 1 100 0 ohms Offset 0 0 10 0 ohms Steady State Impedance Accuracy 5 0 1 ohm Minimum Phase Current 0 5 A 1 A Model Reach 0 5 500 0 ohms Offset 0 0 50 0 oh...

Page 22: ...secondary Steady State Pickup Accuracy 5 A Model 0 025 A 3 1 A Model 0 005 A 3 Pickup Time 50 ms at 60 Hz Max Definite Time Delay Setting Range 0 02 999 90 s Maximum Definite Time Delay Accuracy 0 1 4 2 ms at 60 Hz Inverse Time Element Time Dial K 1 to 100 s Linear Reset Time 240 s fixed Inverse Time Timing Accuracy 4 50 ms at 60 Hz for I2 above 1 05 multiples of pickup Instantaneous Definite Time...

Page 23: ... the SEL 2664 is selected at 0 25 Hz Definite Time Delay 0 0 99 0 s Maximum Definite Time Delay Accuracy 0 5 5 ms Out of Step Element 78 5 A Model Forward Reach 0 1 100 0 ohms Reverse Reach 0 1 100 0 ohms Single Blinder Right Blinder 0 1 50 0 ohms Left Blinder 0 1 50 0 ohms Double Blinder Outer Resistance Blinder 0 2 100 0 ohms Inner Resistance Blinder 0 1 50 0 ohms Steady State Impedance Accuracy...

Page 24: ...tion Variable Timer Phase Overcurrent Pickup A secondary 5 A Model 0 25 100 00 A 1 A Model 0 05 20 00 A Steady State Pickup Accuracy 5 A Model 0 05 A 3 1 A Model 0 01 A 3 Time Delay Pickup and Dropout Timers 0 00 3000 00 s Maximum Definite Time Delay Accuracy 0 1 4 2 ms SELOGIC Control Equation Variable Timers 16 Time Delay Pickup and Dropout Timers 0 00 3000 00 s Maximum Definite Time Delay Accur...

Page 25: ...ng Characteristics 2 24 Reverse Low Forward Power Element 2 29 Element Description 2 29 Setting Calculation 2 31 Element Operating Characteristics 2 32 Loss of Field Element 2 33 Element Description 2 33 Setting Calculation 2 35 Element Operating Characteristics 2 38 Negative Sequence Overcurrent Elements 2 39 Element Description 2 39 Setting Calculation 2 41 Element Operating Characteristics 2 42...

Page 26: ...scription 2 96 Abnormal Frequency Protection Setting Calculation 2 98 Element Operating Characteristics 2 99 RTD Based Protection Models Compatible With SEL 2600 Series RTD Module 2 101 Element Description 2 101 Pole Open Logic 2 108 Element Description 2 108 Pole Open Logic Setting Calculation 2 109 Inadvertent Energization Protection 2 109 Breaker Failure Protection 2 109 Differential Protection...

Page 27: ... Element Logic Diagram 2 53 Figure 2 28 Neutral Ground Time Overcurrent Element 51NT 2 54 Figure 2 29 Residual Ground Time Overcurrent Element 51GT 2 54 Figure 2 30 U S Moderately Inverse Curve U1 2 56 Figure 2 31 U S Inverse Curve U2 2 56 Figure 2 32 U S Very Inverse Curve U3 2 56 Figure 2 33 U S Extremely Inverse Curve U4 2 56 Figure 2 34 U S Short Time Inverse Curve U5 2 57 Figure 2 35 I E C Cl...

Page 28: ...tings Date Code 20060731 SEL 300G Instruction Manual Figure 2 57 Abnormal Frequency Protection Logic Diagram 2 100 Figure 2 58 Winding RTD Trip Characteristics with BLMT 2 00 2 105 Figure 2 59 Pole Open Logic Diagram 2 108 ...

Page 29: ...y Self Tests Store Event Reports and SER Records Respond to Serial Port and Front Panel Commands Figure 2 1 Relay Processing Order Data Acquisition and Filtering The SEL 300G contains current and voltage transformers that step down the secondary voltage and current signals to levels that are safely handled by the internal electronic components The low level ac signals pass through analog low pass ...

Page 30: ...power system cycle Relay Word As the relay processes the protection element algorithms and evaluates the fixed logic if an element is picked up or a logic condition is true the relay changes the state of the associated Relay Word bit from a logical 0 to a logical 1 The relay uses these results to evaluate SELOGIC control equations defined in the relay settings SELOGIC Control Equations After evalu...

Page 31: ...Demand Ammeter Settings SELOGIC Control Equations SELOGIC Control Equation Latch Settings TRIP CLOSE ER Settings Output Settings Figure 2 2 SEL 300G Relay Setting Categories The relay is equipped with two protection element setting groups Group 1 and Group 2 Group 1 and Group 2 contain Enable settings for specific protection elements Settings to define element pickups and time delays SELOGIC contr...

Page 32: ...ER function settings Section 4 SELOGIC Control Equations describes SELOGIC control equations in general and the trip close event trigger and output contact control equations in particular Refer to Section 6 Enter Relay Settings for complete relay Settings Sheets showing each of the relay settings and their ranges in the order that they are entered PROTECTION ELEMENT SELECTION GUIDELINES The SEL 30...

Page 33: ...C 51C or 51V elements for backup protection b If neutral CT is available c If neutral PT is available RELAY CONFIGURATION SETTINGS The SEL 300G provides several settings that configure the relay for the particular generator being protected These settings appear in Group settings or in the Global settings Note All relay settings are made in secondary quantities amps volts ohms or watts Group 1 Grou...

Page 34: ... neutral voltages during ground faults will not exceed 300 Vac When directly connected set PTRN equal to the grounding transformer voltage ratio to one If an auxiliary transformer is connected between the grounding transformer secondary and the relay calculate PTRN by multiplying the grounding transformer ratio by the auxiliary transformer ratio to one In resistance grounded applications calculate...

Page 35: ...age kV CT phase current transformer ratio to one The relay directional power negative sequence overcurrent and differential elements use the INOM setting DWG M300G041 Generator Grounding Transformer a 1 IN VN CTRN CT Ratio to 1 PTRN a SEL 300G Relay partial Generator Grounding Transformer a 1 IN VN CTRN CT Ratio to 1 PTRN 2 a SEL 300G Relay partial 2 1 Optional Auxiliary Transformer Figure 2 3 PTR...

Page 36: ...e Abnormal Frequency Scheme N 1 6 E81AC 6 Enable Differential Protection G T N E87 G 0300G1 and 0300G3 Enable Ground Differential Protection Y N E87N Y 0300G0 and 0300G2 The settings above enable specific protection functions These settings are described fully elsewhere in this section or in Section 13 Differential Element Setting Enable SELOGIC control equations 0 16 ESV 6 Enable Set Reset Latch ...

Page 37: ...triggering condition Front Panel Time Out OFF 0 30 min FP_TO 15 The front panel LCD display will return to its default display after FP_TO minutes of no activity This feature improves the security of the front panel setting entry interface in the event that setting entry is interrupted Date Format MDY YMD DATE_F MDY The DATE_F setting allows you to change the relay date presentation format to eith...

Page 38: ...y is sufficient Additional description and examples are provided in Section 4 SELOGIC Control Equations Setting Group Selection SS1 1 SS2 0 SS1 and SS2 are SELOGIC control equations that help define when setting Group 1 and setting Group 2 are active With the settings shown above SS1 is set equal to logical 1 thus setting Group 1 always is active Section 3 Auxiliary Function Settings provides addi...

Page 39: ... step up transformer compensation and definite time delay You can select either mho distance or compensator distance as the operating principle of the distance elements Compensator distance elements are included for users who desire a different operating principle for the system backup distance relaying Compensator distance elements consist of phase to phase and three phase elements and are implem...

Page 40: ...stance element maximum reach along a line at the angle defined by the MTA1 setting Zone 1 Transformer Compensation Angle 0 30 30 degrees Z1CMP 0 Use the Z1CMP setting to compensate the phase distance element for the presence of a delta wye generator step up transformer between the generator and system When the element is not set to reach through the step up transformer set Z1CMP 0 When the element...

Page 41: ... the Zone 2 element definite time delay Minimum Power Factor OFF 0 98 to 0 50 firmware R320 MPF 0 80 Maximum Generator Load 0 5 to 3 0 per unit firmware R320 MXLD 1 2 See Setting Descriptions Load Encroachment on page 2 16 21P Element Torque Control SELOGIC control equation 21PTC 3PO The phase distance elements are enabled when the result of 21PTC equals logical 1 The elements are blocked when the...

Page 42: ...one 1 Compensator Time Delay 0 00 to 400 00 s Z1CD 0 00 The Z1CD setting defines the Zone 1 element definite time delay Zone 1 Phase Phase Current FD 0 5 to 170 0 A 50PP1 0 5 Set 50PP1 to its minimum value unless higher value is required by special condition Zone 1 Pos Seq Impedance Angle 90 to 45 deg ZANG1 88 Set ZANG1 equal to the angle of the transformer plus system impedance defined by the Zon...

Page 43: ...OP supervision is built into the element logic so it does not need to be added to the 21CTC SELOGIC control equation setting Relay Word Bits Relay Word Bit Function Description Typical Applications MPP1P Instantaneous Zone 1 Phase Phase Compensator Distance Element Pickup Indication Testing SER Event Triggering MABC1P Instantaneous Zone 1 Three Phase Compensator Distance Element Pickup Indication ...

Page 44: ...er Connection only required if Zone 1 or Zone 2 mho element is used and set to reach through the transformer Zone 1 and Zone 2 coordination time delay Generator Rated Minimum Power Factor and Maximum Emergency Loading Recommendations The phase distance elements provide backup phase fault protection for the system step up transformer and generator Zone 2 is typically set to reach far out onto the s...

Page 45: ...phase angle lags the generator phase to neutral voltage phase angle by 30 set ZnCMP 30 Note that the compensator distance elements inherently compensate for the step up transformer In order to obtain desired sensitivity it may be necessary to set the Zone 1 and or Zone 2 element reach very long Due to the long reach setting many phase distance relays would pick up during heavy load The SEL 300G di...

Page 46: ... Phase Distance Element Blocked R X DWG M300G212a Figure 2 5 Distance Element Operating Characteristics Z1P VAB VCA Z1R Z1O Settings _ 0 1 INOM IA VAB _ IAB VAB VBC IB Transformer Compensation Z1CMP 0 30 Zone 1 AB Mho Element Enable mAB1 Logic Similar to mAB1 mCA1 INOM CT Rating 1A or 5A Zone 2 Logic Similar to Zone 1 MTA1 DWG M300G230a 30 _ mBC1 Logic Similar to mAB1 Figure 2 6 Zone 1 Mho Element...

Page 47: ...Word Bits 60LOP 21PTC Z2P Z1P Z1D 0 21P2T 21P2P 21P1T 21P1P From above DWG M300G231a Relay Word Bits Z2D 0 ZLOAD Figure 2 7 Mho Distance Element Logic ang Z1 Acos MPF Z1 _ _ MPF OFF 0 125 _ INOM 3 MXLD VNOM ZLOAD Relay Word Bits DWG M300G254 I1 I2 Figure 2 8 Load Encroachment Logic ...

Page 48: ...element Zone 2 logic is similar to Zone 1 IAB 50PP1 EBUP DC 60LOP IBC ICA PP1F 3P1 PP1 ABC1F DWG M300G255 NOM I 0 1 NOM I 0 1 _ _ _ _ _ 1 2 Figure 2 9 Zone 1 Compensator Element Logic From above Relay Word Bits 21CTC 21C1T Z1CD 0 21C1P MABC1P MPP1P 21C2T Z2CD 0 21C2P MABC2P MPP2P 3P1 PP1 3P2 PP2 SELOGIC Setting DWG M300G256 Figure 2 10 Compensator Distance Element Logic ...

Page 49: ...e time characteristic and a definite time characteristic or as a dual level definite time element In any case the element provides a linear reset characteristic with a settable reset time This element also is supervised by the 24TC torque control setting The volts hertz tripping element has a percent travel operating characteristic similar to that employed by an induction disk time overcurrent ele...

Page 50: ...0 5 1 0 2 0 24IC 2 Level 2 Inverse Time Factor 0 10 10 0 s 24ITD 0 100 Level 2 Pickup Two 100 200 24D2P2 175 Level 2 Time Delay Two 0 00 400 00 s 24D2D2 0 1 The 24IP setting defines the pickup point of the inverse time portion of the operating time curve The SEL 300G asserts the 24C2 Relay Word bit without time delay when the machine volts hertz exceed the 24IP setting The 24IC setting defines the...

Page 51: ... SELOGIC control equation 24TC 60LOP Both volts hertz elements are disabled when the 24TC SELOGIC control equation equals logical 0 The elements are allowed to operate when the 24TC SELOGIC control equation equals logical 1 Typically the 24TC SELOGIC control equation should be set so the volts hertz elements are allowed to operate when there is no loss of potential 60LOP condition detected Other s...

Page 52: ...are usually used to trip the main generator breaker and the field breaker and transfer auxiliaries if needed Refer to Section 4 SELOGIC Control Equations for more detail and examples of tripping SELOGIC control equations Element Operating Characteristics Figure 2 11 and Figure 2 12 are similar to IEEE C37 102 1987 IEEE Guide for AC Generator Protection Figure 4 5 4 1 and Figure 4 5 4 2 01 0 1 1 0 ...

Page 53: ...e Minutes Generator Manufacturer s Recommended Protection Curve Transformer Limit Curve on Generator Voltage Base DWG M300G044 001 01 0 1 1 0 10 100 100 110 120 130 140 Volts Hertz 1000 24D2P2 118 24D2D2 1 2 s 24IP 108 Figure 2 12 Composite Inverse Definite Time Overexcitation Characteristic 24CCS ID ...

Page 54: ... 26 Relay Element Settings Date Code 20060731 SEL 300G Instruction Manual 5 0 PP p 1 100 IP 24 VNOM FNOM freq V ITD 24 t seconds Figure 2 13 Volts Hertz Inverse Time Characteristic 24IC 0 5 DWG M300G147 ...

Page 55: ...Relay Element Settings 2 27 SEL 300G Instruction Manual Date Code 20060731 1 PP p 1 100 24IP VNOM FNOM freq V 24ITD t seconds Figure 2 14 Volts Hertz Inverse Time Characteristic 24IC 1 DWG M300G148 ...

Page 56: ...2 28 Relay Element Settings Date Code 20060731 SEL 300G Instruction Manual 2 PP p 1 100 24IP VNOM FNOM freq V 24ITD t seconds Figure 2 15 Volts Hertz Inverse Time Characteristics 24IC 2 DWG M300G149 ...

Page 57: ...pplications generator motoring can quickly damage the turbine by causing overheating In applications of other prime movers motoring can cause mechanical damage and or unsafe operating conditions Antimotoring protection in the SEL 300G is provided by a reverse low forward power element This element measures the real power flow from the generator If the generator real power output drops below the el...

Page 58: ...The 32P2P defines the per unit power threshold As set above the 32P2 Relay Word bit asserts without time delay when the measured power falls below 0 02 per unit out of the machine The 32P2T Relay Word bit asserts 32P2D seconds after 32P2 asserts One per unit power is defined by the VNOM and INOM settings Set 32P2P OFF to disable the second threshold and hide the 32P2D setting 32 Element Torque Con...

Page 59: ...ing operations Use the Level 2 reverse low forward power element as a sequential tripping interlock or an overload element When the Level 2 element is applied as a sequential tripping interlock the 32P2P setting should be set using a low forward power value 5 to 10 percent of machine rating The element only should be permitted to cause a generator breaker trip after the prime mover trip has occurr...

Page 60: ...wer Threshold 32P2P Power Threshold 32P2 Operate Region Figure 2 17 Reverse Low Forward Power Element Operating Characteristic 32P1D 0 32P2D 0 32P2T Switches Closed when 32PTC Logical 1 DWG M300G056b 32P2 32P1T 32P1 32P2P 32P1P Measured Real Power 32PTC SELOGIC Settings Settings Relay Word Bits Figure 2 18 Reverse Low Forward Power Element Logic Diagram ...

Page 61: ... transient reactance Zone 1 is intended to operate with little time delay in the event of a loss of field under full load conditions Zone 2 reaches further and operates with a longer time delay Zone 2 is intended to trip for loss of field conditions that occur under light load conditions For compatibility with some existing electromechanical loss of field relays the SEL 300G Zone 2 element may be ...

Page 62: ...The 40Z1 Relay Word bit asserts without time delay when the measured positive sequence impedance falls within the Zone 1 mho circle defined by the offset and diameter settings The 40Z1D Relay Word bit asserts 40Z1D seconds after 40Z1 asserts Zone 2 Mho Diameter OFF 0 1 100 0 Ω 5 A relay 40Z2P 13 4 OFF 0 5 500 0 Ω 1 A relay Zone 2 Offset Reactance 50 0 50 0 Ω 5 A relay 40XD2 2 5 250 0 250 0 Ω 1 A r...

Page 63: ... Triggering 40Z2 Zone 2 Loss of Field Pickup Indication Event Triggering SER Triggering Testing 40Z2T Zone 2 Loss of Field Pickup With Definite Time Delay Tripping SER Triggering Setting Calculation Information Needed Generator direct axis reactance d X in secondary ohms Generator transient reactance d X in secondary ohms Generator rated line to line voltage in secondary volts VNOM setting Generat...

Page 64: ...or according to the generator manufacturer s recommendations seconds 0 5 40Z2D In this case the 40DIR setting is hidden Loss of field protection typically trips the main generator breaker and the field breaker When applying loss of field protection with a negative Zone 2 offset you can use the time delay Zone 1 and Zone 2 Relay Word bits 40Z1T and 40Z2T directly in the generator breaker and field ...

Page 65: ... control equations The traditional application of this scheme provides accelerated 0 25 second Zone 2 tripping in the event of an undervoltage condition occurring during the loss of field To achieve this accelerated tripping it is necessary to use a SELOGIC control equation variable and a positive sequence undervoltage element 27V1 The undervoltage element generally is set 80 percent of nominal vo...

Page 66: ...gs Date Code 20060731 SEL 300G Instruction Manual Element Operating Characteristics X R DWG M300G047a Zone 1 Zone 2 d X 40Z2P pu 1 0 40Z1P 2 d X Figure 2 20 Loss of Field Element Operating Characteristic Negative Zone 2 Offset ...

Page 67: ...13 1977 defined the ability of generators to withstand unbalance current in terms of negative sequence current The standard defines a continuous withstand capability as well as a short time capability expressed in terms of t I2 2 The SEL 300G provides a negative sequence definite time overcurrent element suitable for unbalance alarm application and an t I2 2 time overcurrent element for unbalance ...

Page 68: ...cent of nominal current to which the element must respond Set the 46Q2K setting equal to the generator rated t I2 2 short time current capability rating defined by the generator manufacturer The 46Q2 Relay Word bit asserts without time delay when the measured negative sequence current is greater than 46Q2P percent of INOM The 46Q2T Relay Word bit asserts in a time defined by the time overcurrent e...

Page 69: ...et the 46Q2P setting equal to or below the generator continuous unbalance current capability 12 8 46Q2P Set the 46Q2K setting equal to or below the generator short time negative sequence current capability 10 46Q2K If there are operating conditions under which you wish to prevent negative sequence overcurrent element operation define those conditions in the 46QTC torque control setting Normally th...

Page 70: ... Sequence Time Overcurrent Element Negative Sequence Current Calculation 46Q2K 46QTC SELOGIC Torque Control I2 Percent Calculation IA IB IC Setting PHROT INOM SELOGIC Setting 46Q2 46Q1 46Q2T 46Q2R Setting 46Q2P I2 percent Torque Control Switch Closed When 46QTC Logical 1 I2 A Relay Word Bits Figure 2 22 Negative Sequence Overcurrent Element Logic Diagram ...

Page 71: ...060731 1 0 01 0 1 1 10 100 10 100 1000 10000 I2 percent of INOM 1000 10000 46Q2K 100 75 50 40 30 20 10 5 2 46Q2P minimum 2 46Q2T Operating Time seconds DWG M300G150 2 op INOM 2 I K 2 Q 46 t seconds Figure 2 23 Negative Sequence Time Overcurrent Operating Characteristic ...

Page 72: ...former as shown in Section 5 Installation The 50P 50N and 50G elements may be set sensitively and applied for inadvertent energization protection as described in Section 4 SELOGIC Control Equations Where you use the relay to protect solidly grounded generators the phase neutral and residual overcurrent elements can all respond to stator ground faults in the mid and upper winding areas Overcurrent ...

Page 73: ...N When E50_87 N the elements listed above are inactive and their pickup and time delay settings are hidden and do not need to be entered Enable Time O C Elements Y N E51 Y Set E51 Y to enable the 51N and 51G inverse time overcurrent elements If none of these overcurrent elements is required set E51 N When E51 N the elements listed above are inactive and their settings are hidden and do not need to...

Page 74: ...und O C Pickup OFF 0 25 100 00 A 50R1P 8 00 Level 1 Residual Ground O C Time Delay 0 00 400 00 s 50R1D 30 00 Level 2 Residual Ground O C Pickup OFF 0 25 100 00 A 50R2P 8 00 Level 2 Residual Ground O C Time Delay 0 00 400 00 s 50R2D 30 00 Some none or all of the available definite time overcurrent elements may be applied for various protection indication and control functions as required by your ap...

Page 75: ...g this generator Each of the inverse time overcurrent elements is also equipped with a torque control setting When the equation result is logical 1 the element is permitted to operate When the result is logical 0 the element is not permitted to operate Use other protection elements logic conditions or control inputs to supervise these elements if desired Relay Word Bits Relay Word Bit Function Des...

Page 76: ...2T 87 Input Level 2 Neg Seq O C With Definite Time Delay Tripping Control SER Triggering 50R1 87 Input Level 1 Residual O C Indication Control 50R1T 87 Input Level 1 Residual O C With Definite Time Delay Tripping Control SER Triggering 50R2 87 Input Level 2 Residual O C Indication Control 50R2T 87 Input Level 2 Residual O C With Definite Time Delay Tripping Control SER Triggering 51N Neutral Time ...

Page 77: ...ry faults 3 0 51NTD U2 51NC Electromechanical reset emulation is not necessary and this element may be in service continuously so the torque control setting is logical 1 1 51NTC N 51RS You can determine the lower boundary of stator winding coverage provided by this element using the equation 100 CTRN N In 51NP 2 x where In generator ground fault current A primary N grounding transformer voltage ra...

Page 78: ...nable and apply those phase neutral and residual overcurrent elements that are required for your specific control scheme Pickup settings and time delays are governed by the requirements of the application Set the pickup of unused elements to OFF Element Operating Characteristics Pickup and Reset Time Curves Figure 2 24 and Figure 2 25 show pickup and reset time curves applicable to all instantaneo...

Page 79: ... Instruction Manual Date Code 20060731 0 0 2 0 4 0 6 0 8 1 1 2 1 4 1 6 1 8 1 2 2 3 4 5 6 7 8 9 10 Applied Current Multiples of Pickup Setting Reset Time Cycles Maximum Minimum Figure 2 25 Instantaneous Overcurrent Element Reset Time Curve ...

Page 80: ...de 50P1D 0 50P1T 50P1P 50P1 50P2D 0 50P2T 50P2P 50P2 IP IG Neutral Current Magnitude Residual Current Magnitude 50N1D 0 50N1T 50N1P 50N1 50N2D 0 50N2T 50N2P 50N2 IN 50G1D 0 50G1T 50G1P 50G1 50G2D 0 50G2T 50G2 IG IN IC IB IA DWG M300G059 Settings Relay Word Bits IP IN IG 50G2P Figure 2 26 Definite Time Overcurrent Element Logic Diagram ...

Page 81: ...ion Negative Sequence Current Calculation PHROT Setting IA87 IB87 IC87 IR I2 IP87 I287 IA87 Maximum 87 Input Phase Current 87 Input Negative Sequence Current Individual Phase Current Settings Relay Word Bits IB87 Individual Phase Current IC87 Individual Phase Current IR87 87 Input Residual Current 50H1D 0 50H2D 0 IA87 50H2PA IB87 50H2PB IC87 50H2PC 50H2A 50H2B 50H2T 50H2 50H2C Figure 2 27 87 Input...

Page 82: ...orque Control Switch Relay Word Bits Setting IN SELOGIC Setting DWG M300G050 Figure 2 28 Neutral Ground Time Overcurrent Element 51NT SELOGIC Torque Control 51GTC 51GR Reset 51GT Curve Timeout 1 Cycle Reset Timing Electromechanical Setting 51GRS N Y Torque Control Switch Position 51GTC State Open Closed Logical 0 Logical 1 51G Pickup 51GP Pickup 51GC Curve Type 51GTD Time Dial 51GRS Electromechani...

Page 83: ... of pickup current for operating time tp M 1 for reset time tr M 1 U S Moderately Inverse Curve U1 2 0 02 M 1 1 08 TD tr 1 M 0 0104 0 0226 TD tp I E C Class A Curve Standard Inverse C1 2 0 02 M 1 13 5 TD tr 1 M 0 14 TD tp U S Inverse Curve U2 2 2 M 1 5 95 TD tr 1 M 5 95 0 180 TD tp I E C Class B Curve Very Inverse C2 2 M 1 47 3 TD tr 1 M 13 5 TD tp U S Very Inverse Curve U3 2 2 M 1 3 88 TD tr 1 M ...

Page 84: ...0 150 125 60 50 30 25 15 12 5 6 5 3 2 5 DWG M300G098 Multiples of Pickup 100 90 80 70 60 50 40 30 20 10 Figure 2 31 U S Inverse Curve U2 0 50 1 00 2 00 3 00 4 00 5 00 6 00 8 00 10 00 12 00 15 00 10 20 30 40 50 60 70 80 90 100 1 2 3 4 5 6 7 8 9 1 2 3 4 5 6 7 8 9 01 02 03 04 05 06 07 08 09 100 1 2 3 4 5 6 7 8 9 5 6 7 8 9 90 80 70 60 50 40 30 20 10 Time in Seconds Time in Cycles 60 Hz 50Hz 6000 5000 ...

Page 85: ...00 500 300 250 150 125 60 50 30 25 15 12 5 6 5 3 2 5 DWG M300G115 Multiples of Pickup Figure 2 35 I E C Class A Curve Standard Inverse C1 0 05 0 10 0 20 0 30 0 40 0 50 0 60 0 70 0 80 0 90 1 00 10 20 30 40 50 60 70 80 90 100 1 2 3 4 5 6 7 8 9 1 2 3 4 5 6 7 8 9 01 02 03 04 05 06 07 08 09 100 1 2 3 4 5 6 7 8 9 5 6 7 8 9 90 80 70 60 50 40 30 20 10 Time in Seconds Time in Cycles 60 Hz 50Hz 6000 5000 30...

Page 86: ...and a voltage controlled phase time overcurrent element One of these elements typically is used for system phase fault backup protection to trip the generator in the event of an uncleared phase fault on the system side of the step up transformer The voltage controlled phase time overcurrent element 51C operates when its torque control setting 51CTC is equal to logical 1 Typically the torque contro...

Page 87: ...me O C Pickup OFF 0 50 16 00 A 5 A Model OFF 0 10 3 20 A 1 A Model 51CP 3 00 Voltage Controlled Time O C Curve U1 U5 C1 C5 51CC U2 Voltage Controlled Time O C Time Dial 0 50 15 00 U curves 51CTD 3 00 0 05 1 00 C curves Voltage Controlled Time O C EM Reset Y N 51CRS Y 51C Torque Control Setting SELOGIC control equation 51CTC 27PP1 60LOP When EBUP V Compensation Angle 0 30 30 deg 51VCA 0 Use the 51V...

Page 88: ...uipped with a torque control setting When the equation result is logical 1 the element is permitted to operate When the result is logical 0 the element is not permitted to operate Use other protection elements logic conditions or control inputs to supervise these elements if desired Relay Word Bits Relay Word Bit Function Description Typical Applications 51C Voltage Controlled Time O C Pickup Indi...

Page 89: ...on should be applied if the system phase overcurrent relays are induction disk relays otherwise electromechanical reset emulation is not necessary N 51CRS By definition this element should be torque controlled by an undervoltage element To prevent misoperation if a potential transformer fuse blows the element is also torque controlled by the 60LOP Relay Word bit 60LOP 27PP1 51CTC To enable and set...

Page 90: ...abled as long as there is not a loss of potential condition Overcurrent Tripping Because these overcurrent elements detect system faults of an enduring and potentially serious nature tripping is generally applied to the generator main breaker the field breaker the prime mover and the generator lockout relay Refer to Section 4 SELOGIC Control Equations for more detail and examples of tripping SELOG...

Page 91: ...rve Type 51VTD Time Dial 51VRS Electromechanical Reset Y N Settings 51VT Phase Time Overcurrent Element Curve Timing and Reset Timing max phase 51VP Torque Control Switch Relay Word Bits Setting IP SELOGIC Setting DWG M300G070a VP associated phase VNOM Setting Figure 2 41 Voltage Restrained Phase Time Overcurrent Element 51VT 0 25 0 50 1 00 0 25 0 50 1 00 51V Pickup per unit of 51VP setting Select...

Page 92: ... elements operate using the maximum of the measured phase voltage magnitudes Residual overvoltage elements operate using the sum of the three phase voltage measurements The positive and negative sequence overvoltage elements operate when their respective measurement exceeds their set threshold The phase to phase overvoltage element operates when the maximum phase to phase voltage exceeds the set t...

Page 93: ...equipped with a definite time delay If a definite time characteristic is desired use a SELOGIC control equation variable and its built in time delay pickup and dropout timers Relay Word Bits Relay Word Bit Function Description Typical Applications 27P1 Level 1 Phase Undervoltage Pickup Indication Control 27P2 Level 2 Phase Undervoltage Pickup Indication Control 27V1 Positive Sequence Undervoltage ...

Page 94: ...applied for torque control setting guidelines have been provided in sections associated with the controlled element Set the pickup of unused elements to OFF 27V1P V1 27V1 27PP1 VPP 27P2P 27P1P VP 27PP1 27P2 27P1 Voltage Magnitude Calculation Positive Sequence Voltage Calculation PHROT VA VB VC V1 VP V1 VPP minimum phase voltage magnitude positive sequence voltage magnitude minimum phase to phase v...

Page 95: ... Sequence Voltage Calculation Positive Sequence Voltage Calculation PHROT VA VB VC VG V1 V2 VP VG V1 V2 VPP maximum phase voltage magnitude residual voltage magnitude positive sequence voltage magnitude negative sequence voltage magnitude maximum phase to phase voltage magnitude DWG M300G053 Setting Relay Word Bits Setting 59PP2 59PP2 59QP V2 59Q Figure 2 44 Overvoltage Element Logic Diagram ...

Page 96: ...tional Description The SEL 300G provides a two zone function designed to detect stator winding ground faults on resistance and high impedance grounded generators The Zone 1 element 64G1 uses a fundamental frequency neutral overvoltage element that is sensitive to faults in the middle and upper portions of the winding The Zone 2 element 64G2 uses a third harmonic voltage differential function to de...

Page 97: ...generator terminal third harmonic voltage magnitude 64RAT third harmonic voltage ratio setting VN3 measured generator neutral third harmonic voltage magnitude 64G2P differential sensitivity setting If the difference between the measured third harmonic voltage magnitudes is greater than the 64G2P setting the relay asserts the 64G2 Relay Word bit Figure 2 45 illustrates the 64G1 and 64G2 element ope...

Page 98: ...cally uses neutral third harmonic undervoltage protection Setting Descriptions Enable 100 Stator Ground Protection Y N E64 Y Set E64 Y to enable the 100 percent stator ground protection elements If the relay is used to protect a solidly grounded machine these elements are not effective and should be disabled by setting E64 N When E64 N the 64G1 and 64G2 elements are hidden and their settings do no...

Page 99: ...elay Word Bits Relay Word Bit Function Description Typical Applications 64G1 Zone 1 Stator Ground Pickup Indication Event Triggering SER Triggering Testing 64G1T Zone 1 Stator Ground Time Delayed Trip Tripping SER Triggering 64G2 Zone 2 Stator Ground Pickup Testing 64G2T Zone 2 Stator Ground Time Delayed Trip Tripping SER Triggering T64G Zone 2 Pickup for Ground Near Generator Terminals Indication...

Page 100: ...eadsheet 64G Element Setting Worksheet which is available on the SEL Internet home page at www selinc com or by contacting the factory 1 Operate the generator at no load Using the SEL 300G METER command record the values of terminal and neutral third harmonic voltage secondary V load no voltage neutral harmonic Third ______ VN3_NL secondary V load no voltage terminal harmonic d ______Thir VP3_NL 2...

Page 101: ...sformer If 64G1P is less than the zero sequence voltage then the 64G1D setting must be longer than system ground fault clearing time to provide security Ensuring 64G2Min 15 and selecting 64G1P for at least 95 percent winding coverage will give an overlap of 10 percent or greater between the elements Third Harmonic Neutral Undervoltage Setting Recommendations use with open delta potentials The vast...

Page 102: ...y using the following equation PTRN 1 732 1000 kV 100 95 1 64G1P assuming 95 coverage where kV nominal machine line to line voltage kV primary PTRN Ngt Nat Ngt grounding transformer ratio to 1 Nat neutral voltage auxiliary transformer ration to 1 use 1 if relay VN input is connected directly to the grounding transformer secondary 64G1P must be greater than 0 5 V secondary Zero sequence voltage can...

Page 103: ...ation VP3 VN1 VN3 VP3 VA3 VC3 VB3 Third Harmonic Filter VA VC VB Fundamental Frequency Filter VN3 VN1 VN 64G1D 0 64G1 64G1P 64G2D 0 X 64G2 VP3 64RAT Positive Sequence Voltage Calculation PHROT V1 64GTC 64RAT 0 0 VN3 64G2P _ V1 V1 SELOGIC Setting Settings Voltages Relay Word Bits 64GTC DELTA_Y D 3 VNOM 0 8 T64G N64G DWG M300G055a Figure 2 46 64G Logic Diagram ...

Page 104: ...lue causes the 64F elements 64F1T or 64F2T to assert If there is no insulation deterioration there is no leakage path between the field winding to ground the insulation resistance value is extremely high In this situation however due to sensitivity limits the SEL 2664 calculates a very large insulation resistance value of 20 megohms As soon as the field winding insulation develops a breakdown to t...

Page 105: ...en the 64F elements are not calculated the 64F1 64F1T 64F2 and 64F2T Relay Word bits are set to zero 0 and all accumulated timer values are reset to zero 0 Setting Descriptions Table 2 2 SEL 2664 Module Configuration Settings Setting Prompt Setting Range Setting Name Factory Default 64F Input Option EXT NONE 64FOPT NONE When the SEL 2664 module is not in use set the 64F Input Option setting equal ...

Page 106: ...ted timer values are reset to zero 0 Table 2 4 64 Elements Torque Control Equation Setting Prompt Setting Range Setting Name Factory Default Hide Rule Usage Notes 64F Element Torque Control SELOGIC Equation SV 1 Hide if 64FOPT NONE Relay Word Bits 64FTC Field Ground Protection Torque Control Indication 64F1 Level 1 Field Ground Protection Element Instantaneous Pickup Control Indication 64F1T Level...

Page 107: ...est of the system It is imperative to detect and isolate an out of step condition as early as possible because the resulting high peak currents winding stresses and high shaft torques can be very damaging to the generator and the associated generator step up transformer The SEL 300G implements two out of step tripping schemes single blinder and double blinder Users can select whichever scheme suit...

Page 108: ... is only for trajectories traveling from right to left Out of step trajectories traveling from left to right traverse the protection zone in the reverse sequence i e from Area C to B to A The Relay Word bits assert in the same way whether trajectories travel from right to left or from left to right The single blinder scheme distinguishes between short circuit faults and out of step conditions by t...

Page 109: ... Z1 0 5 CYC 0 Latch the states of 78R1 and 78R2 on rising edge of SWING OOS Relay Word Bits 78R1 78R2 SWING 1 Latched 78R1 Latched 78R2 1 OOSTC 78TD 78TDURD OOST 1 Input Output DWG M300G234 Settings Half Cycle Processing Interval 78TD 78TDURD _ I1 0 0 5 CYC SEL OGIC Settings Figure 2 49 Single Blinder Scheme Logic Diagram ...

Page 110: ...s value is left at one the out of step element will not be controlled by any other conditions external to the element However users can block the operation of the 78 element for certain conditions such as the presence of excessive negative sequence currents by setting OOSTC to 46Q1 Refer to Section 4 SELOGIC Control Equations for a detailed discussion of SELOGIC control equations The trip delay ti...

Page 111: ...ions Figure 2 50 shows the elements set per the following recommendations A transient stability study normally provides adequate data for setting the elements and timers properly The out of step protection zone which is limited by mho element 78Z1 should extend from the generator neutral to the high side bushings of the generator step up transformer Normally set forward reach 78FWD at 2 3 times th...

Page 112: ...WD 78FWD Forward Reach 78REV Reverse Reach X d Generator Transient Reactance XT Transformer Reactance Zs System Impedance M N Total Impedance Between Generator and System S S Perpendicular Bisector of M N α and β Angle of Separation Between Generator and System Zs X 78Z1 XT d X β α Figure 2 50 Single Blinder Typical Settings ...

Page 113: ...d the associated generator step up transformer The SEL 300G implements two out of step tripping schemes single blinder and double blinder Users can select whichever scheme suits their application or can disable out of step protection 78R1 78R2 78R2 X R 78Z1 78R1 DWG M300G246 78REV 78FWD 78R2 78R1 78R1 Pickup 78R2 Pickup 78R2 Pickup 78R1 Pickup Note Diameter of 78Z1 78REV 78FWD Figure 2 51 Double B...

Page 114: ...dance trajectory exits the mho circle the rising edge triggered timer with 78TD pickup delay and 78TDURD dropout delay starts timing Relay Word bit OOST remains picked up for 78TDURD seconds after pickup delay time 78TD expires The double blinder scheme distinguishes between short circuit faults and out of step conditions by monitoring the length of time that the impedance trajectory stays between...

Page 115: ... 78R1 Re Z1 78R2 I1 50ABC OOS Relay Word Bits 78R1 78R2 SWING DWG M300G237 Settings 0 5 CYC 0 0 78Z1 OOSTC 78TD 78TDURD OOST 78D 0 Half Cycle Processing Interval Input Output 78TD 78TDURD 0 5 CYC 0 0 5 CYC 0 0 5 CYC SEL OGIC Settings Figure 2 52 Double Blinder Scheme Logic Diagram ...

Page 116: ... Control SELOGIC control equation OOSTC has a default setting of one If this value is left at one the out of step element will not be controlled by any other conditions external to the element However users can block operation of the 78 element for certain conditions such as the presence of excessive negative sequence currents by setting OOSTC to 46Q1 Refer to Section 4 SELOGIC Control Equations f...

Page 117: ...rator step up transformer impedance in secondary ohms Impedance of line or lines beyond the generator step up transformers if needed Convert all impedances to generator base kV Recommendations Figure 2 53 shows the elements set per the following recommendations The out of step protection zone which is limited by mho element 78Z1 should extend from the generator neutral to the high side bushings of...

Page 118: ...e out of step slip frequency accurately the outer and inner blinders must be separated appropriately For example assume that the highest out of step frequency encountered is five slip cycles per second which translates to 30 degrees per cycle 60 Hz Set the blinders with a 70 degree separation This separation translates to a positive sequence impedance travel time of 2 3 cycles between the two blin...

Page 119: ...edance M N Total Impedance Between Generator and System S S Perpendicular Bisector of M N α Angle of Separation Between Generator and System Measured at 78R2 γ Angle of Separation Between Generator and System Measured at 78R1 78REV 78R1 78R2 78R2 78R1 78FWD α γ S R S N Zs DWG M300G248c XT M X 78R2 Pickup 78R1 Pickup 78R1 Pickup 78R2 Pickup d X Figure 2 53 Double Blinder Typical Settings ...

Page 120: ...e off nominal frequency operating time accumulator function for additional protection Setting Descriptions Enable Frequency Elements N 1 6 E81 2 Set E81 to enable up to six over underfrequency elements When E81 N the frequency elements are disabled and their settings are hidden and do not need to be entered 81 ELEMENTS Phase Undervoltage Block 20 00 150 00 V 27B81P 20 00 Level 1 Pickup OFF 20 00 7...

Page 121: ... Level 5 Frequency Element With Time Delay Tripping Indication SER Triggering 81D6 Level 6 Frequency Element Pickup Testing 81D6T Level 6 Frequency Element With Time Delay Tripping Indication SER Triggering 27B81 Phase Undervoltage for Frequency Element Blocking Indication Event Triggering Testing Note Instantaneous frequency element Relay Word bits 81D1 81D6 should not be used for applications ot...

Page 122: ...e generator can be quickly resynchronized once the system condition causing the frequency disturbance has been corrected Refer to Section 4 SELOGIC Control Equations for more detail and examples of tripping SELOGIC control equations Element Operating Characteristics To Frequency Element Logic Figure 2 54 VA 27B81P Setting Voltages 27B81 Relay Word Bit DWG M300G063a VB VC _ _ _ 0 5 CYC VAB VBC VAC ...

Page 123: ...t 3 Setting E81 3 _ 81D4D 0 _ Over Frequency Under Frequency 81D4 81D4T 81D4P 81D4P FNOM 81D4P FNOM Frequency Element 4 Setting E81 4 _ 81D5D 0 _ Over Frequency Under Frequency 81D5 81D5T 81D5P 81D5P FNOM 81D5P FNOM Frequency Element 5 Setting E81 5 _ 81D6D 0 _ Over Frequency Under Frequency 81D6 81D6T 81D6P 81D6P FNOM 81D6P FNOM Frequency Element 6 Setting E81 6 Undervoltage Condition from Figure...

Page 124: ...t The accumulator values are nonvolatile and are retained through relay power off cycles The accumulator values may be viewed or reset using the relay serial port PROFILE command Setting Descriptions Enable Abnormal Frequency Scheme N 1 6 E81AC 6 Set E81AC 1 6 to enable the abnormal frequency operating time accumulator function If this function is not required set E81AC N When E81AC N the function...

Page 125: ...ation result is logical 1 We do not wish to accumulate time during generator startup or when the generator frequency cannot be accurately determined due to low voltage With the default setting off frequency operating time is accumulated when no phase voltage is below the 27B81P setting and the generator breaker is not open Relay Word Bits Relay Word Bit Function Description Typical Applications BN...

Page 126: ... Recommendations Steam turbine manufacturers can provide documentation showing turbine operating time limitations during abnormal frequency This documentation should show continuous operation at nominal frequency an area of restricted time of operation and an area of prohibited time of operation Define accumulator frequency bands and assign times to those bands that prevent the generator from oper...

Page 127: ...minutes Time seconds Frequency Hz Continuous Operation Restricted Operation Prohibited Operation TBND6 0 65 s LBND1 58 5 Hz LBND2 57 9 Hz LBND3 57 4 Hz LBND4 56 9 Hz LBND5 56 5 Hz LBND6 56 0 Hz Band 3 Band 4 Band 5 Band 6 Band 2 Accumulator Band 1 TBND5 2 0 s TBND4 12 0 s TBND3 120 0 s TBND2 600 0 s TBND1 5000 0 s UBND1 59 5 Hz Figure 2 56 Example Turbine Operating Limitations During Abnormal Freq...

Page 128: ...62ACC 0 TBND3 BND3A BND3T _ 62ACC 0 TBND4 BND4A BND4T _ 62ACC 0 TBND5 BND5A BND5T _ 62ACC 0 TBND6 BND6A BND6T System Frequency UBND1 LBND1 BANDS 2 LBND2 LBND3 LBND4 LBND5 BANDS 6 BANDS 3 BANDS 4 BANDS 5 ONLINE SELOGIC Setting E81AC Y DWG M300G065 Settings _ LBND6 Relay Word Bits Figure 2 57 Abnormal Frequency Protection Logic Diagram ...

Page 129: ...hresholds for the winding RTDs Setting Descriptions RTD Configuration Settings Setting Prompt Setting Range Setting Name Factory Default RTD Input Option EXT NONE RTDOPT NONE Temperature Preference Setting C F TMPREF F When RTDs are not used set the RTD Input Option setting equal to NONE When RTDs are connected to the inputs of the SEL 2600 series set the RTD Input Option setting equal to EXT The ...

Page 130: ...ient generator cooling air temperature set RTD Location equal to AMB Only one ambient temperature RTD is allowed For inputs connected to monitor temperatures of other apparatus set RTD Location equal to OTH RTD Type Settings Setting Prompt Setting Range Setting Name Factory Default RTD Type PT100 NI100 NI120 CU10 RTD1TY PT100 RTD Type PT100 NI100 NI120 CU10 RTD2TY PT100 RTD Type PT100 NI100 NI120 ...

Page 131: ...RTD Alarm Temperature OFF 32 482 F ALTMP3 OFF RTD Trip Temperature OFF 32 482 F TRTMP4 OFF RTD Alarm Temperature OFF 32 482 F ALTMP4 OFF RTD Trip Temperature OFF 32 482 F TRTMP5 OFF RTD Alarm Temperature OFF 32 482 F ALTMP5 OFF RTD Trip Temperature OFF 32 482 F TRTMP6 OFF RTD Alarm Temperature OFF 32 482 F ALTMP6 OFF RTD Trip Temperature OFF 32 482 F TRTMP7 OFF RTD Alarm Temperature OFF 32 482 F A...

Page 132: ...e Winding Trip Voting is not enabled The alarm and trip temperature settings for Bearing Ambient and Other RTD types function similarly except that trip voting is not available for Ambient and Other RTDs To disable any of the temperature alarm or trip functions set the appropriate temperature setting to OFF Only healthy RTDs can contribute temperatures to the alarm and trip functions The relay inc...

Page 133: ...rential Temperature setting setting Limit Bias Overload BLMT I 1 to limited is I INOM Current Nominal Current Load Sequence Positive I pu pu pu Figure 2 58 illustrates the Load Current Biased RTD trip characteristic with BLMT Overload Bias Limit set to 2 00 pu Amps Load Current Biased RTD Element Load Per Unit of Nominal Current Trip Temperature TRTMP TMPK TRTMP TRTMP TMPK TRTMP 2 TMPK 0 0 5 1 0 1...

Page 134: ...10 97 140 60 00 123 34 165 90 135 30 11 35 158 70 00 127 07 174 25 141 70 11 74 176 80 00 130 89 182 84 148 30 12 12 194 90 00 134 70 191 64 154 90 12 51 212 100 00 138 50 200 64 161 80 12 90 230 110 00 142 29 209 85 168 80 13 28 248 120 00 146 06 219 29 176 00 13 67 266 130 00 149 82 228 96 183 30 14 06 284 140 00 153 58 238 85 190 90 14 44 302 150 00 157 32 248 95 198 70 14 83 320 160 00 161 04 ...

Page 135: ...Temperature Trip Tripping Indication SER Triggering AMBALRM Ambient Temperature Alarm Indication SER Triggering OTHTRIP Other Temperature Trip Tripping Indication SER Triggering OTHALRM Other Temperature Alarm Indication SER Triggering RTDnAL n 1 to 12 RTDn Temperature Alarm Indication Testing RTDnTR n 1 to 12 RTDn Temperature Trip Indication Testing RTDFLT RTD Fault open shorted RTD or no communi...

Page 136: ... illustrates the logic 3POD 0 Relay Word Bits SELOGIC Setting 3PO 52A Setting Currents 50LP IA IB IC 50L DWG M300G062 Figure 2 59 Pole Open Logic Diagram Setting Descriptions Load Detection Phase Pickup OFF 0 25 100 00 A 5 A Model 50LP 0 25 OFF 0 05 20 00 A 1 A Model Three Pole Open Time Delay 0 00 1 00 s 3POD 0 00 The 50LP setting defines the pickup setting for the 50L overcurrent element The 3PO...

Page 137: ...or complete details and a setting example BREAKER FAILURE PROTECTION In some protection topologies the SEL 300G SELOGIC control equations and nondedicated overcurrent elements can provide breaker failure protection Refer to Section 4 SELOGIC Control Equations for complete details and a setting example DIFFERENTIAL PROTECTION Settings for the ground differential 87N elements provided by relay Model...

Page 138: ......

Page 139: ...onitor Function 3 15 Breaker Monitor Setting Example 3 18 Optoisolated Input Debounce Timers 3 21 Input Debounce Timers 3 22 Input Functions 3 23 Factory Settings Example 3 23 SER Trigger Settings and Alias Settings 3 24 SER Triggering 3 24 Making SER Trigger Settings 3 24 Alias Settings 3 25 TABLES Table 3 1 Definitions for Active Setting Group Indication Relay Word Bits SG1 and SG2 3 10 Table 3 ...

Page 140: ...V Circuit Breaker 3 17 Figure 3 10 SEL 300G Relay Breaker Maintenance Curve for a 13 8 kV Circuit Breaker 3 19 Figure 3 11 Operation of SELOGIC Control Equation Breaker Monitor Initiation Setting 3 20 Figure 3 12 Example Operation of Optoisolated Inputs IN101 Through IN106 All Models 3 21 Figure 3 13 Example Operation of Optoisolated Inputs IN201 Through IN208 Extra I O Board Models 0300G_1 and 03...

Page 141: ...s demand and peak demand metering for the following values Currents IA B C N Input currents A primary IG Residual ground current A primary IG 3I0 IA IB IC 3I2 Negative sequence current A primary Power MWA B C 3P Single when Delta_Y Y and three phase megawatts MVARA B C 3P Single when Delta_Y Y and three phase megavars Depending on enable setting EDEM these demand and peak demand values are thermal...

Page 142: ...Thermal Demand Current per unit 0 0 5 1 0 0 5 10 minutes Time 15 Input Current Magnitude per unit 0 0 5 1 0 0 5 10 minutes Time 15 0 9 67 33 Rolling Demand Meter Response EDEM ROL Thermal Demand Meter Response EDEM THM Step Current Input DMTC 15 minutes 0 Figure 3 1 Response of Thermal and Rolling Demand Meters to a Step Input setting DMTC 15 minutes ...

Page 143: ...3 1 middle to the step current input top In general as voltage VC across the capacitor in Figure 3 2 cannot change instantaneously the thermal demand meter response is not immediate either for changes in applied current magnitude The thermal demand meter response time is based on the demand meter time constant setting DMTC Note in Figure 3 1 the thermal demand meter response middle is at 90 percen...

Page 144: ... or the demand meters were reset The three 5 minute intervals in the sliding time window at Time 0 minutes each integrate into the following 5 minute totals 5 Minute Totals Corresponding 5 Minute Interval 0 0 per unit 15 to 10 minutes 0 0 per unit 10 to 5 minutes 0 0 per unit 5 to 0 minutes 0 0 per unit Rolling demand meter response at Time 0 minutes 0 0 3 0 0 per unit Time 5 Minutes The three 5 m...

Page 145: ...emand Meter Time Constant 5 10 15 30 60 min DMTC 15 Set the demand meter time constant Phase Demand Pickup OFF 0 50 16 00 A secondary 5 A model PDEMP 5 50 OFF 0 10 3 20 A secondary 1 A model Neutral IN Demand Pickup OFF 0 50 16 00 A secondary 5 A model NDEMP 1 00 OFF 0 10 3 20 A secondary 1 A model Residual 3I0 Demand Pickup OFF 0 5 16 A secondary 5 A model GDEMP 1 00 OFF 0 10 3 20 A secondary 1 A...

Page 146: ...eg Seq Demand Current Exceeds Pickup Indication Testing DWG M300G099 Demand Function Thermal EDEM THM or Rolling EDEM ROL 3I2 IG Demand Function Thermal EDEM THM or Rolling EDEM ROL IN Demand Function Thermal EDEM THM or Rolling EDEM ROL Demand Function Thermal EDEM THM or Rolling EDEM ROL reset demand demand reset demand reset demand reset residual max phase demand current IA DEM IB DEM IC DEM PD...

Page 147: ... in column Vdc in event reports Thus pickup settings DCLOP and DCHIP should be set to off DCLOP OFF DCHIP OFF they are of no real use If an event report is displayed with the EVE R command column Vdc will display the sampled ac voltage waveform rather than the average Setting Descriptions DC Battery Voltage Level 1 OFF 20 300 Vdc DCHIP OFF DC Battery Voltage Level 2 OFF 20 300 Vdc DCLOP OFF The DC...

Page 148: ... 0 if Vdc pickup setting DCHIP Create Desired Logic for DC Under and Overvoltage Alarming Pickup settings DCLOP and DCHIP are set independently Thus they can be set DCLOP DCHIP or DCLOP DCHIP Figure 3 5 shows the resultant dc voltage elements that can be created with SELOGIC control equations for these two setting cases In these two examples the resultant dc voltage elements are time qualified by ...

Page 149: ...when dc battery voltage stays between allowable limits If the relay loses power entirely Vdc 0 Vdc Vdc DCHIP then output contact OUT106 should logically deassert according to the bottom of Figure 3 5 and this is surely what happens for a total loss of power all output contacts deassert on total loss of power Output Contact Type Considerations a or b Consider the output contact type a or b needed f...

Page 150: ... 2 is the active setting group For example if setting Group 2 is the active setting group Relay Word bit SG2 asserts to logical 1 and SG1 deasserts to logical 0 Selecting the Active Setting Group The active setting group is selected with SELOGIC control equation settings SS1 and SS2 The serial port GROUP command see Section 10 Serial Port Communications and Commands The front panel GROUP pushbutto...

Page 151: ...hbutton SELOGIC control equation settings SS1 and SS2 have priority over the serial port GROUP command and the front panel GROUP pushbutton in selecting the active setting group If either one of SS1 or SS2 asserts to logical 1 neither the serial port GROUP command nor the front panel GROUP pushbutton can be used to switch the active setting group But if SS1 and SS2 both deassert to logical 0 the s...

Page 152: ... additional information on SELOGIC control equations and the latch control switch function SET5 IN104 LT5 rising edge of input IN104 AND NOT LT5 RST5 IN104 LT5 rising edge of input IN104 AND LT5 SS1 LT5 LT5 activate setting Group 1 SS2 LT5 NOT LT5 activate setting Group 2 DWG M300G084 LT5 IN104 set reset rising edge detect SET5 Relay Word Bit RST5 SELOGIC Setting SELOGIC Setting Relay Word Bit Fig...

Page 153: ... only change the state of the latch control switch once e g latch bit LT5 changes state from logical 0 to logical 1 For example in Figure 3 7 if LT5 logical 0 then input IN104 is routed to setting SET5 as discussed previously SET5 IN104 rising edge of input IN104 If input IN104 is then asserted for a few cycles by the SCADA contact see Pulse 1 in Figure 3 8 SET5 is asserted to logical 1 for one pr...

Page 154: ... IN104 shows the state of optoisolated input IN104 after the input pickup dropout debounce timer IN104D Thus when using Relay Word bit IN104 in Figure 3 7 and associated SELOGIC control equations keep in mind any time delay produced by the input pickup dropout debounce timer IN104D DWG M300G085 RST5 IN104 LT5 SET5 IN104 LT5 SG2 SG1 LT5 IN104 IN104 TGR rising edge Pulse 1 rising edge Pulse 2 rising...

Page 155: ...all setting group changes Exceeding the limit can result in an EEPROM self test failure An average of 10 setting groups changes per day can be made for a 25 year relay service life This requires that SELOGIC control equation settings SS1 and SS2 be set with care Do not use SS1 or SS2 settings that result in continuous cyclical changing of the active setting group Time setting TGR qualifies setting...

Page 156: ...ker maintenance information in Table 3 3 is plotted in Figure 3 9 Connect the plotted points in Figure 3 9 for a breaker maintenance curve To estimate this breaker maintenance curve in the SEL 300G breaker monitor three set points are entered Set Point 1 maximum number of close open operations with corresponding current interruption level Set Point 2 number of close open operations that correspond...

Page 157: ... Code 20060731 10 000 1000 2 3 4 5 6 7 8 9 100 2 3 4 5 6 7 8 9 10 2 3 4 5 6 7 8 9 1 2 3 4 5 6 7 8 9 50 40 30 20 10 Number of Close Open Operations DWG M300G127 kA Interrupted per Operation 5 Figure 3 9 Plotted Breaker Maintenance Points for a 13 8 kV Circuit Breaker ...

Page 158: ...ollowing settings are made from the breaker maintenance information in Table 3 3 and Figure 3 9 COSP1 10000 COSP2 150 COSP3 12 KASP1 1 2 KASP2 8 0 KASP3 20 0 Figure 3 10 shows the resultant breaker maintenance curve Breaker Maintenance Curve Details In Figure 3 10 note that set points KASP1 COSP1 and KASP3 COSP3 are set with breaker maintenance information from the two extremes in Table 3 3 and Fi...

Page 159: ...00 1000 2 3 4 5 6 7 8 9 100 2 3 4 5 6 7 8 9 10 2 3 4 5 6 7 8 9 1 2 3 4 5 6 7 8 9 50 40 30 20 10 Number of Close Open Operations kA Interrupted per Operation 5 KASP1 1 2 COSP1 10000 COSP2 150 KASP2 8 0 COSP3 12 KASP3 20 0 Figure 3 10 SEL 300G Relay Breaker Maintenance Curve for a 13 8 kV Circuit Breaker ...

Page 160: ...ion as the indication to read in current values The acquired current values are then applied to the breaker maintenance curve and the breaker monitor accumulated currents trips see references in previous paragraph In the factory default settings the SELOGIC control equation breaker monitor initiation setting is set BKMON TRIP1 TRIP1 is the logic output of Figure 4 6 Refer to Figure 3 11 When BKMON...

Page 161: ...iate terminal The optoisolated inputs in Figure 3 12 and Figure 3 13 operate similarly Relay Word Bits energized de energized States Relay Word Bit IN102 IN101 logical 1 logical 0 open closed Input States Optoisolated Inputs Opto isolated States Example Switch DWG M300G130 Debounce Built in Timers open closed IN104 de energized IN103 energized logical 0 logical 1 open open IN106 IN105 de energized...

Page 162: ...1 and 0300G_Y Input Debounce Timers See Figure 3 12 and Figure 3 13 Each input has settable pickup dropout timers IN101D through IN106D for input energization de energization debounce Note that a given time setting e g IN101D 0 50 is applied to both the pickup and dropout time for the corresponding input Time settings IN101D through IN106D are settable from 0 00 to 1 00 cycles The relay takes the ...

Page 163: ...t functions Input Functions Optoisolated inputs IN101 through IN106 receive their function by how their corresponding Relay Word bits IN101 through IN106 are used in SELOGIC control equations Factory Settings Example DWG M300G076 52a IN102 Generator Main Breaker 52a Generator Field Breaker IN101 SEL 300G Figure 3 14 Circuit Breaker Auxiliary Contacts Connected to Optoisolated Inputs IN101and IN102...

Page 164: ...e elements are Relay Word bits referenced in Table 9 3 The relay monitors each element in the SER lists every 1 4 cycle If an element changes state the relay time tags the changes in the SER For example setting SER1 contains Time overcurrent element pickups 51N and 51V Instantaneous overcurrent element 50N1 Thus any time one of these overcurrent elements picks up or drops out the relay time tags t...

Page 165: ...esired within the text string use an underscore _ instead Do not use the characters in a text string they are treated as spaces As an example you could set ALIAS1 as follows ALIAS1 IN101 GEN_MAIN_BKR CLOSED OPENED SER IN101 With these settings the SER function would record the date and time of each assertion and deassertion of the IN101 Relay Word bit in the SER record The record could look like t...

Page 166: ......

Page 167: ...Set Trip 4 14 Unlatch Trip 4 15 Generator Tripping 4 15 Generator Main Circuit Breaker Trip TR1 4 15 Generator Field Breaker Trip TR2 4 16 Prime Mover Trip TR3 4 16 Generator Lockout Relay Trip TR4 4 17 Factory Default Tripping Logic 4 17 Program Output Contacts for Tripping 4 19 Close Logic 4 20 Set Close 4 20 Unlatch Close 4 21 Settings Example 4 21 Defeat the Close Logic 4 22 Program an Output ...

Page 168: ... Table 4 3 Correspondence Between Local Control Switch Positions and Label Settings 4 40 Table 4 4 Correspondence Between Local Control Switch Types and Required Label Settings 4 42 Table 4 5 Relay Self Tests 4 57 Table 4 6 SEL 300G Relay Word Bits 4 59 Table 4 7 Relay Word Bit Definitions for Table 4 6 4 61 FIGURES Figure 4 1 Result of Falling Edge Operator on a Deasserting Underfrequency Element...

Page 169: ... Configured GEN SHUTDOWN Switch Drives Local Bit LB1 4 42 Figure 4 23 Remote Control Switches Drive Remote Bits RB1 Through RB16 4 44 Figure 4 24 Traditional Panel Light Installations 4 46 Figure 4 25 Rotating Text Display Replaces Traditional Panel Light Installations 4 47 Figure 4 26 Inadvertent Energization Logic Diagram 4 51 Figure 4 27 Generator Breaker Topology Where SEL 300G1 Relay Offers B...

Page 170: ......

Page 171: ...nel Display Configuration Settings Inadvertent Energization Logic With Example Settings Breaker Failure Protection Relay Self Testing Functions Additional SELOGIC Control Equation Application Examples Tables at the end of this section summarize all of the Relay Word bits available for making SELOGIC control equations Note Do not AND any of the out of step 78 element Relay Word bits with any of the...

Page 172: ...Element Settings The following Relay Word bits are the logic outputs of the neutral time overcurrent element 51N indication that the neutral current magnitude is above the level of the neutral time overcurrent pickup setting 51NP 51NT indication that the neutral time overcurrent element has timed out on its curve 51NR indication that the neutral time overcurrent element is fully reset Neutral Time...

Page 173: ... Examples Neutral Time Overcurrent Element 51NT Common uses for Relay Word bits 51N 51NT and 51NR 51N testing e g assign to an output contact for pickup testing trip unlatch logic 51NT trip logic 51NR used in testing e g assign to an output contact for reset indication Other Relay Word Bits The preceding example was for a neutral time overcurrent element demonstrating Relay Word bit operation for ...

Page 174: ...of the loss of field 40 element Relay Word bits The 78 and 40 elements are updated by the relay on opposite half power system cycles Therefore the logical AND of the two element types may not operate as expected SELOGIC Control Equation Operators SELOGIC control equation settings use logic similar to Boolean algebra logic combining Relay Word bits together using one or more of the six SELOGIC cont...

Page 175: ...rly to the rising edge operator but looks for Relay Word bit deassertion element going from logical 1 to logical 0 The falling edge operator in front of a Relay Word bit sees this logical 1 to logical 0 transition as a falling edge and asserts to logical 1 for one processing interval For example suppose the SELOGIC control equation event report generation setting is set with the detection of the f...

Page 176: ...n When the circuit breaker is open the 52b contact is closed If a 52a contact is connected to optoisolated input IN101 the SELOGIC control equation circuit breaker status setting 52A is set 52A IN101 Conversely if a 52b contact is connected to optoisolated input IN101 the SELOGIC control equation circuit breaker status setting 52A is set 52A IN101 NOT IN101 With a 52b contact connected if the circ...

Page 177: ...ctly to logical 1 e g 46QTC 1 directly to logical 0 e g SV6 0 Set SELOGIC Control Equations Directly to 1 or 0 SELOGIC control equations can be set directly to 1 logical 1 or 0 logical 0 instead of with Relay Word bits If a SELOGIC control equation setting is set directly to 1 it is always asserted on enabled If a SELOGIC control equation setting is set equal to 0 it is always deasserted off disab...

Page 178: ... control equations each relay setting group is equipped with 16 nondedicated SELOGIC control equation variables Each of these variables is equipped with a time delay pickup timer a time delay dropout timer and an independent definition equation The ESV setting allows you to select and set only the SELOGIC control equation variables required by your application Enable SELOGIC control equations 0 16...

Page 179: ...age is lost to the panel the latching relay output contact remains closed The state of a traditional latching relay output contact is changed by pulsing the latching relay inputs see Figure 4 3 Pulse the set input to close set the latching relay output contact Pulse the reset input to open reset the latching relay output contact Often the external contacts wired to the latching relay inputs are fr...

Page 180: ...l 1 latch bit LTn deasserts to logical 0 If both settings SETn and RSTn assert to logical 1 setting RSTn has priority and latch bit LTn deasserts to logical 0 Latch Control Switch Application Ideas Latch control switches can be applied to almost any control scheme The following is an example of using a latch control switch to perform local or remote generator shutdown through the SEL 300G Local Re...

Page 181: ... behave the same as traditional latching relays In a traditional installation if power is lost to the panel the latching relay output contact position remains unchanged Settings Change or Active Setting Group Change If individual settings are changed for the active setting group or one of the other setting groups or the active setting group is changed the states of the latch bits Relay Word bits L...

Page 182: ...ts IN101 through IN108 are used in settings SETn and RSTn the inputs have their own debounce timer that can help in providing the necessary time qualification see Section 3 Auxiliary Function Settings TRIP LOGIC The SEL 300G provides tripping logic to operate up to four external devices Table 4 2 shows the normal association between tripping settings and the apparatus controlled Figure 4 6 illustr...

Page 183: ...p Setting O C2 TAR R ULTR2 TARGET RESET Pushbutton Serial Port Com m ands SELO G IC Setting TR3 Trip Seal In and Unlatch Logic 0 TDU RD Rising Edge Detect O R 3 M inum um Trip D uration Tim er Unlatch Trip R elay W ord Bit TRIP3 SELO G IC Trip Setting O C3 TAR R ULTR3 TARGET RESET Pushbutton Serial Port Com m ands SELO G IC Setting TR4 Trip Seal In and Unlatch Logic 0 TDU RD Rising Edge Detect O R...

Page 184: ...ing edge on its input logical 0 to logical 1 transition if it is not already timing timer is reset The TDURD timer assures that the TRIP1 Relay Word bit remains asserted at logical 1 for a minimum of TDURD seconds If the TR1 SELOGIC control equation result is logical 1 beyond the TDURD time Relay Word bit TRIP1 remains asserted at logical 1 for as long as the output of OR 1 gate remains at logical...

Page 185: ...TRIPPING Generator Main Circuit Breaker Trip TR1 It is necessary to trip the Generator Main Circuit Breaker to isolate the generator from the system in response to many situations The SEL 300G elements and logic used to detect each of the conditions are summarized in the following table Generator Tripping Condition Indicated or Detected By Generator Manual Shutdown Local or Remote Bit Operation an...

Page 186: ...ement 51CT Voltage Restrained Time Overcurrent Element 51VT Mho Phase Distance Elements Z1P1T Z1P2T Generator Abnormal Operating Conditions Overexcitation Volts Hertz Element 24C2T Reverse Power Element 32P1T Loss of Field Elements 41Z1T or 40Z2T Generator Inadvertent Energization Inadvertent Energization Detected INADT Prime Mover Trip TR3 A prime mover trip is performed first during a manual gen...

Page 187: ...tance all of the devices are tripped in response to a generator fault To simplify the relay settings we have assigned nondedicated SELOGIC control equation variables to collect conditions that are used in more than one tripping equation These settings are summarized and described below Generator Fault Prolonged System Fault Inadvertent Energization and Manual Trips SELOGIC control equation variabl...

Page 188: ... TR2 TR3 or TR4 modify the equations for TR2 TR3 and TR4 to include Relay Word bit OOST TR1 SELOGIC Control Equation Term Asserts to Indicate SV3 Generator fault detected by elements set in SV3 control equation defined above SV4 Generator abnormal operating condition detected by elements set in SV4 SELOGIC control equation defined above 46Q2T Generator current unbalance trip 81D1T 81D2T Generator ...

Page 189: ...condition ULTR3 TR3 Generator Lockout Relay Tripping Settings As described above TR4 is used to define the generator lockout relay tripping conditions TR4 SV3 TR4 SELOGIC Control Equation Term Asserts to Indicate SV3 Generator fault detected by elements set in SV3 SELOGIC control equation defined above The trip signal can be released after the tripping conditions are no longer present as indicated...

Page 190: ...pen 52A logical 0 Closing is enabled CLEN logical 1 Then the CLOSE Relay Word bit can be asserted to logical 1 if any one of the following occurs The serial communications port CLOSE command is executed SELOGIC control equation setting CL goes from logical 0 to logical 1 rising edge transition If a serial port CLOSE command is executed or CL goes from logical 0 to logical 1 while the CLEN SELOGIC ...

Page 191: ...ore than 1 second SV5 CLOSE SV5PU 1 00 SV5DO 0 00 SV6 CLOSE SV6PU 0 00 SV6DO 30 00 The factory setting for the Close Dwell Timer setting is CLSD 0 00 s A longer CLSD timer setting would be applied if the close logic should remain armed for a time while the generator is synchronized e g synch check supervised closing See the Settings Sheets at the end of Section 6 Enter Relay Settings for setting r...

Page 192: ...the generator circuit breaker If a phase to phase connected VT is applied it should be connected between A and B phase or between B and C phase See Section 5 Installation for additional connection details The relay measures the system conditions through the VS input The relay measures generator frequency using the VA or VAB input Other generator voltage conditions are determined using the voltage ...

Page 193: ...nes the maximum acceptable percentage magnitude difference between the system and generator voltages prior to closing the generator breaker See Figure 4 10 and Figure 4 11 for more detail Generator Voltage High Required Y N GENV Y If your synchronization practice requires that the generator voltage be higher than the system voltage prior to closing the generator breaker set GENV Y If not set GENV ...

Page 194: ...ycle to initiate a close 25C assertion is timed so that if the slip remains constant and the breaker closes in TCLOSD seconds the breaker closes when the angle difference is equal to CANGLE Breaker Close Time 0 000 to 1 000 s TCLOSD 0 150 The TCLOSD setting predicts the amount of time that it will take for the generator main breaker to close from the instant the SEL 300G CLOSE contact closes to th...

Page 195: ...lip Breaker Time Compensated Phase Angle Within 25ANG1 Setting Indication Testing Control 25A2 Uncompensated Phase Angle Within 25ANG2 Setting Indication Testing Control 25C Initiate CLOSE to Match Target Close Angle Indication Testing Control CFA Close Failure Angle Condition Testing BKRCF Breaker Close Failed Control Testing 27VS Synch Undervoltage Pickup Indication Control Setting Calculation I...

Page 196: ... nominal line to neutral voltage is 67 V secondary then 25VLO 0 9 67 V secondary 60 3 V secondary 25VHI 1 05 67 V secondary 70 4 V secondary When a phase to phase connected synch VT is used the nominal phase to phase voltage would probably be approximately 120 V secondary leading to 25VLO 0 9 120 V secondary 108 V secondary 25VHI 1 05 120 V secondary 126 V secondary The 25VDIF setting defines a ma...

Page 197: ...xamples After the relay has been placed in service and the generator breaker closed you may wish to refine the 25RCF setting to account for transformer ratio errors Use the procedure in the Manually Refine the 25RCF Setting While the Generator is in Service section on page 4 29 to refine the 25RCF setting manually The 25SLO and 25SHI settings define the minimum and maximum acceptable slip frequenc...

Page 198: ...ference is less than the 25ANG1 setting The 25C Relay Word bit asserts when the slip compensated phase angle difference is equal to the CANGLE setting When you would like to initiate a generator breaker close timed so the phase angle difference will equal the CANGLE setting supervise the CLOSE initiation with the 25C Relay Word bit Settings for 25ANG1 25ANG2 and CANGLE depend on the requirements o...

Page 199: ...ency This value will be equal to the absolute value of 25SHI or 25SLO whichever is larger Angle Rotation _______ Set CFANGL less than or equal to CFANGL Damage Angle Angle Rotation CFANGL _______ The BSYNCH SELOGIC control equation should be set to block the synch check function whenever the generator circuit breaker is closed and during other conditions that you select Manually Refine the 25RCF S...

Page 200: ..._______ kV primary _______ degrees Using a scientific calculator and accounting for the phase angles subtract the second voltage from the first then note the magnitude of the phase to phase voltage V__ _________ kV primary When SYNCP VA VB or VC and DELTA_Y D record the magnitude of V1 V1 _________ kV primary Step 5 Calculate the secondary magnitude of VS by dividing the primary value noted in Ste...

Page 201: ...h check function is active BSYNCH logical 0 and an external automatic or manual synchronizer is operating to bring the generator into synchronism When the SEL 300G synch check function determines that the conditions are acceptable the 25C Relay Word bit asserts Since SV6T is already logical 1 SV6T 25C will assert to initiate the close as long as the CLSD timer has not expired Thus the CLSD timer s...

Page 202: ...nch Check Function Voltage Element Characteristic fA fS 59VS 59VP BSYNCH 3 0 CYC 0 SLIP fA fS Enable Slip Calculation SLIP Hz _ GENFHI GENFLO 25SHI _ 25SLO SF VEN VDIF 25VDIF OFF SELOGIC Setting Generator Frequency System Frequency Settings Relay Word Bits DWG M300G215a Note Enable Slip Calculation asserts when both fA and fS frequencies are within 20 70 Hz Figure 4 12 Synch Check Function Slip El...

Page 203: ... TCLOSD 360 TCLOSD _ _ 25ANG1 25C Relay Word Bits 25A2 25A1 UncompAng VS VP CFANGL CFA _ SF VEN Enable Angle Calculation Settings Uncompensated Angle Difference Ang VP Ang VS COMPA DWG M300G216 Figure 4 13 Synch Check Function Angle Elements Relay Word Bits 25C CLOSE 3PO CFA S R Q BKRCF 25A2 25A1 99 sec 0 RESET Relay Word Bit DWG M300G218a TCLOSD 0 Figure 4 14 Breaker Close Failure Logic Diagram ...

Page 204: ...1N 51C 51V 64G1 64G2 60LOP 81D1 81D2 81D1 81D2 BNDA BNDT INAD Note the rising edge operator in front of each of these elements Rising edge operators are especially useful in generating an event report at fault inception and then generating another later if a breaker failure condition occurs For example at the inception of a stator ground fault pickup indicator 64G1 asserts and an event report is g...

Page 205: ...ols the ALARM output contact Figure 4 16 is used for the following discussion examples The output contacts in Figure 4 16 and Figure 4 17 operate similarly Factory Settings Example In the factory SELOGIC control equation settings seven output contacts are used OUT101 TRIP1 Generator Main Circuit Breaker Trip OUT102 TRIP2 Generator Field Circuit Breaker Trip OUT103 TRIP3 Prime Mover Trip OUT104 TRI...

Page 206: ...When the relay is operational the ALARM output contact coil is energized The alarm logic circuitry keeps the ALARM output contact coil energized Depending on the ALARM output contact type a or b the ALARM output contact closes or opens as demonstrated in Figure 4 16 An a type output contact is open when the output contact coil is de energized and closed when the output contact coil is energized A ...

Page 207: ...IC Control Equations Settings Relay Word Bits Example Relay Word Bit States Output Contact Coil States Output Contacts and example contact types see Note 2 Output Contact Terminal States PULSE OUT101 OUT101 OUT101 logical 0 de energized OUT101 a open PULSE OUT102 OUT102 OUT102 logical 1 energized OUT102 a closed PULSE OUT103 OUT103 OUT103 logical 0 de energized OUT103 a open PULSE OUT104 OUT104 OU...

Page 208: ... OUT201 OUT201 OUT201 logical 0 de energized OUT201 a open PULSE OUT202 OUT202 OUT202 logical 1 energized OUT202 a closed PULSE OUT203 OUT203 OUT203 logical 0 de energized OUT203 a open PULSE OUT204 OUT204 OUT204 logical 0 de energized OUT204 a open PULSE OUT205 OUT205 OUT205 logical 0 de energized OUT205 b closed PULSE OUT206 OUT206 OUT206 logical 1 energized OUT206 b open PULSE OUT207 OUT207 OUT...

Page 209: ...ained logical 1 position The switch representation in this figure is derived from the standard Graphics Symbols for Electrical and Electronics Diagrams IEEE Std 315 1975 CSA Z99 1975 ANSI Y32 2 1975 4 11 Combination Locking and Nonlocking Switch Item 4 11 1 Figure 4 18 Local Control Switches Drive Local Bits LB1 Through LB16 The output of the local control switch in Figure 4 18 is a Relay Word bit...

Page 210: ...etting through the serial port using the command SET G View these settings using the serial port command SHO G see Section 6 Enter Relay Settings and Section 10 Serial Port Communications and Commands Local Control Switch Types Configure any local control switch as one of the following three switch types ON OFF Switch Local bit LBn is in either the ON LBn logical 1 or OFF LBn logical 0 position OF...

Page 211: ...MENTARY Switch ON OFF MOMENTARY Switch The local bit LBn is in either the ON LBn logical 1 or OFF LBn logical 0 position or is in the OFF LBn logical 0 position and pulses to the MOMENTARY LBn logical 1 position for one processing interval 1 4 cycle OFF position logical 0 MOMENTARY position DWG M300G145 Relay Word Bit LBn Logical 1 n 1 through 16 ON position Figure 4 21 Local Control Switch Config...

Page 212: ...s Local bit LB1 is used in a few of the factory SELOGIC control equation settings for manual generator shutdown Its corresponding local control switch position labels are set to configure the switches as OFF MOMENTARY switches Local Bit Label Settings Function LB1 NLB1 GEN SHUTDOWN trips prime mover and initiates generator main circuit breaker and field circuit breaker sequential trips CLB1 RETURN...

Page 213: ...hrough LB16 are retained if power to the relay is lost and then restored If a local control switch is in the ON position corresponding local bit is asserted to logical 1 when power is lost it comes back in the ON position corresponding local bit is still asserted to logical 1 when power is restored If a local control switch is in the OFF position corresponding local bit is deasserted to logical 0 ...

Page 214: ...remote control switches in Figure 4 23 are Relay Word bits RBn n 1 to 16 called remote bits Use these remote bits in SELOGIC control equations Any given remote control switch can be put in one of the following three positions ON logical 1 OFF logical 0 MOMENTARY logical 1 for one processing interval Remote Bit Application Ideas With SELOGIC control equations the remote bits can be used in applicat...

Page 215: ...dicating panel lights are turned on and off by circuit breaker auxiliary contacts front panel switches SCADA contacts etc They indicate such conditions as circuit breaker open closed protection elements enabled disabled Traditional Indicating Panel Meters Traditional indicating panel meters are wired to ac current and voltage transformers in series or parallel with SEL 300G ac inputs The panel met...

Page 216: ...ree phase power scaled in primary megawatts and megavars and the present generator output power factor Front Panel Frequency Display Y N FP_FR Y Setting to Y enables rotating display of measured generator frequency in hertz and measured dc battery voltage in volts Front Panel Current Differential Display Y N FP_87 N Setting to Y enables rotating display of measured generator differential input pha...

Page 217: ...ext displays available in the SEL 300G Each text display has two complementary screens e g GEN BKR CLOSED and GEN BKR OPEN available General Operation of Rotating Text Display Settings SELOGIC control equation display point setting DPn n 1 through 16 controls the display of corresponding complementary text settings DPn_1 displayed when DPn logical 1 DPn_0 displayed when DPn logical 0 Make each tex...

Page 218: ...s closed resulting in DP1 IN101 logical 1 This results in the display of corresponding text setting DP1_1 on the front panel display GEN BKR CLOSED Circuit Breaker Open In Figure 4 25 optoisolated input IN101 is de energized when the 52a circuit breaker auxiliary contact is open resulting in DP1 IN101 logical 0 This results in the display of corresponding text setting DP1_0 on the front panel disp...

Page 219: ...ting directly to 0 logical 0 or 1 logical 1 and the corresponding text setting For example if an SEL 300G is protecting a generator labeled Unit 1A the generator name can be continually displayed with the following settings DP5 1 set directly to logical 1 DP5_1 UNIT 1A displays when DP5 logical 1 DP5_0 blank This results in the continual display of text setting DP5_1 on the front panel display UNI...

Page 220: ...itions be true to arm Inadvertent Energization tripping by using the SELOGIC control equation AND operator Generator is de energized 50L 27V1 IN102 where 50L 50L sensitive phase overcurrent element is not picked up 27V1 positive sequence phase undervoltage element is picked up IN102 field circuit breaker auxiliary contact is open We need to add time delay pickup and dropout timers to this logic eq...

Page 221: ...t connected to the SEL 300G remove this term from the SV2 SELOGIC control equation The SV2DO timer defines that inadvertent energization protection will remain armed for 1 second after the 27V1 element deasserts due to reapplication of the generator field If you can parallel the generator within 1 second of reenergizing the field shorten the SV2DO timer setting INADPU must be set less than SV2DO N...

Page 222: ...aker Failure Logic Breaker failure time is defined by the SV7PU time delay pickup timer setting This timer starts when the SEL 300G TRIP1 Relay Word bit asserts or when external protection asserts the IN103 input if the breaker is closed 52A logical 1 or if the 87 input phase or residual overcurrent element is picked up 50H1 or 50R1 logical 1 By including the SV7 Relay Word bit in the SV7 SELOGIC ...

Page 223: ...0G165 SEL 300G1 Partial GEN 52 87 Inputs 3 3 Optional Step Up Transformer IN Input Figure 4 29 Generator Breaker Topology Where SEL 300G1 Relay Offers Breaker Failure and Breaker Flashover Protection In this topology the SEL 300G is able to measure directly current flowing in the generator breaker and step up transformer neutral circuit The SV7 SELOGIC control equation below creates a breaker fail...

Page 224: ...tion is latched in The SV7PU timer continues to run until the breaker opens 52A logical 0 and the measured current drops below the pickup setting of both overcurrent elements Assign the SV7T Relay Word bit to close an output contact which can then be connected to perform breaker failure lockout tripping In multibreaker applications or in applications where only the generator current is measured se...

Page 225: ...vercurrent protection You may use either the definite time element 46Q1T or the instantaneous pickup of the inverse time element 46Q2 to generate an alarm OUT107 46Q1T Loss of Potential 60LOP Because accurate relaying potentials are required by many of the protection elements the 60LOP function is used to supervise these functions The volts hertz element loss of field element directional power ele...

Page 226: ...ises above DCLOP or falls below DCHIP If dc voltage fails altogether the relay ALARM contact will close Relay Self Test Alarms The relay runs a variety of self tests As shown below many relay problems detected by self test cause a closure of the ALARM output contact Monitoring this contact is the single most important relay maintenance activity that you can perform The relay takes the following co...

Page 227: ...s the 5 V power supply every 10 seconds Failure 4 65 V 5 40 V Yes Latched 5 V REG Warning 4 75 V 5 20 5 25 V No Pulsed Measures the regulated 5 V power supply every 10 seconds Failure 4 50 V 5 40 5 50 V Yes Latched 12 V PS Warning 11 50 V 12 50 V No Pulsed Measures the 12 V power supply every 10 seconds Failure 11 20 V 14 00 V Yes Latched 15 V PS Warning 14 40 V 15 60 V No Pulsed Measures the 15 V...

Page 228: ... the nonvolatile copy of the relay settings every 10 seconds The following self tests are performed by dedicated circuitry in the microprocessor and the SEL 300G main board Failures in these tests shut down the microprocessor and are not shown in the STATUS report Micro processor Crystal Failure Yes Latched The relay monitors the microprocessor crystal If the crystal fails the relay displays CLOCK...

Page 229: ...0N1 50N1T 50N2 50N2T CC CL CLOSE ULCL 12 64GTC 64G1 64G1T 64G2 64G2T OOS 60LOP CLEN 13 BKMON BCW BCWA BCWB BCWC FAULT DCLO DCHI 14 81D1 81D2 81D3 81D4 81D5 81D6 3PO 52A 15 81D1T 81D2T 81D3T 81D4T 81D5T 81D6T 27B81 50L 16 ONLINE BND1A BND1T BND2A BND2T BND3A BND3T BNDA 17 TRGTR BND4A BND4T BND5A BND5T BND6A BND6T BNDT 18 TRIP TRIP1 TRIP2 TRIP3 TRIP4 OC1 OC2 OC3 19 TR1 TR2 TR3 TR4 ULTR1 ULTR2 ULTR3 ...

Page 230: ... WDGALRMg 53 RTDFLTg 2600INg 54 RTD4TRg RTD4ALg RTD3TRg RTD3ALg RTD2TRg RTD2ALg RTD1TRg RTD1ALg 55 RTD8TRg RTD8ALg RTD7TRg RTD7ALg RTD6TRg RTD6ALg RTD5TRg RTD5ALg 56 RTD12TRg RTD12ALg RTD11TRg RTD11ALg RTD10TRg RTD10ALg RTD9TRg RTD9ALg Not used a This Relay Word bit is replaced with in SEL 300G models without compensator distance element b This Relay Word bit is replaced with in SEL 300G models 03...

Page 231: ...ng Group 2 Selection SELOGIC control equation see Table 3 2 Indication 27P1 Level 1 phase instantaneous undervoltage element any phase to neutral voltage below pickup setting 27P1P see Figure 2 43 27P2 Level 2 phase instantaneous undervoltage element any phase to neutral voltage below pickup setting 27P2P see Figure 2 43 27PP1 Level 1 phase to phase instantaneous undervoltage element any phase to ...

Page 232: ...ltage V1 above pickup setting 59V1P see Figure 2 44 4 59Q Negative sequence instantaneous overvoltage element negative sequence voltage V2 above pickup setting 59QP see Figure 2 44 Tripping Control 59PP1 Level 1 phase to phase instantaneous overvoltage element any phase to phase voltage above pickup setting 59PP1 see Figure 2 44 40ZTC Loss of field element torque control see Figure 2 19 Indication...

Page 233: ...lement 46Q2T fully reset see Figure 2 22 Testing INAD Inadvertent Energization SELOGIC control equation see Figure 4 26 Indication 6 INADT Inadvertent Energization SELOGIC control equation timed out see Figure 4 26 Tripping 78R1 Out of step right blinder or outer resistance blinder see Figures 2 47 and 2 50 78R2 Out of step left blinder or inner resistance blinder see Figures 2 47 and 2 50 78Z1 Ou...

Page 234: ...lement 51NT timed out derived from 51N see Figure 2 28 Tripping Control 8 51NR Neutral time overcurrent element 51NT fully reset see Figure 2 28 Testing 51VTC Voltage restrained phase time overcurrent torque control see Figure 2 41 Indication 51V Voltage restrained phase time overcurrent element pickup maximum phase current above voltage adjusted pickup setting 51VP see Figure 2 41 Testing 51VT Vo...

Page 235: ...ng Control Indication 50G2 Level 2 residual instantaneous overcurrent element pickup residual current above 50G2P setting see Figure 2 26 Control Indication 10 50G2T Level 2 residual definite time overcurrent element timed out derived from 50G2 see Figure 2 26 Tripping Control Indication 50N1 Level 1 neutral instantaneous overcurrent element pickup neutral current above 50N1P setting see Figure 2 ...

Page 236: ...e 2 46 Tripping Control OOS Out of step element see Figures 2 48 and 2 51 Indication 60LOP Loss of relaying potential Indication Control 12 CLEN Close Enable SELOGIC control equation see Figure 4 8 Indication BKMON Breaker Monitor initiating control equation see Figure 3 11 Testing BCW BCW BCWA BCWB BCWC BCWA A phase breaker contact wear has reached 100 percent wear level see Breaker Monitor in Se...

Page 237: ...elay current see Figure 2 58 14 52A Generator Breaker Auxiliary Contact SELOGIC control equation see Figure 2 58 Indication Control 81D1T Level 1 definite time frequency element 81D1T timed out derived from 81D1 see Figure 2 54 81D2T Level 2 definite time frequency element 81D2T timed out derived from 81D2 see Figure 2 54 81D3T Level 3 definite time frequency element 81D3T timed out derived from 8...

Page 238: ...rmal frequency band 3 trip accumulated off frequency operating time in band 3 exceeds TBND3 setting see Figure 2 56 Indication Tripping 16 BNDA BNDA BND1A BND2A BND3A BND4A BND5A BND6A Testing Indication TRGTR Target Reset front panel button pressed Control BND4A Abnormal frequency band 4 alarm measured frequency between LBND3 and LBND4 settings see Figure 2 56 Testing Indication BND4T Abnormal fr...

Page 239: ...TR2 SELOGIC control equation to initiate TRIP2 see Figure 4 6 TR3 SELOGIC control equation to initiate TRIP3 see Figure 4 6 TR4 SELOGIC control equation to initiate TRIP4 see Figure 4 6 ULTR1 SELOGIC control equation to unlatch TRIP1 see Figure 4 6 ULTR2 SELOGIC control equation to unlatch TRIP2 see Figure 4 6 ULTR3 SELOGIC control equation to unlatch TRIP3 see Figure 4 6 19 ULTR4 SELOGIC control ...

Page 240: ...sserted see Figure 4 23 Control via serial port 23 RB9 RB10 RB11 RB12 RB13 RB14 RB15 RB16 Remote Bit 9 asserted see Figure 4 23 Remote Bit 10 asserted see Figure 4 23 Remote Bit 11 asserted see Figure 4 23 Remote Bit 12 asserted see Figure 4 23 Remote Bit 13 asserted see Figure 4 23 Remote Bit 14 asserted see Figure 4 23 Remote Bit 15 asserted see Figure 4 23 Remote Bit 16 asserted see Figure 4 23...

Page 241: ...control equation variable timer output SV3T asserted see Figure 4 2 25 SV4T SELOGIC control equation variable timer output SV4T asserted see Figure 4 2 Control SV5 SELOGIC control equation variable timer input SV5 asserted see Figure 4 2 SV6 SELOGIC control equation variable timer input SV6 asserted see Figure 4 2 SV7 SELOGIC control equation variable timer input SV7 asserted see Figure 4 2 SV8 SE...

Page 242: ...rted see Figure 4 2 Control SV13 SELOGIC control equation variable timer input SV13 asserted see Figure 4 2 SV14 SELOGIC control equation variable timer input SV14 asserted see Figure 4 2 SV15 SELOGIC control equation variable timer input SV15 asserted see Figure 4 2 SV16 SELOGIC control equation variable timer input SV16 asserted see Figure 4 2 Testing seal in functions etc SV13T SELOGIC control ...

Page 243: ...put contact indicating that relay failed or PULSE ALARM command executed see Figure 4 16 and Figure 4 17 OUT107 Output contact OUT107 asserted see Figure 4 16 OUT106 Output contact OUT106 asserted see Figure 4 16 OUT105 Output contact OUT105 asserted see Figure 4 16 OUT104 Output contact OUT104 asserted see Figure 4 16 OUT103 Output contact OUT103 asserted see Figure 4 16 OUT102 Output contact OUT...

Page 244: ...nce instantaneous overcurrent element pickup negative sequence current above 50Q1P setting see Figure 2 27 Control Indication 50Q1T Level 1 87 input negative sequence definite time overcurrent element timed out derived from 50Q1 see Figure 2 27 Tripping Control Indication 50Q2 Level 2 87 input negative sequence instantaneous overcurrent element pickup negative sequence current above 50Q2P setting ...

Page 245: ...any phase to phase voltage below pickup setting 27PP2 see Figure 2 43 SF Slip frequency within acceptable bounds see Figure 4 12 Control Indication VDIF Generator and system voltage difference within acceptable bounds see Figure 4 10 GENVHI Generator voltage greater than system voltage see Figure 4 10 GENVLO Generator voltage less than system voltage see Figure 4 10 GENFHI Slip frequency greater t...

Page 246: ... asserted see Figure 3 13 Optoisolated input IN203 asserted see Figure 3 13 Optoisolated input IN202 asserted see Figure 3 13 Optoisolated input IN201 asserted see Figure 3 13 Control via optional optoisolated inputs 64FTC Field Ground Protection Torque Control see Figure 2 47 Indication 64F1 Level 1 Field Ground Protection Element Instantaneous Pickup Control Indication 64F1T Level 1 Field Ground...

Page 247: ...ent element pickup see Figure 2 27 50H2B IB87 phase instantaneous overcurrent element pickup see Figure 2 27 44 50H2C IC87 phase instantaneous overcurrent element pickup see Figure 2 27 Control Not used Not used Not used Not used Not used Not used Not used Not used Not used Not used Not used Not used 45 Not used 46 SET1 SET2 SET3 SET4 SET5 SET6 SET7 SET8 Set Latch Bit 1 see Figure 4 4 Set Latch Bi...

Page 248: ...e Figure 4 4 Reset Latch Bit 11 see Figure 4 4 Reset Latch Bit 12 see Figure 4 4 Reset Latch Bit 13 see Figure 4 4 Reset Latch Bit 14 see Figure 4 4 Reset Latch Bit 15 see Figure 4 4 Reset Latch Bit 16 see Figure 4 4 Control Latch Bits 50 LT1 LT2 LT3 LT4 LT5 LT6 LT7 LT8 Latch Bit 1 asserted see Figure 4 4 Latch Bit 2 asserted see Figure 4 4 Latch Bit 3 asserted see Figure 4 4 Latch Bit 4 asserted ...

Page 249: ...ng RTD temperatures exceed their trip or biased trip when RTDBIAS NONE setpoints BRGALRM asserts when any healthy bearing RTD temperature exceeds its alarm setpoint or biased alarm setpoint 52 WDGTRIP WDGALRM Winding Temperature Trip and Alarm WDGTRIP asserts when one or two when EWDGV Y healthy winding RTD temperatures exceed their trip or biased trip when RTDBIAS NONE setpoints WDGALRM asserts w...

Page 250: ... RTD6AL RTD6 Trip RTD6 Alarm 55 RTD5TR RTD5AL RTD5 Trip RTD5 Alarm RTD12TR RTD12AL RTD12 Trip RTD12 Alarm RTD11TR RTD11AL RTD11 Trip RTD11 Alarm RTD10TR RTD10AL RTD10 Trip RTD10 Alarm 56 RTD9TR RTD9AL RTD9 Trip RTD9 Alarm Tripping Indication The Open Command Relay Word bit OCn and Close Command Relay Word bit CC are already embedded in the Trip Logic see Figure 4 6 and Close Logic see Figure 4 8 r...

Page 251: ...r Jumpers 5 33 EIA 232 Serial Port Voltage Jumpers 5 34 Clock Battery 5 35 TABLES Table 5 1 Communication Cables to Connect the SEL 300G Relay to Other Devices 5 21 Table 5 2 Output Contact Jumpers and Corresponding Output Contacts 5 32 Table 5 3 Extra Alarm Output Contacts and Corresponding Controlling Jumpers 5 32 Table 5 4 Required Position of Jumper JMP23 for Desired Output Contact OUT107 Oper...

Page 252: ...rent Differential Protection 5 22 Figure 5 16 SEL 300G1 Relay AC Connection Example High Impedance Grounded Generator With Step Up Transformer Included in Differential Zone 5 23 Figure 5 17 SEL 300G0 Relay AC Connection Example Resistance Grounded Generator With Ground Differential Protection 87N 5 23 Figure 5 18 SEL 300G0 Relay AC Connection Example Solidly Grounded Generator With Ground Differen...

Page 253: ... mounting rack and provide additional space at the rear of the relay for applications where the relay might otherwise be too deep to fit Panel Mount We also offer the SEL 300G in a panel mount version for a clean look Panel mount relays have sculpted front panel molding that covers all installation holes see Figure 5 1 Cut your panel and drill mounting holes according to the dimensions in Figure 5...

Page 254: ...L 300G Instruction Manual Figure 5 1 SEL 300G Relay Dimensions and Panel Mount Cut Out To better use Figure 5 1 refer to Table 1 3 for rack unit height information on the SEL 300G models 2U or 3U screw terminal block or Connectorized option ...

Page 255: ...Installation 5 3 SEL 300G Instruction Manual Date Code 20060731 Figure 5 2 SEL 300G Relay Front Panel Drawings for Rack Mount Relays 2U and 3U Screw Terminal Block and Connectorized Versions ...

Page 256: ...5 4 Installation Date Code 20060731 SEL 300G Instruction Manual Figure 5 3 SEL 300G Relay Front Panel Drawings for Panel Mount Relays 2U and 3U Screw Terminal Block and Connectorized Versions ...

Page 257: ...Installation 5 5 SEL 300G Instruction Manual Date Code 20060731 Figure 5 4 SEL 300G0 Relay Rear Panel Drawings for Rack and Panel Mount Relays 2U and 3U Screw Terminal Block Version ...

Page 258: ...5 6 Installation Date Code 20060731 SEL 300G Instruction Manual Figure 5 5 SEL 300G1 Relay Rear Panel Drawings for Rack and Panel Mount Relays 2U and 3U Screw Terminal Block Version ...

Page 259: ...Installation 5 7 SEL 300G Instruction Manual Date Code 20060731 Figure 5 6 SEL 300G2 Relay Rear Panel Drawings for Rack and Panel Mount Relays 2U and 3U Screw Terminal Block Version ...

Page 260: ...5 8 Installation Date Code 20060731 SEL 300G Instruction Manual Figure 5 7 SEL 300G3 Relay Rear Panel Drawings for Rack and Panel Mount Relays 2U and 3U Screw Terminal Block Version ...

Page 261: ...Installation 5 9 SEL 300G Instruction Manual Date Code 20060731 Figure 5 8 SEL 300G0 Relay Rear Panel Drawings for Rack and Panel Mount Relays 2U and 3U Connectorized Version ...

Page 262: ...5 10 Installation Date Code 20060731 SEL 300G Instruction Manual Figure 5 9 SEL 300G1 Relay Rear Panel Drawings for Rack and Panel Mount Relays 2U and 3U Connectorized Version ...

Page 263: ...Installation 5 11 SEL 300G Instruction Manual Date Code 20060731 Figure 5 10 SEL 300G2 Relay Rear Panel Drawings for Rack and Panel Mount Relays 2U and 3U Connectorized Version ...

Page 264: ...5 12 Installation Date Code 20060731 SEL 300G Instruction Manual Figure 5 11 SEL 300G3 Relay Rear Panel Drawings for Rack and Panel Mount Relays 2U and 3U Connectorized Version ...

Page 265: ...00G_Y Wiring Harness Wiring Harness The SEL WA0300G_W and SEL WA0300G_Y Wiring Harnesses include all connectors necessary for relay installation All connectors requiring special termination come prewired from the factory Refer to the SEL WA0300G_W SEL WA0300G_Y Model Option Table which is available from the factory The SEL WA0300G_W Wiring Harness includes the following connectors not prewired 2 8...

Page 266: ... 1 CT shorting connector for current inputs IA IB IC and IN 1 connector for voltage inputs VA VB VC and VN 1 connector for POWER inputs and 1 spade connector for GROUND connection chassis ground In addition the wiring harness package also contains the following prewired connectors for specific models 1 CT shorting connector for current inputs IA87 IB87 and IC87 SEL 0300G1 and SEL 0300G3 1 connecto...

Page 267: ...Installation 5 15 SEL 300G Instruction Manual Date Code 20060731 Figure 5 12 SEL 300G Relay Connectorized Coding Top View Models 0300G_W and 0300G_Y ...

Page 268: ...r supply The control power circuitry is isolated from the relay chassis ground Plug the power supply connector into terminals Z25 and Z26 The connector locks in place upon insertion Refer to Section 1 Introduction and Specifications for power supply ratings The relay power supply rating is listed on the serial number sticker on the relay rear panel Models 0300G_0 and 000G_1 Connect control voltage...

Page 269: ...dard Output contacts are not polarity dependent High Current Interrupting Output Contacts Model 0300G_1 part numbers with a numeral 6 in bold below sample part number indicate high current interrupting output contacts on the extra I O board OUT201 through OUT212 0 3 0 0 G _ Y _ _ _ _ 6 X _ X Connectorized models 0 3 0 0 G _ 1 _ _ _ _ 6 X _ X screw terminal block models High current interrupting ou...

Page 270: ...Figure 5 20 Figure 5 22 and Figure 5 24 for typical CT wiring examples Refer to the serial number sticker on the relay rear panel for the nominal current ratings 5 A or 1 A for the phase IA87 IB87 IC87 and current inputs listed under label AMPS AC Current Transformer Inputs Connectorized models Models 0300G0 0300G1 0300G2 and 0300G3 Note the polarity dots above terminals Z01 Z03 Z05 and Z07 Refer ...

Page 271: ...attach the wire to the connector at the factory Potential Transformer Inputs Any of the phase voltage inputs can be connected to voltages up to 200 V continuous The neutral voltage input VN NN can be connected to voltages up to 300 V continuous The synch voltage input VS NS can be connected to voltages up to 200 V continuous Figure 5 14 through Figure 5 24 show examples of typical voltage connecti...

Page 272: ...munications and Commands for detailed cable diagrams for selected cables cable diagrams precede Table 10 4 Note Listing of devices not manufactured by SEL in Table 5 1 is for the convenience of our customers SEL does not specifically endorse or recommend such products nor does SEL guarantee proper operation of those products or the correctness of connections over which SEL has no control For examp...

Page 273: ... 2664 Field Ground Module SEL C805 Multimode 200 µm core diameter fiber optic cable with ST connectors or SEL C807 Multimode 62 5 µm core diameter fiber optic cable with ST connectors a A corresponding main board jumper must be installed to power the StarComm Modem with 5 Vdc 0 5 A limit from the SEL 300G See Figure 5 26 and Table 5 7 b Data Terminal Equipment c Data Communication Equipment d Refe...

Page 274: ...sformers 87 Input Current Transformers A B C C B A Z14 Z13 Z08 Z07 Z06 Z05 Z04 Z03 Z02 Z01 Z24 Z23 Z22 Z21 Z20 Z19 IC87 VN IN IC IB IA IB87 IA87 VA VC VB Z09 Z10 Z11 Z12 N Figure 5 14 SEL 300G1 Relay AC Connection Example High Impedance Grounded Generator With Current Differential Protection DWG M300G088 Generator Phase Input Current Transformers A B C C B A Z14 Z13 Z08 Z07 Z06 Z05 Z04 Z03 Z02 Z01...

Page 275: ...rmer and CT connections ratios A B C Z12 Z11 Z10 Z09 VC VA VB N Figure 5 16 SEL 300G1 Relay AC Connection Example High Impedance Grounded Generator With Step Up Transformer Included in Differential Zone Z05 Z04 Z03 Z02 Z01 Z06 DWG M300G090 Generator Z08 Z07 Z12 Z11 Z10 Z09 IN VC VA VB IC IB IA Z14 Z13 VN Optional VN connection provides 100 Stator Ground Protection A B C N Figure 5 17 SEL 300G0 Rel...

Page 276: ...300G0 Relay AC Connection Example Solidly Grounded Generator With Ground Differential Protection 87N Z05 Z04 Z03 Z02 Z01 Z06 DWG M300G093 Generator IC IB IA Z23 Z24 IC87 Z22 Z21 IB87 Z20 Z19 IA87 A B C Z14 Z13 Z08 Z07 VN IN Z12 Z11 Z10 Z09 VC VA VB N Figure 5 19 SEL 300G1 Relay AC Connection Example High Impedance Grounded Generator With Split Phase Current Differential Protection ...

Page 277: ...C87 VN IN IC IB IA IB87 IA87 VA VC VB A B C Z09 Z10 Z11 Z12 N Figure 5 20 SEL 300G1 Relay Applied Using Open Delta Potentials Generator Phase Input Current Transformers A B C C B A 52 to A B or C DWG M300G202 Z14 Z13 Z08 Z07 Z06 Z05 Z04 Z03 Z02 Z01 VN IN IC IB IA Z16 Z15 VS Z12 Z11 Z10 Z09 VC VA VB N Figure 5 21 SEL 300G2 Relay High Impedance Grounded Generator With Synch Check and Without Current...

Page 278: ...IA87 A B C Z14 Z13 Z08 Z07 VN IN Window CT Figure 5 22 SEL 300G1 Relay High Impedance Grounded Generator With Split Phase Self Balancing Differential Protection Z05 Z04 Z03 Z02 Z01 Z06 DWG M300G205 Generator Z08 Z07 Z12 Z11 Z10 Z09 IN VC VA VB IC IB IA A B C 52 SYNCP VBC Z16 Z15 VS N Figure 5 23 SEL 300G2 Relay Solidly Grounded Generator With Ground Differential 87N and Synch Check ...

Page 279: ...r With Open Delta PTs Step Up Transformer Included in Differential Zone and Synch Check DC DC IN101 IN102 IN103 IN104 IN105 IN106 OUT101 TRIP1 OUT102 TRIP2 OUT103 TRIP3 OUT104 TRIP4 OUT105 CLOSE OUT106 60LOP OUT107 Element Alarms ALARM Self Test Alarm TC TC TC 86 CC Gen Main 52A Field BKR 52A Breaker Failure Initiate Main Breaker TRIP 52A 52A Field Breaker TRIP Prime Mover Trip Gen Lockout Relay M...

Page 280: ...ve a main board in the top guides and Models 0300G_1 and 0300G_Y have an extra I O board below the main board Each board corresponds to a row of rear panel screw terminal blocks 5 On Connectorized versions remove the rear panel connectors that correspond to the circuit board you wish to remove by loosening the screws on either end of each connector Removal of the extra I O board also requires remo...

Page 281: ...JMP27 A B JMP26 A B JMP25 A B JMP24 A B JMP22 A B JMP21 JMP23 SERIAL PORT 1 EIA 485 SERIAL PORT 2 EIA 232 SERIAL PORT 3 EIA 232 JMP1 J1 JMP2 JMP6 A B C D µC U46 SERIAL PORT F EIA 232 R131 LEDs PUSHBUTTONS POWER I O CONNECTOR ANALOG CONNECTOR LCD CONTRAST ADJUST J10 B1 CLOCK BATTERY J8 J9 J7 Figure 5 26 Jumper Connector and Major Component Locations on the SEL 300G Relay Main Board All Models ...

Page 282: ...7 JMP19 JMP18 B B B B A OUT208 B A B OUT204 A B OUT203 A B OUT202 OPTOISOLATED INPUTS OUTPUT CONTACTS A B POWER I O CONNECTOR JMP20 JMP21 JMP22 JMP23 JMP24 JMP25 JMP26 JMP27 JMP28 OUT201 DWG M300G095 Figure 5 27 Jumper Connector and Major Component Locations on the SEL 300G Relay Extra I O Board Model 0300G_1 Screw Terminal Block Version ...

Page 283: ...OUT209 OUT207 OUT206 OUT205 JMP17 JMP19 JMP18 B B B OUT208 OUT204 OUT203 OUT202 OPTOISOLATED INPUTS OUTPUT CONTACTS POWER I O CONNECTOR JMP20 OUT201 DWG M300G257 Figure 5 28 Jumper Connector and Major Component Locations on the SEL 300G Relay Extra I O Board Model 0300G_Y Plug In Connector Version ...

Page 284: ...g Output Contacts SEL 300G Relay Model Number Output Contact Jumpers Corresponding Output Contacts Reference Figures All Models JMP21 JMP29 but not JMP23 ALARM OUT101 Figure 5 26 0300G_1 JMP17 JMP28 OUT212 OUT201 Figure 5 27 0300G_Y JMP17 JMP20 OUT212 OUT209 Figure 5 28 Extra Alarm Output Contact Control Jumper All the SEL 300G models have dedicated alarm output contacts labeled ALARM see Figure 5...

Page 285: ...ted ALARM output contact it will be in the opposite state of the dedicated ALARM output contact in a standard relay shipment In a standard relay shipment the dedicated ALARM output contact comes as a b type output contact and all the other output contacts including the extra alarm come as a type output contacts The output contact type for any output contact can be changed see preceding subsection ...

Page 286: ... 232 Serial Port Voltage Jumpers The jumpers listed in Table 5 7 connect or disconnect 5 Vdc to Pin 1 on the corresponding EIA 232 serial ports The 5 Vdc is rated at 0 5 A maximum for each port See Table 10 2 in Section 10 Serial Port Communications and Commands for EIA 232 serial port pin functions In a standard relay shipment the jumpers are OFF removed not in place so that the 5 Vdc is not conn...

Page 287: ...annot be recharged CAUTION There is danger of explosion if the battery is incorrectly replaced Replace only with Ray O Vac no BR2335 or equivalent recommended by manufacturer Dispose of used batteries according to the manufacturer s instructions If the relay does not maintain the date and time after power loss replace the battery Follow the instructions in the previous subsection Accessing the Rel...

Page 288: ......

Page 289: ... Setup 6 2 Terminal Emulation 6 2 Establish Communication 6 2 Setting Entry 6 2 Setting Entry Error Messages 6 3 Modify Settings via the Front Panel 6 6 Settings Sheets 6 9 TABLES Table 6 1 Serial Port SET Commands 6 1 Table 6 2 SET Command Editing Keystrokes 6 3 Table 6 3 Setting Interdependency Error Messages 6 4 FIGURES Figure 6 1 Front Panel SET Pushbutton Options Setting Sheets 6 8 ...

Page 290: ......

Page 291: ...ttings SET Command All settings All settings a View settings with the respective serial port SHOWSET commands SHO SHO G SHO R SHO P See SHO Command Show View Settings in Section 10 Serial Port Communications and Commands b Refer to Section 9 Front Panel Operation for detailed information on the front panel menus and screens and operator control pushbuttons c Refer to Appendix G ACSELERATOR QuickSe...

Page 292: ...age documentation for assistance in making these PC communication port configuration settings Establish Communication Note In this manual commands you type appear in bold uppercase SET Computer keys you press appear in bold brackets Enter Prepare to enter relay settings by connecting the PC equipped with serial port and terminal emulation software to the relay serial port using the correct communi...

Page 293: ... a see Figure 4 16 and the EN LED extinguishes while the relay is disabled The relay is disabled for as long as 15 seconds If changes are made to the Group settings for the inactive setting group see Table 6 1 the relay is not disabled while it saves the new settings The ALARM contact closes momentarily for b contact opens for an a see Figure 4 16 but the EN LED remains on while the new settings a...

Page 294: ...or increase the 25SLO setting This narrows the range of acceptable slip frequency and reduces the lead angle of the CLOSE signal under 120 degrees Zone 2 must fully encompass Zone 1 Loss of Field Function Increase the 40Z2P and or 40XD2 setting to make the Zone 2 element larger than the Zone 1 element Time dial setting out of range for selected curve family 51xTD Change the affected time dial sett...

Page 295: ...Pmax must be in the range 0 1 32 0 Current Differential Function Modify the O87P U87P or IRS1 setting to satisfy the requirement shown in the error message Overall SELOGIC setting size too large Try simplifying equations SELOGIC control equations Reduce the total amount of SELOGIC control equation space used by collecting terms or using single sets of parentheses PRE must be less than LER Event Le...

Page 296: ...ter Out of Step Function Single Blinder Scheme Increase the setting of 78R1 78R2 must be 5 and 100 of 78FWD or 78REV whichever is greater Out of Step Function Single Blinder Scheme Increase the setting of 78R2 Need one ambient RTD to be AMB biased RTD Configuration Set one RTDnLOC AMB Only one ambient RTD allowed RTD Configuration Set RTDnLOC to something other than AMB VNOM must be 140 V for DELT...

Page 297: ...uttons to maneuver within the settings list After finding the setting you wish to modify press the SELECT pushbutton Modify numeric settings by using the Left Right arrow pushbuttons to underline single digits then the Up Down arrow pushbuttons to change the digit similar to moving a thumbwheel Modify Y N enable settings by using the Up Down arrow pushbuttons to change the setting from Y to N and ...

Page 298: ...lobal settings View settings only PORT Set Show View and modify port settings View settings only 1 2 1 2 3 F PASS ACC BAC 2AC Modify Password Setting Exit Settings Enter Access Level 2 Password if Password Protection is enabled see Section 5 Installation Enter Access Level 2 Password if Password Protection is enabled Enter Access Level 2 Password if Password Protection is enabled Enter Access Leve...

Page 299: ...0 0 A 5 A model 0 2 2 0 A 1 A model INOM Protection Element Enables Enable Backup System Protection N D DC V C firmware R320 and higher N D V C firmware R320 EBUP Enable Load Encroachment Y N Applies to firmware R320 and higher hidden when EBUP N V or C ELE Enable Volts Hertz Protection Y N E24 Enable Synchronism Checking Y N Model 300G2 300G3 E25 Enable Undervoltage U V Protection Y N E27 Enable ...

Page 300: ...en when Z2R OFF MTA2 Zone 2 Transformer Compensation 0 30 30 degrees hidden when Z2R OFF Z2CMP Zone 2 Phase Distance Time Delay 0 00 to 400 00 seconds hidden when Z2R OFF Z2D Minimum Power Factor OFF 0 98 0 50 Applies to firmware R320 MPF Maximum Generator Load 0 5 3 0 per unit Applies to firmware R320 hidden when MPF OFF MXLD 21P Element Torque Control SELOGIC control equation 21PTC 21 Compensato...

Page 301: ...e Pickup 100 200 hidden when 24CCS OFF DD 24IP Level 2 Inverse Time Curve 0 5 1 2 hidden when 24CCS OFF DD 24IC Level 2 Inverse Time Factor 0 1 10 0 s hidden when 24CCS OFF DD 24ITD Level 2 Pickup One 100 200 hidden when 24CCS OFF ID I 24D2P1 Level 2 Time Delay One 0 00 400 00 s hidden when 24CCS OFF ID I 24D2D1 Level 2 Pickup Two 101 200 hidden when 24CCS OFF I 24D2P2 Level 2 Time Delay Two 0 00 ...

Page 302: ... Level 2 Phase to Phase U V Pickup OFF 0 1 200 0 V 27PP2 32 Elements hidden when E32 N Level 1 Power Threshold 0 0015 to 3 0000 pu 32P1P Level 1 Power Time Delay 0 01 400 00 s 32P1D Level 2 Power Threshold OFF 0 0015 to 3 0000 pu 32P2P Level 2 Power Time Delay 0 01 400 00 s hidden when 32P2P OFF 32P2D 32 Element Torque Control SELOGIC control equation 32PTC 40 Elements hidden when E40 N Zone 1 Mho...

Page 303: ...e O C Time Delay 0 00 400 00 s hidden when 50P2P OFF 50P2D Level 1 Neutral O C Pickup OFF 0 25 100 00 A 5 A model OFF 0 05 20 00 A 1 A model 50N1P Level 1 Neutral O C Time Delay 0 00 400 00 s hidden when 50N1P OFF 50N1D Level 2 Neutral O C Pickup OFF 0 25 100 00 A 5 A model OFF 0 05 20 00 A 1 A model 50N2P Level 2 Neutral O C Time Delay 0 00 400 00 s hidden when 50N2P OFF 50N2D Level 1 Residual O ...

Page 304: ...0Q2P OFF 50Q2D Level 1 Residual O C Pickup OFF 0 25 100 00 A 5 A model OFF 0 05 20 00 A 1 A model 50R1P Level 1 Residual O C Time Delay 0 00 400 00 s hidden when 50R1P OFF 50R1D Level 2 Residual O C Pickup OFF 0 25 100 00 A 5 A model OFF 0 05 20 00 A 1 A model 50R2P Level 2 Residual O C Time Delay 0 00 400 00 s hidden when 50R2P OFF 50R2D 51N Element hidden when E51 N Neutral Time O C Pickup OFF 0...

Page 305: ...ined Time O C Pickup 2 00 16 00 A 5 A model 0 40 3 20 A 1 A model 51VP Volt Restrained Time O C Curve U1 U5 C1 C5 51VC Volt Restrained Time O C Time Dial 0 50 15 00 U curves 0 05 1 00 C curves 51VTD Volt Restrained Time O C EM Reset Y N 51VRS 51V Element Torque Control SELOGIC control equation 51VTC Open Pole Element Three Pole Open Time Delay 0 00 1 00 s 3POD Load Detection Phase Pickup OFF 0 25 ...

Page 306: ...XT NONE 64FOPT Level 1 Pickup OFF 0 5 200 0 kOhms hidden when 64FOPT NONE 64F1P Level 1 Delay 0 0 99 0 s hidden when 64FOPT NONE or when 64F1P OFF 64F1D Level 2 Pickup OFF 0 5 200 0 kOhms hidden when 64FOPT NONE 64F2P Level 2 Delay 0 0 99 0 s hidden when 64FOPT NONE or when 64F2P OFF 64F2D 64F Element Torque Control SELOGIC control equation hidden when 64FOPT NONE 64FTC 78 Elements hidden when E78...

Page 307: ...E81 2 81D2P Level 2 Time Delay 0 03 400 00 s hidden when E81 2 or 81D2P OFF 81D2D Level 3 Pickup OFF 20 00 70 00 Hz hidden when E81 3 81D3P Level 3 Time Delay 0 03 400 00 s hidden when E81 3 or 81D3P OFF 81D3D Level 4 Pickup OFF 20 00 70 00 Hz hidden when E81 4 81D4P Level 4 Time Delay 0 03 400 00 s hidden when E81 4 or 81D4P OFF 81D4D Level 5 Pickup OFF 20 00 70 00 Hz hidden when E81 5 81D5P Leve...

Page 308: ...A 5 A model OFF 0 02 CTR CTRN to 3 00 A 1 A model 87N2P Level 2 Ground Differential Time Delay 0 00 to 400 00 s hidden when 87N2P OFF 87N2D 87N Element Torque Control SELOGIC control equation 87NTC 87 Elements for Model 0300G1 0300G3 hidden when E87 N XFMR High Side Winding L L Voltage OFF 1 0 1000 0 kV hidden when E87 G VWDGD XFMR GEN YY YDAC YDAB DACDAC DABDAB DABY DACY hidden when E87 G TRCON 8...

Page 309: ...RG AMB OTH NONE RTD2LOC RTD Location WDG BRG AMB OTH NONE RTD3LOC RTD Location WDG BRG AMB OTH NONE RTD4LOC RTD Location WDG BRG AMB OTH NONE RTD5LOC RTD Location WDG BRG AMB OTH NONE RTD6LOC RTD Location WDG BRG AMB OTH NONE RTD7LOC RTD Location WDG BRG AMB OTH NONE RTD8LOC RTD Location WDG BRG AMB OTH NONE RTD9LOC RTD Location WDG BRG AMB OTH NONE RTD10LOC RTD Location WDG BRG AMB OTH NONE RTD11...

Page 310: ...0 C ALTMP8 RTD Trip Temperature OFF 32 to 482 F or 0 to 250 C TRTMP9 RTD Alarm Temperature OFF 32 to 482 F or 0 to 250 C ALTMP9 RTD Trip Temperature OFF 32 to 482 F or 0 to 250 C TRTMP10 RTD Alarm Temperature OFF 32 to 482 F or 0 to 250 C ALTMP10 RTD Trip Temperature OFF 32 to 482 F or 0 to 250 C TRTMP11 RTD Alarm Temperature OFF 32 to 482 F or 0 to 250 C ALTMP11 RTD Trip Temperature OFF 32 to 482...

Page 311: ...n Variable SV2 SV2 SV2 Pickup Time 0 00 3000 00 s SV2PU SV2 Dropout Time 0 00 3000 00 s SV2DO SELOGIC Control Equation Variable SV3 SV3 SV3 Pickup Time 0 00 3000 00 s SV3PU SV3 Dropout Time 0 00 3000 00 s SV3DO SELOGIC Control Equation Variable SV4 SV4 SV4 Pickup Time 0 00 3000 00 s SV4PU SV4 Dropout Time 0 00 3000 00 s SV4DO SELOGIC Control Equation Variable SV5 SV5 SV5 Pickup Time 0 00 3000 00 s...

Page 312: ...e 0 00 3000 00 s SV12DO SELOGIC Control Equation Variable SV13 SV13 SV13 Pickup Time 0 00 3000 00 s SV13PU SV13 Dropout Time 0 00 3000 00 s SV13DO SELOGIC Control Equation Variable SV14 SV14 SV14 Pickup Time 0 00 3000 00 s SV14PU SV14 Dropout Time 0 00 3000 00 s SV14DO SELOGIC Control Equation Variable SV15 SV15 SV15 Pickup Time 0 00 3000 00 s SV15PU SV15 Dropout Time 0 00 3000 00 s SV15DO SELOGIC...

Page 313: ...T7 Reset Latch Bit LT7 SELOGIC control equation RST7 Set Latch Bit LT8 SELOGIC control equation SET8 Reset Latch Bit LT8 SELOGIC control equation RST8 Set Latch Bit LT9 SELOGIC control equation SET9 Reset Latch Bit LT9 SELOGIC control equation RST9 Set Latch Bit LT10 SELOGIC control equation SET10 Reset Latch Bit LT10 SELOGIC control equation RST10 Set Latch Bit LT11 SELOGIC control equation SET11...

Page 314: ...ion Time 0 00 400 00 s TDURD Trip Equation 1 SELOGIC control equation TR1 Unlatch Trip Equation 1 SELOGIC control equation ULTR1 Trip Equation 2 SELOGIC control equation TR2 Unlatch Trip Equation 2 SELOGIC control equation ULTR2 Trip Equation 3 SELOGIC control equation TR3 Unlatch Trip Equation 3 SELOGIC control equation ULTR3 Trip Equation 4 SELOGIC control equation TR4 Unlatch Trip Equation 4 SE...

Page 315: ... SELOGIC control equation OUT107 Output Contact Equations for Model 0300G_1 extra I O board Output Contact OUT201 SELOGIC control equation OUT201 Output Contact OUT202 SELOGIC control equation OUT202 Output Contact OUT203 SELOGIC control equation OUT203 Output Contact OUT204 SELOGIC control equation OUT204 Output Contact OUT205 SELOGIC control equation OUT205 Output Contact OUT206 SELOGIC control ...

Page 316: ... Settings Group Change Delay Group Change Delay 0 400 s TGR Group 1 Select Input SELOGIC control equation SS1 Group 2 Select Input SELOGIC control equation SS2 Breaker Monitor Settings Breaker Monitor Input SELOGIC control equation BKMON Close Open Set Point 1 max 1 65000 operations COSP1 Close Open Set Point 2 mid 1 65000 operations COSP2 Close Open Set Point 3 min 1 65000 operations COSP3 kA Int...

Page 317: ...setting subject to the specified character limit Enter NA to null a label Local Bit LB1 Name 14 characters NLB1 Clear Local Bit LB1 Label 7 characters setting hidden if NLB1 NA CLB1 Set Local Bit LB1 Label 7 characters setting hidden if NLB1 NA SLB1 Pulse Local Bit LB1 Label 7 characters setting hidden if NLB1 NA PLB1 Local Bit LB2 Name 14 characters NLB2 Clear Local Bit LB2 Label 7 characters set...

Page 318: ... characters setting hidden if NLB7 NA CLB7 Set Local Bit LB7 Label 7 characters setting hidden if NLB7 NA SLB7 Pulse Local Bit LB7 Label 7 characters setting hidden if NLB7 NA PLB7 Local Bit LB8 Name 14 characters NLB8 Clear Local Bit LB8 Label 7 characters setting hidden if NLB8 NA CLB8 Set Local Bit LB8 Label 7 characters setting hidden if NLB8 NA SLB8 Pulse Local Bit LB8 Label 7 characters sett...

Page 319: ...aracters setting hidden if NLB13 NA CLB13 Set Local Bit LB13 Label 7 characters setting hidden if NLB13 NA SLB13 Pulse Local Bit LB13 Label 7 characters setting hidden if NLB13 NA PLB13 Local Bit LB14 Name 14 characters NLB14 Clear Local Bit LB14 Label 7 characters setting hidden if NLB14 NA CLB14 Set Local Bit LB14 Label 7 characters setting hidden if NLB14 NA SLB14 Pulse Local Bit LB14 Label 7 c...

Page 320: ...ical 1 16 characters DP2_1 Display if DP2 logical 0 16 characters DP2_0 Display Point DP3 SELOGIC control equation DP3 Display if DP3 logical 1 16 characters DP3_1 Display if DP3 logical 0 16 characters DP3_0 Display Point DP4 SELOGIC control equation DP4 Display if DP4 logical 1 16 characters DP4_1 Display if DP4 logical 0 16 characters DP4_0 Display Point DP5 SELOGIC control equation DP5 Display...

Page 321: ... if DP11 logical 0 16 characters DP11_0 Display Point DP12 SELOGIC control equation DP12 Display if DP12 logical 1 16 characters DP12_1 Display if DP12 logical 0 16 characters DP12_0 Display Point DP13 SELOGIC control equation DP13 Display if DP13 logical 1 16 characters DP13_1 Display if DP13 logical 0 16 characters DP13_0 Display Point DP14 SELOGIC control equation DP14 Display if DP14 logical 1...

Page 322: ...ited by spaces or commas See Sequential Events Recorder SER Report in Section 11 Event Reports and SER Functions SER Trigger List 1 SER1 SER Trigger List 2 SER2 SER Trigger List 3 SER3 SER Trigger List 4 SER4 Relay Word Bit Aliases ALIAS EALIAS setting are hidden See Alias Settings in Section 3 Auxiliary Function Settings Enable ALIAS Settings 0 10 20 30 40 EALIAS ALIAS1 ALIAS2 ALIAS3 ALIAS4 ALIAS...

Page 323: ...00G Instruction Manual Date Code 20060731 SEQUENTIAL EVENTS RECORDER SETTINGS SERIAL PORT COMMAND SET R ALIAS20 ALIAS21 ALIAS22 ALIAS23 ALIAS24 ALIAS25 ALIAS26 ALIAS27 ALIAS28 ALIAS29 ALIAS30 ALIAS31 ALIAS32 ALIAS33 ALIAS34 ALIAS35 ALIAS36 ALIAS37 ALIAS38 ALIAS39 ALIAS40 ...

Page 324: ... 8 BITS Parity 0 E N Odd Even None PARITY Stop Bits 1 2 STOP Other Port Settings Time Out 0 30 minutes T_OUT Send Auto Messages to Port Y N AUTO Fast Operate Enable Y N FASTOP Other Port Settings Set T_OUT to the number of minutes of serial port inactivity for an automatic log out Set T_OUT 0 for no port time out If the event report length setting LER 180 cycles set the port time out setting T_OUT...

Page 325: ...rained Time Overcurrent 51V Element 7 74 Overvoltage 59 Elements 7 79 100 Stator Ground 64 Element 7 81 Out of Step 78 Element Single Blinder 7 89 Out of Step 78 Element Double Blinder 7 94 Over underfrequency 81 Elements 7 95 Ground Differential 87N Element 7 98 Current Differential 87 Elements 7 102 Differential Element Commissioning Worksheet 7 111 Check List 7 112 TABLES Table 7 1 Communicatio...

Page 326: ...ply Polarity Continuity Checks 7 8 Figure 7 7 Three Phase AC Connection Test Voltage Signals 7 14 Figure 7 8 Open Delta AC Potential Connection Test Voltage Signals 7 14 Figure 7 9 Three Voltage Source and Three Current Source Test Connections 7 19 Figure 7 10 Two Voltage Source and Three Current Source Test Connections 7 19 Figure 7 11 Generator Voltage and Current Relationships During a System P...

Page 327: ...ode 20060731 Figure 7 30 Out of Step Double Blinder Element Diameter and Blinder Tests 7 95 Figure 7 31 87N Test Connections 7 99 Figure 7 32 Percentage Restraint Differential Characteristic 7 103 Figure 7 33 Test Connections for Parallel Current Sources 7 110 ...

Page 328: ......

Page 329: ... system and all auxiliary equipment Verify control signal inputs and outputs Check breaker auxiliary inputs SCADA control inputs and monitoring outputs Use an ac connection check to verify that the relay current and voltage inputs are of the proper magnitude and phase rotation Brief fault tests ensure that the relay settings are correct It is not necessary to test every relay element timer and fun...

Page 330: ... Port Communications and Commands and Section 9 Front Panel Operation Low Level Test Interface The SEL 300G has a low level test interface between the calibrated input module and the separately calibrated processing module You may test the relay in either of two ways conventionally by applying ac current and voltage signals to the relay inputs or by applying low magnitude ac voltage signals to the...

Page 331: ...e press the front panel METER button and compare the relay readings to other accurate instruments in the relay input circuits Figure 7 1 Low Level Test Interface 0300G0 Figure 7 2 Low Level Test Interface 0300G1 Figure 7 3 Low Level Test Interface 0300G2 Figure 7 4 Low Level Test Interface 0300G3 ...

Page 332: ...press SELECT Press the Down arrow pushbutton until TAR 7 is displayed on the top row of the LCD The bottom row of the LCD displays all elements asserted in Relay Word Row 7 The relay maps the state of the elements in Relay Word Row 7 on the bottom row of LEDs The 51PT element state is reflected on the LED labeled 32 See Table 4 6 for the correspondence between the Relay Word elements and the TAR c...

Page 333: ...4 24D1 24D1T ensures that the SER function records the times of all assertions and deassertions of the instantaneous element 24D1 and the time delayed element 24D1T It is not required that these two Relay Word bits reside in the same SERn setting nor is it necessary that they be alone in the SERn setting Following the test simply execute the serial port SER command to review the sequential events ...

Page 334: ...es are made to the relay electrical connections This procedure is intended as a guideline Modify this procedure as necessary to conform with your standard practices and the operating and commissioning guidelines published by the generator and prime mover manufacturers Required Equipment SEL 300G installed and connected according to your protection design PC with serial port terminal emulation soft...

Page 335: ...C Power Start STEP 2 AC DC Continuity Checks STEP 4 Power Supply DC Polarity Checks See Fig 7 6 STEP 5 Contact Output DC Polarity Checks STEP 6 Remove AC Signals STEP 7 Energize Relay Shut Down Generator STEP 20 Operate Generator at Full Load Record Third Harmonic Voltages STEP 21 Shut Down Generator STEP 22 Calculate and Enter 64G Element Settings STEP 23 Clear Relay Data Buffers Are 64G Element ...

Page 336: ... and Z26 Refer to Figure 7 6 Verify continuity between the positive low side terminal of the breaker or fuse block and terminal Z25 marked Verify continuity between the negative low side terminal of the breaker or fuse block and terminal Z26 marked This step is important because the SEL 300G 24 48 Vdc power supply is polarity sensitive CAUTION Do not apply reverse polarity dc voltage or ac voltage...

Page 337: ...EL or you can build your own cable using the cable pinout shown in the SEL 5801 Cable Selector Software This software is available from SEL or can be downloaded free of charge from the SEL world wide web site at http www selinc com Serial Port 1 on all the SEL 300G models is an EIA 485 port 4 wire The Serial Port 1 plug in connector accepts wire size AWG 24 to 12 Strip the wires 0 31 inches 8 mm a...

Page 338: ...odem 5 Vdc Powered C220 all EIA 232 ports Standard Modem 25 Pin Female DCEc C222 all EIA 232 ports RFL 9660 C245A All EIA 232 ports with SEL 2800 transceiver SEL 2600 Series RTD Module C805d All EIA 232 ports with SEL 2812MR transceiver SEL 2664 Field Ground Module SEL C805 Multimode 200 µm core diameter fiber optic cable with ST connectors or SEL C807 Multimode 62 5 µm core diameter fiber optic c...

Page 339: ... from the PC serial port and relay responses displayed Start your PC and run the appropriate terminal emulation software Step 10 Configure the terminal emulation software to operate the PC COM port COM1 COM2 etc at the relay baud rate factory default 2400 baud using 8 data bits 1 stop bit no parity bit and XON XOFF flow control Refer to the terminal emulation package documentation or HELP function...

Page 340: ...ommand ACC Enter If the Password jumper is not in place the relay asks for the Access Level 1 password to be entered Password The relay is shipped with the default Access Level 1 password shown in the table under the PAS command At the above prompt enter the default password and press the Enter key The prompt indicates the relay is now in Access Level 1 If the entered password is incorrect the rel...

Page 341: ... made to Global SER or Port settings the relay is disabled while it saves the new settings If changes are made to the Group settings for the active setting group the relay is disabled while it saves the new settings The ALARM contact closes momentarily and the EN LED extinguishes while the relay is disabled The relay is disabled for as long as 15 seconds If changes are made to the Group settings f...

Page 342: ...OT ACB DWG M300G104 VB VC VA Figure 7 7 Three Phase AC Connection Test Voltage Signals If open delta potentials are used set the test source phase angles as shown in Figure 7 8 When setting PHROT ABC set angle Ia 0 set angle Ib 120 set angle Ic 120 set angle Vab 30 set angle Vcb 90 When setting PHROT ACB set angle Ia 0 set angle Ib 120 set angle Ic 120 set angle Vab 30 set angle Vcb 90 DWG M300G20...

Page 343: ...and Commands for more details regarding the front panel TARGET command Apply rated dc voltage to the individual relay optoisolated input circuits As you apply dc voltage to each input its label will appear in the LCD display and its LED will illuminate Execution of the TAR command via the front panel display remaps the bottom row of the front panel target LEDs see Figure 9 3 pushbutton OTHER For i...

Page 344: ... TRIP3 or TRIP4 assert These tripping bits typically are used individually one TRIPn bit per output contact see the tripping application examples in Section 4 SELOGIC Control Equations If any relay settings were modified during Step 14 confirm that they have been returned to their correct settings Step 16 Connect the relay for tripping duty If the relay is an SEL 300G0 model and 100 percent stator...

Page 345: ...e the front panel or serial port METER DIFF command to check differential protection quantities Differential operate current quantities IOP1 IOP2 and IOP3 should be near zero Note If the SEL 300G1 Relay METER DIFF function reports nonzero differential operate currents there is likely a differential current transformer connection problem or a problem with the TRCON or CTCON settings Use the Differe...

Page 346: ... R commands to record the relay settings The relay is now ready for operation PROTECTION ELEMENT TESTS Introduction This section describes detailed test procedures for individual protection elements While it is not necessary to test every protection function provided by the relay at commissioning time you may wish to test selected elements to verify correct element operation Note Many of the prote...

Page 347: ...tions DWG M300G220 VAB IA VCB IB V IC Two Voltage and Three Current Sources Z01 IA Z02 Z03 Z04 Z05 Z06 Z07 Z08 Z09 Z10 Z11 Z12 IB IC IN VA Z13 Z14 VB VC N VN NN Relay Rear Panel Voltage and Current Inputs DELTA_Y D Z15 Z16 VS NS VS VS Source only needed for 25 Element Tests Figure 7 10 Two Voltage Source and Three Current Source Test Connections Distance 21 Element Equipment Needed SEL 300G Relay ...

Page 348: ... reach in secondary ohms Maximum Torque Angle in degrees Definite time delay in seconds Delta wye step up transformer compensation The voltage and current phase shift introduced by a delta wye step up transformer changes the voltage and current signals presented to the SEL 300G Relay during a phase phase fault on the system The effect is illustrated by Figure 7 11 and Figure 7 12 Generator Voltage...

Page 349: ...e for the effects of the delta wye step up transformer when the mho distance element is used Compensator distance elements inherently compensate for the step up transformer The element pickup accuracy test below describes a mho distance three phase test The compensator distance three phase test is similar Element Pickup Accuracy Test Step 1 Make test source connections according to Figure 7 9 or F...

Page 350: ... the front panel or serial port SHO G command note the global PHROT and DELTA_Y settings PHROT ________ ABC or ACB generator phase rotation DELTA_Y ________ Y or D generator phase pt connection Step 3 This element is easiest to test by simulating a three phase fault increasing the test currents while holding the test voltages constant Set the test source voltage magnitudes greater than or equal to...

Page 351: ...D display then press SELECT This command sequence causes the LCD display and lower deck of target LEDs to display individual Relay Word rows Press the Down arrow button twice to display Relay Word Row 39 which contains the distance element indications as shown in Table 7 5 Table 7 5 Relay Word Row 39 Shows Relay Word Bits for Distance Elements Target LED 24 27 59 32 40 46 64G 81 87 TAR 39 Command ...

Page 352: ...review and output contact operation These methods are described in Test Methods beginning on page 7 4 21P1D Time Delay Accuracy Test The 21P1T Relay Word bit asserts Z1D seconds after the 21P1P element picks up The Element Pickup Accuracy Test verified the accuracy of the 21P1P setting This test applies current signals greater than the pickup values found above and measures the element definite op...

Page 353: ...to Figure 7 10 Current sources are not needed for this test Basic Element Operation The SEL 300G volts hertz element is designed to detect generator overexcitation that occurs when the generator terminal voltage is increased or operating frequency is decreased The relay measures the generator phase to phase voltages and the generator frequency then calculates the volts hertz using the following eq...

Page 354: ...ation DELTA_Y ________ Y or D phase potential connection Make test source connections according to Figure 7 9 or Figure 7 10 Current sources are not required for this test and may be left disconnected Step 5 Using the front panel or serial port SHO command note the settings associated with the relay volts hertz element VNOM ________ volts nominal phase to phase voltage E24 Y setting enables the vo...

Page 355: ...ly using the front panel TARGET function Press the front panel OTHER pushbutton use the Down arrow button to underline the word TAR in the LCD display then press SELECT This command sequence causes the LCD display and lower deck of target LEDs to display individual Relay Word rows Press the Down arrow button twice to display Relay Word Row 2 which contains the volts hertz element indications as sh...

Page 356: ...ment Timing Accuracy Test is to apply predefined signals to the relay and measure the element response time There are two methods available to measure the element response time SER review and output contact operation These methods are described in Test Methods beginning on page 7 4 24D1D Time Delay Accuracy Test The 24D1T Relay Word bit asserts 24D1D seconds after the measured volts hertz exceed t...

Page 357: ...24 Ttest error error _________ 24C2 Time Delay Accuracy Test 24CCS DD When 24CCS DD the 24C2 element operates as a definite time delayed element with two independent time delays each associated with an independent pickup setting as shown in Figure 7 13 This test procedure uses up to four test points to verify that the definite time delays are operating properly t 24D2D2 24D2P1 Test 1 Test 3 opt Te...

Page 358: ...oint3 24D2P2 100 3 VNOM TestPoint3 Vtest3 V secondary Vtest3 ___________ V secondary Select TestPoint2 such that TestPoint2 24D2P2 100 3 VNOM TestPoint2 Vtest2 V secondary Vtest2 ___________ V secondary Select optional Test Point 4 such that TestPoint4 TestPoint2 100 3 VNOM TestPoint4 Vtest4 V secondary Vtest4 ___________ V secondary When DELTA_Y D use the equations below to calculate the test vol...

Page 359: ...tact driving an external timer select one method and make the settings and connections necessary to support the selection Configure the voltage test source to apply balanced three phase voltages with magnitudes equal to Vtest1 Step 3 Apply the test voltages and record the element operating time Ttest1 Remove the test voltages for at least 24CR seconds to permit the element to fully reset Repeat us...

Page 360: ... that the element is operating properly time seconds volts hertz Test 1 Test 2 Test 3 24IP DWG M300G106a Figure 7 14 24C2 Time Delay Test Points 24CCS I Step 1 When DELTA_Y Y calculate the test voltage magnitudes for Test Point 1 Test Point 2 and Test Point 3 using the equations below 100 3 VNOM 24IP 1 1 Vtest1 V secondary Vtest1 ___________ V secondary 100 3 VNOM 24IP 1 3 Vtest2 V secondary Vtest...

Page 361: ...ations below 100 VNOM 24IP 1 1 Vtest1 V secondary Vtest1 ___________ V secondary 100 VNOM 24IP 1 3 Vtest2 V secondary Vtest2 ___________ V secondary 100 VNOM 24IP 1 5 Vtest3 V secondary Vtest3 ___________ V secondary Calculate the expected operate time at each test point using the equation 24IC 1 100 24IP VNOM Vtestn 24ITD Topn seconds Top1 _____________ seconds Top2 _____________ seconds Top3 ___...

Page 362: ...the equation 100 Topn Topn Ttestn errorn error1 _________ error2 _________ error3 _________ 24C2 Time Delay Accuracy Test 24CCS ID When 24CCS ID the 24C2 element operates as a composite element having an inverse time and a definite time characteristic as shown in Figure 7 15 This test procedure uses four test points to verify that the element is operating properly time seconds volts hertz 24IP Tes...

Page 363: ...condary Vtest4 ___________ V secondary Calculate the expected operate time at TestPoints 1 2 and 3 using the following equation IC 24 1 100 IP 24 VNOM 3 Vtestn ITD 24 Topn seconds Top1 _____________ seconds Top2 _____________ seconds Top3 _____________ seconds Top4 24D2D2 seconds _________ seconds Note The Topn equation above assumes that the test voltage is applied at a frequency equal to FNOM Wh...

Page 364: ...ondary Calculate the expected operate time at Test Points 1 2 and 3 using the following equation 24IC 1 100 24IP VNOM Vtestn 24ITD Topn seconds Top1 _____________ seconds Top2 _____________ seconds Top3 _____________ seconds Top4 24D2D2 seconds _________ seconds Note The Topn equation above assumes that the test voltage is applied at a frequency equal to FNOM Step 2 Based on the two timing test de...

Page 365: ...ns Connect the voltage sources according to Figure 7 9 or Figure 7 10 Basic Element Operation The SEL 300G synchronism checking function is designed to ensure that the generator and system voltage magnitudes phase angles and frequencies are matched within settable limits before the generator breaker can be closed Individually the limit checks are simple to test First the relay compares the magnitu...

Page 366: ...e the 25A1 and 25C elements Voltage Element Accuracy Test Use the following steps to test accuracies of the voltage signals used in the synchronism checking function Step 1 Make test source connections according to Figure 7 9 or Figure 7 10 Step 2 Using the front panel or serial port SHO command note the settings associated with the relay synch check function E25 Y setting enables the synch check ...

Page 367: ...apply to test the synch check elements Refer to Table 7 7 and make the test source settings suggested for your combination of SYNCP COMPA DELTA_Y and PHROT settings Table 7 7 Synch Check Element Test Voltage Phase Angles VS Generator Voltages When Angle 0 Relay Settings VP and Error Calculation 0o VS VA 0o 120o VB VC 120o VC VB SYNCP VA COMPA 0 DELTA_Y Y PHROT B C RCF 25 VA VP 100 VLO 25 VLO 25 RC...

Page 368: ...B VP 100 VLO 25 VLO 25 RCF 25 732 1 VTestP errorP 0o VS VA 90o VC 150o 30o VB SYNCP VAB COMPA 0 DELTA_Y Y PHROT C RCF 25 732 1 VA VP 100 VLO 25 VLO 25 RCF 25 732 1 VTestP errorP 0o VS VB 90o VA 150o 30o VC SYNCP VBC COMPA 0 DELTA_Y Y PHROT C RCF 25 732 1 VB VP 100 VLO 25 VLO 25 RCF 25 732 1 VTestP errorP 0o VS VCB 90o 30o VAB SYNCP VA COMPA 0 DELTA_Y D PHROT B RCF 25 732 1 VAB VP 100 VLO 25 VLO 25...

Page 369: ...rP 0o VS VAB 30o 90o VCB SYNCP VC COMPA 0 DELTA_Y D PHROT B RCF 25 732 1 VAB VP 100 VLO 25 VLO 25 RCF 25 732 1 VTestP errorP 0o VS VAB 60o 0o VCB SYNCP VAB COMPA 0 DELTA_Y D PHROT B RCF 25 VAB VP 100 VLO 25 VLO 25 RCF 25 VTestP errorP 0o VS VAB 150o 120o VCB SYNCP VBC COMPA 0 DELTA_Y D PHROT B RCF 25 VBC VP 100 VLO 25 VLO 25 RCF 25 VTestP errorP 0o VS VAB 30o 90o VCB SYNCP VC COMPA 0 DELTA_Y D PHR...

Page 370: ...ent asserts when 25VLO VS 25VHI To predict the test voltage magnitude where the 59VP element will pick up use the equations for VP shown in Table 7 7 for your combination of relay settings This calculation assumes that you will increase the magnitude of phase voltages together while holding the phase angles constant When performing this test manually it is easy to determine when an instantaneous e...

Page 371: ...o the relay when the 59VP element asserts 59VP asserted when phase voltage magnitude equaled ________ V secondary VTestP Step 6 Gradually increase the magnitude of the synch voltage Record the voltage magnitude applied to the relay when the 59VS element asserts 59VS asserted when synch voltage magnitude equaled ________ V secondary VTestS Use the equation shown in the appropriate area of Table 7 7...

Page 372: ...lay Word Row 37 Shows Relay Word Bits for Slip Frequency Elements Target LED 24 27 59 32 40 46 64G 81 87 TAR 37 Command causes these LEDs to represent 59PP2 27PP2 SF VDIF GENVHI GENVLO GENFHI GENFLO During the manual test as you change test voltage frequencies you can see the SF GENFHI and GENFLO Relay Word bits assert and deassert to indicate pickup and dropout of the respective elements If you p...

Page 373: ...lement asserts when the absolute phase angle difference equals the CANGLE setting When performing this test manually it is easy to determine when the angle elements pick up by viewing the element states directly using the front panel TARGET function Press the front panel OTHER pushbutton use the Down arrow button to underline the word TAR in the LCD display then press SELECT This command sequence ...

Page 374: ... error by adding the COMPA setting to the test result then subtract the expected test phase angle element setting Undervoltage 27 Elements Equipment Needed SEL 300G Relay under test Two or Three Phase AC Voltage Test Source with adjustable magnitude and phase angle PC with terminal emulation software and appropriate serial cable to connect the PC COM port to the relay Test Source Connections When ...

Page 375: ...ils During the manual test as you change the test voltage magnitude you can see Relay Word bits assert and deassert to indicate pickup and dropout of the respective elements If you prefer to monitor a contact closure to indicate element pickup use the Access Level 2 SET command to program an output contact to close when the element under test picks up Step 4 When DELTA_Y Y test the 27Pn elements a...

Page 376: ...ned to detect generator motoring conditions and provide an alarm or trip The relay measures the generator phase voltages and currents then calculates the three phase power in per unit of the generator nominal power using the equation cos INOM VNOM 732 1 Ip Vp 3 Power Θ per unit Where Vp measured generator phase voltage magnitude Ip measured generator phase current magnitude VNOM nominal generator ...

Page 377: ...are enabled when 32PTC logical 1 Using the front panel or serial port SHO G command note the global PHROT setting PHROT ________ ABC or ACB generator phase rotation Step 3 This element is easiest to test by changing the test current while holding the phase to phase test voltage equal to VNOM Set the test source voltage magnitudes equal to VNOM 1 732 Set the test source voltage phase angles as show...

Page 378: ...al 1 for IP IOP 32PnP 0 32PnP 0 P DWG M300G108 Operate Operate Figure 7 16 32Pn Element Operate Region Depends on the Sign of the 32Pn Setting When performing this test manually it is easy to determine when an instantaneous element picks up by viewing the element state directly using the front panel TARGET function Press the front panel OTHER pushbutton use the Down arrow button to underline the w...

Page 379: ... to indicate element pickup use the Access Level 2 SET command to program an output contact to close when the element under test picks up Step 4 Set the test source current phase angles appropriately to test the 32P1 pickup based on the relay settings and the information above Turn on the current test sources and gradually increase the magnitude of all three phase currents Record the current magni...

Page 380: ...ase test voltages equal to VNOM Set the test source voltage magnitudes equal to VNOM Set the test source voltage phase angles as shown in Figure 7 8 Set the test source current phase angles depending on the sign of the power setting for the element under test as follows When setting 32PnP 0 0 set angle Ia angle 0 set angle Ib angle 120 120 if PHROT C set angle Ic angle 120 120 if PHROT C When sett...

Page 381: ...ly increase the magnitude of all three phase currents Record the current magnitude applied to the relay when the instantaneous element under test asserts deasserts Record the current magnitude and turn off the current test sources Itest1 _______ A secondary If necessary change the test source current phase angles to test the 32P2 pickup Turn on the current test sources and gradually increase the m...

Page 382: ...as determined by the test above The element time is calculated from the instant current signals are applied to the relay until the 32PnT Relay Word bit asserts Record the element operating time Ttestn Step 3 For 32PnP 0 Configure the current test sources to apply balanced three phase currents with magnitudes equal to 1 1 Iopn as determined by the element accuracy test above and turn on the current...

Page 383: ... field elements 40Z1P _________ Ω secondary Zone 1 Mho Element diameter setting 40XD1 ________ Ω secondary Zone 1 Mho Element offset setting 40Z1D ________ seconds Zone 1 element definite time delay 40Z2P _________ Ω secondary Zone 2 Mho Element diameter setting 40XD2 ________ Ω secondary Zone 2 Mho Element offset setting 40Z2D ________ seconds Zone 2 element definite time delay 40DIR ________ deg...

Page 384: ... Ic 30 Refer to Figure 7 17 and Figure 7 18 In these figures the phase current necessary to apply the test at the point indicated by the vector TestXAn is calculated using the following equation DWG M300G109a Test XAn Test XBn 40Zn Relay Word bit Asserted 40ZnP 40XDn X R Figure 7 17 Loss of Field Element Diameter and Offset Tests 40XD2 0 ...

Page 385: ...40 3 Va IopXBn A secondary DELTA_Y D IopXB1 ________ A secondary IopXB2 ________ A secondary When 40XD2 is positive this second point on the mho circle is not available to test When performing this test manually it is easy to determine when an instantaneous element picks up by viewing the element state directly using the front panel TARGET function Press the front panel OTHER pushbutton use the Do...

Page 386: ...the respective elements If you prefer to monitor a contact closure to indicate element pickup use the Access Level 2 SET command to program an output contact to close when the element under test picks up Step 4 Turn on the current test sources and gradually increase the magnitude of all three phase currents Record the applied current magnitude when the Zone 1 and Zone 2 instantaneous elements asse...

Page 387: ...racteristic you may wish to rotate the test current phase angles a few degrees each way from 90 and retest the element pickup points Many programmable relay test systems can be set up to take additional test points automatically You can also perform the test manually The calculations below require the use of a scientific calculator having square root and arcsine functions Referring to Figure 7 19 ...

Page 388: ...____ ohms DWG M300G111a 40ZnP 40XDn X R Θ Z1 x δ y Figure 7 19 Loss of Field Element Off Diameter Test 40XDn 0 Z1 x arcsin Θn degrees Θ ________ degrees Set the test source current phase angles as follows When setting PHROT ABC set angle Ia 90 Θ set angle Ib 30 Θ set angle Ic 150 Θ When setting PHROT ACB set angle Ia 90 Θ set angle Ib 150 Θ set angle Ic 30 Θ ...

Page 389: ... test rotating the test current phase angles by Θn Element Timing Accuracy Test Note This procedure uses the setup from the Element Pickup Accuracy Test Perform the Element Pickup Accuracy Test before proceeding with the Element Timing Accuracy Test The object of the Element Timing Accuracy Test is to apply predefined signals to the relay and measure the element response time There are two methods...

Page 390: ...ement time is calculated from the instant current signals are applied until the 40ZnT Relay Word bit asserts Record the element operating time Ttestn Step 3 Calculate the relay timing error using the equation 100 ZnD 40 ZnD 40 Ttestn errorn error1 _________ error2 _________ Negative Sequence Overcurrent 46 Element Equipment Needed SEL 300G Relay under test Single Phase AC Current Test Source with ...

Page 391: ...ence overcurrent element INOM _________ amps nominal phase current E46 Y setting enables the negative sequence overcurrent elements 46Q1P ________ negative sequence current alarm element pickup setting 46Q1D ________ seconds alarm element definite time delay 46Q2P ________ negative sequence current inverse time element pickup 46Q2K ________ inverse time element time dial 46QTC ____________________...

Page 392: ...r to monitor a contact closure to indicate element pickup use the Access Level 2 SET command to program an output contact to close when the element under test picks up Step 4 Gradually increase the magnitude of the test current Record the current magnitude applied to the relay when the instantaneous element under test asserts Itest1 ________ A secondary Itest2 ________ A secondary Use the equation...

Page 393: ...ions necessary to support the selection Configure the current test source to apply single phase current with magnitude equal to 1 1 Itest1 as measured by the 46Q1P test performed above Step 2 Expect 46Q1T to assert 46Q1D seconds after the test signals are applied Step 3 Apply the test current calculated in Step 1 and record the element operating time Ttest1 Remove the test current Ttest1 _________...

Page 394: ...econdary INOM 5 0 3 2 Itest A secondary Itest2 ___________ A secondary INOM 0 1 3 3 Itest A secondary Itest3 ___________ A secondary Calculate the expected operate time at each test point using the equation 2 INOM 3 Itestn K 2 Q 46 Topn seconds Top1 _____________ seconds Top2 _____________ seconds Top3 _____________ seconds Step 2 Based on the two timing test descriptions above SER or output conta...

Page 395: ...nd appropriate serial cable to connect the PC COM port to the relay Test Source Connections Connect the current source according to Figure 7 20 Basic Element Operation The SEL 300G offers a variety of phase residual and neutral overcurrent elements These elements offer instantaneous definite time and inverse time operating characteristics You can test any of the elements using a single phase curre...

Page 396: ... If you prefer to monitor a contact closure to indicate element pickup use the Access Level 2 SET command to program an output contact to close when the element under test picks up Step 4 Gradually increase the magnitude of the test current Record the current magnitude applied to the relay when the instantaneous element under test asserts Itest ________ A secondary Use the equation below to calcul...

Page 397: ...ement timing characteristic Step 1 Use the equations below to calculate the test current magnitudes for Test Point 1 Test Point 2 and Test Point 3 Ipickup 3 1 Itest A secondary Itest1 ___________ A secondary Ipickup 5 2 Itest A secondary Itest2 ___________ A secondary Ipickup 7 3 Itest A secondary Itest3 ___________ A secondary Calculate the expected operate time at each test point using the equat...

Page 398: ... Voltage plus a Single Phase Current AC Test Source with adjustable magnitude and phase angle between the signals PC with terminal emulation software and appropriate serial cable to connect the PC COM port to the relay Test Source Connections Connect the voltage and current sources according to Figure 7 22 or Figure 7 23 DWG M300G116 VA IA VB IB VC IC Three Phase Voltage and Current Sources Z01 IA...

Page 399: ...he element torque control condition then use the current source to test the element as if it were any other time overcurrent element See Section 2 Relay Element Settings for complete descriptions of the 51C voltage controlled phase time overcurrent element and the undervoltage elements typically used to control the 51C element Element Pickup Accuracy Test Step 1 Connect the voltage and current sou...

Page 400: ...e LCD display and lower deck of target LEDs to display individual Relay Word rows Press the Down arrow button several times to display Relay Word Row 7 which contains the voltage controlled phase time overcurrent element indications as shown in Table 7 15 Table 7 15 Relay Word Row 7 Shows Relay Word Bits for Voltage Controlled Time Overcurrent Elements Target LED 24 27 59 32 40 46 64G 81 87 TAR 7 ...

Page 401: ...test points to verify that the element is operating properly Step 1 Use the equations below to calculate the test current magnitudes for Test Point 1 Test Point 2 and Test Point 3 CP 51 3 1 Itest A secondary Itest1 ___________ A secondary CP 51 5 2 Itest A secondary Itest2 ___________ A secondary CP 51 7 3 Itest A secondary Itest3 ___________ A secondary Calculate the expected operate time at each...

Page 402: ...COM port to the relay Test Source Connections Connect the voltage and current sources according to Figure 7 9 or Figure 7 10 Basic Element Operation The 51V voltage restrained phase time overcurrent element s pickup setting 51VP is reduced depending on the magnitude of the applied phase phase voltage The relationship between element pickup current and phase phase voltage is linear If the phase pha...

Page 403: ...n DELTA_Y D Set the test source voltage phase angles as shown in Figure 7 7 or Figure 7 8 Note that balanced 3 phase voltage and current test values are used for the following tests The phase angle between IA and VA or VAB may be any value The 51VP pickup setting is made directly in secondary amps However the actual pickup is adjusted by the ratio of the applied voltage to the nominal voltage as s...

Page 404: ...oltage Restrained Time Overcurrent Elements Target LED 24 27 59 32 40 46 64G 81 87 TAR 9 Command causes these LEDs to represent 51VTC 51V 51VT 51VR PDEM QDEM GDEM NDEM With voltage applied as described above the relay should display the 51VTC and 51VR Relay Word bit names in the LCD display and illuminate the 24 and 40 LEDs which the TAR command reassigns to display the 51VTC and 51VR Relay Word b...

Page 405: ...curacy Test To test 51V overcurrent element inverse time characteristic this test procedure uses three test points to verify that the element is operating properly Step 1 Use the equations below to calculate the test current magnitudes for Test Point 1 Test Point 2 and Test Point 3 VP 51 3 1 Itest A secondary Itest1 ___________ A secondary VP 51 5 2 Itest A secondary Itest2 ___________ A secondary...

Page 406: ...ch test point using the equation 100 Topn Topn Ttestn errorn error1 _________ error2 _________ error3 _________ Step 5 To verify the element timing characteristic under reduced voltage conditions select one reduced voltage Vr ________ phase phase V secondary 0 125 Vr VNOM 1 0 Calculate new Itest quantity using the equations VP VNOM Vr Itest 51 3 732 1 1 A secondary DELTA_Y Y VP VNOM Vr Itest 51 3 ...

Page 407: ...Equipment Needed SEL 300G Relay under test Single Phase AC Voltage Test Source with adjustable magnitude PC with terminal emulation software and appropriate serial cable to connect the PC COM port to the relay Test Source Connections Connect the voltage source according to Figure 7 24 DELTA_Y Y or Figure 7 25 DELTA_Y D DWG M300G119 VA IA Single Phase Voltage Sources Z01 IA Z02 Z03 Z04 Z05 Z06 Z07 ...

Page 408: ...ings associated with the voltage element under test Step 3 These element pickup settings are made directly in secondary volts 59P1 59P2 59G1 59G2 59PP1 and 59PP2 will pick up when the applied voltage magnitude is equal to the pickup setting 59Q and 59V1 operate for applied single phase voltage equal to three times their settings Vop ________ V secondary When performing this test manually it is eas...

Page 409: ...AC Voltage Test Sources with adjustable magnitude and frequency for 64G2 element test 64RAT 0 Four Single Phase AC Voltage Test Sources with adjustable magnitude phase angles and frequency for 64G2 element test 64RAT 0 PC with terminal emulation software and appropriate serial cable to connect the PC COM port to the relay Basic Element Operation 64G1 Element Operation The 64G1 element is a fundame...

Page 410: ...N VN NN Relay Rear Panel Voltage and Current Inputs VN Figure 7 26 Neutral Voltage Test Connection 64G1 Step 2 Using the front panel or serial port SHO command note the settings associated with the 64G1 elements E64 Y setting enables the 100 Stator Ground Elements 64G1P ________ V secondary neutral overvoltage element setting 64G1D ________ seconds neutral overvoltage time delay 64GTC ____________...

Page 411: ...t to close when the element under test picks up Step 4 Set the test source frequency equal to FNOM Gradually increase the test voltage magnitude to approach the pickup setting of the 64G1 element Record the test voltage applied to the relay when the 64G1 Relay Word bit asserts Vtest ________ volts Use the equation below to calculate the element error 100 P 1 G 64 P 1 G 64 Vtest error error _______...

Page 412: ...t Remove the test voltage Ttest _________ seconds Step 4 Calculate the relay timing error using the equation 100 D 1 G 64 D 1 G 64 Ttest error error _________ 64G2 Element Operating Accuracy Test 64RAT 0 Step 1 Connect the voltage sources according to Figure 7 27 DWG M300G122 VB Two Phase Voltage Sources Z01 IA Z02 Z03 Z04 Z05 Z06 Z07 Z08 Z09 Z10 Z11 Z12 IB IC IN VA Z13 Z14 VB VC N VN NN Relay Rea...

Page 413: ...hase voltage input equal to 2 64G2P 64RAT Calculate the expected VN magnitudes at which the element should operate Use the equations ondary sec V ________ __________ VN P 2 G 64 0 3 VN and P 2 G 64 VN When performing this test manually it is easy to determine when an instantaneous element picks up by viewing the element state directly using the front panel TARGET function Press the front panel OTH...

Page 414: ... The Element Pickup Accuracy Test verified the accuracy of the pickup settings This test measures the element definite operating time Step 1 Based on the two timing test descriptions above SER or output contact driving an external timer select one method and make the settings and connections necessary to support the selection Configure the voltage test sources to apply neutral and phase voltages w...

Page 415: ...seconds third harmonic voltage differential time delay 64GTC __________________________________________________________ Torque Control Setting element is enabled when 64GTC logical 1 Using the front panel or serial port SHO G command note the global FNOM PHROT and DELTA_Y settings FNOM ________ Hz nominal generator frequency PHROT ________ ABC or ACB generator phase rotation DELTA_Y ________ Y or ...

Page 416: ... Word bit asserts Vtest ________ volts Use the equation below to calculate the element error 100 P 2 G 64 P 2 G 64 Vtest error error _________ 64G2 Element Timing Accuracy Test 64RAT 0 Note This procedure uses the setup from the Element Pickup Accuracy Test Perform the Element Pickup Accuracy Test before proceeding with the Element Timing Accuracy Test The object of the Element Timing Accuracy Tes...

Page 417: ...detects an out of step condition by tracking the path of positive sequence impedance trajectories that pass through the protection zone If the relay detects an out of step condition it asserts the following Relay Word bits Relay Word bit SWING picks up when the positive sequence impedance moves from the load region into Area A left blinder 78R2 and mho element 78Z1 assert Relay Word bit OOS picks ...

Page 418: ...ight blinder setting 78R2 __________ Ω secondary left blinder setting Using the front panel or serial port SHO G command note the global PHROT and DELTA_Y setting PHROT _______ ABC or ACB generator phase rotation DELTA_Y _____ Y or D generator PT connection Step 3 This element is easiest to test by changing the test current while holding test voltage equal to VNOM Set the test source voltage magni...

Page 419: ...o current is less than or equal to the forward reach 78FWD ohms of the mho circle Expected value setting 78FWD Va 1 Z 78 Iop DELTA_Y Y setting 78FWD 3 Va 1 Z 78 Iop DELTA_Y D Expected Iop78Z1 ______________ A secondary Step 4 Turn on the current test sources and gradually increase the magnitude of all three phase currents Record the applied current magnitude when the 78Z1 element asserts Itest78Z1...

Page 420: ...__ Y or D generator PT connection Step 3 This element is easiest to test by changing the test current while holding the test voltage equal to VNOM Set the test source voltage magnitude equal to VNOM 1 732 DELTA_Y Y or VNOM DELTA_Y D Set the test source voltage phase angles as shown in Figure 7 7 or Figure 7 8 Set the test source current phase angles as follows When setting PHROT ABC set angle Ia 0...

Page 421: ...sed for testing 78R2 should be displaced by 180 Follow Steps 1 through 3 from the 78R1 Element Operating Accuracy Test on the preceding page Follow Steps 4 and 5 below to complete the 78R2 element test Step 1 Turn on the current test source and gradually increase the magnitude of all three phase currents Record the applied current magnitude when the 78R2 element asserts Itest78R2 ______ A secondar...

Page 422: ...ep condition if the positive sequence impedance stays between the two blinders for more than 78D seconds and advances further inside the inner blinder The logic issues an out of step trip once an out of step condition is established and the positive sequence impedance exits the mho circle If the relay detects an out of step condition it asserts the following Relay Word bits Relay Word bit SWING pi...

Page 423: ... Needed SEL 300G Relay under test Three Phase AC Voltage Test Source with adjustable magnitude phase angles and frequency PC with terminal emulation software and appropriate serial cable to connect the PC COM port to the relay Test Source Connections Connect the voltage sources according to Figure 7 9 or Figure 7 10 Current sources are not required for this test Basic Element Operation The SEL 300...

Page 424: ...ckup frequency 81D4D ________ seconds Level 1 time delay 81D5P ________ hertz Level 1 pickup frequency 81D5D ________ seconds Level 1 time delay 81D6P ________ hertz Level 1 pickup frequency 81D6D ________ seconds Level 1 time delay Using the front panel or serial port SHO G command note the global FNOM PHROT and DELTA_Y settings FNOM ________ Hz nominal generator frequency PHROT ________ ABC or A...

Page 425: ... element under test asserts Ftest ________ hertz Use the equation below to calculate the element error DnP 81 Ftest error error _________ hertz Element Timing Accuracy Test Note This procedure uses the setup from the Element Pickup Accuracy Test Perform the Element Pickup Accuracy Test before proceeding with the Element Timing Accuracy Test The object of the Element Timing Accuracy Test is to appl...

Page 426: ...s after the test signals are applied Step 3 Apply the test voltages calculated in Step 1 and record the element operating time Ttest Remove the test voltages Ttest _________ seconds Step 4 Calculate the relay timing error using the equation 100 DnD 81 DnD 81 Ttest error error _________ Ground Differential 87N Element Equipment Needed SEL 300G Relay under test Two AC Current Test Sources with adjus...

Page 427: ...und faults but can sensitively detect most internal ground faults The relay ground differential element picks up when I87N the ground difference current is greater than the 87N element pickup setting The relay calculates I87N using the equation ondary sec A IN CTRN CTR IG N 87 I where I87N round difference current IG Measured residual current IA IB IC IN Measured neutral current CTR Phase CT Ratio...

Page 428: ...s are enabled when 87NTC logical 1 Step 3 This element is easiest to test by increasing neutral current until the element picks up To prove differential operation you can then increase the phase current while holding the neutral current constant until the element drops out To predict the test neutral current magnitude where the element will operate use equation NnP 87 INop A secondary This calcula...

Page 429: ...rogram an output contact to close when the element under test picks up Step 4 Gradually increase the magnitude of applied neutral current Record the current magnitude applied to the relay when the instantaneous element under test asserts 87N1P asserted when neutral current magnitude equaled ________ A secondary Atest1 Next gradually increase the magnitude of applied phase current Make sure that th...

Page 430: ... Based on the two timing test descriptions above SER or output contact driving an external timer select one method and make the settings and connections necessary to support the selection Configure the current test sources to IN and Atest2 as determined in the element accuracy test 87N1P should be deasserted Remove IN Step 2 Expect 87N1T to assert 87N1D seconds after the IN test signal is removed ...

Page 431: ... panel or serial port SHO command note the settings associated with the 87U element E87 G or T setting enables the Current Differential Elements TRCON _______ transformer connection setting hidden when E87 G CTCON _______ ct connection setting hidden when E87 G TAP1 _________ A phase current input tap quantity TAPD _________ A 87 input tap quantity U87P _________ multiple of TAP unrestrained eleme...

Page 432: ...ay individual Relay Word rows Press the Down arrow button several times to display Relay Word Row 34 which contains the 87U element indications as shown in Table 7 20 Table 7 20 Relay Word Row 34 Shows Relay Word Bits for 87U Elements Target LED 24 27 59 32 40 46 64G 81 87 TAR 34 Command causes these LEDs to represent 87U 87U1 87U2 87U3 50H1 50H1T 50H2 50H2T During the manual test as you change th...

Page 433: ... 87R element picks up when the differential operate current exceeds the O87P setting if the test current is low enough to not move the test into the percentage restrained characteristic of the element Calculate the expected element operate current using the equation Iop O87P TAP1 A Iop ________ A secondary where A is selected from Table 7 19 when test current is applied to IA IB or IC Replace A wi...

Page 434: ...t applied to the relay when the 87R Relay Word bit asserts Itest ________ amps Use the equation below to calculate the element error 100 P 87 O P 87 O A 1 TAP Itest error error _________ Replace TAP1 and A with TAPD and B if the test was performed with current applied to IA87 IB87 or IC87 SLP1 Restrained Element Accuracy Test Step 1 Connect current sources to the IA and IA87 current inputs Step 2 ...

Page 435: ...ate value for the test using the following formula B TAPD 200 SLP1 1 IRT IA87f IA87f ____________ amps The A and B connection compensation constants are found in Table 7 19 Calculate the initial value for the IA87 current using the equation IA87i IA TAPD TAP1 IA87i ____________ amps This initial value of current when applied to the relay with IA will result in IOP 0 When performing this test manua...

Page 436: ...he front panel or serial port SHO command note the settings associated with the 87R element E87 G or T setting enables the Current Differential Elements TRCON ________ transformer connection setting hidden when E87 G CTCON ________ ct connection setting hidden when E87 G TAP1 ________ A phase current input tap quantity TAPD ________ A 87 input tap quantity O87P ________ multiple of TAP restrained ...

Page 437: ...ndividual Relay Word rows Press the Down arrow button several times to display Relay Word Row 33 which contains the 87R element indications as shown in Table 7 21 During the manual test as you change the test current you can see the Relay Word bits assert and deassert to indicate pickup and dropout of the respective elements If you prefer to monitor a contact closure to indicate element pickup use...

Page 438: ... the Down arrow button to underline the word TAR in the LCD display then press SELECT This command sequence causes the LCD display and lower deck of target LEDs to display individual Relay Word rows Press the Down arrow button several times to display Relay Word Row 33 which contains the 87R element indications as shown in Table 7 21 Increase the magnitude of applied current until 87R asserts Note...

Page 439: ... Perform the following additional checks 1 Plot the six measured currents in the chart on the following Check List Verify correct phase rotation for both sets of three currents Correct any problems found and recheck the operate quantities to determine if they are less than 10 percent 2 Based on the relay settings and the chart notations verify the desired phase angle difference between the phase c...

Page 440: ...N DAB TRCON YDAB CTCON Y TRCON DACY CTCON DAC TRCON YDAC CTCON Y TRCON DABDAB CTCON Y TRCON DACDAC CTCON Y TRCON YY CTCON Y Then phase angles should be 180 apart If E87 T AND TRCON GEN CTCON DAC TRCON DABY CTCON Y TRCON YDAC CTCON Y Then I87 should lead IW1 by 150 Plot Phasors 135 90 45 180 180 135 90 45 0 DWG MAPP E If E87 T AND TRCON GEN CTCON DAB TRCON DACY CTCON Y TRCON YDAB CTCON Y Then I87 s...

Page 441: ...and Externally Initiated Trips 8 5 Station DC Battery Monitor 8 10 View Station DC Battery Voltage 8 10 Analyze Station DC Battery Voltage 8 10 Operation of Station DC Battery Monitor When AC Voltage is Powering the Relay 8 11 Differential Metering 8 11 View Differential Metering Information 8 11 Energy Metering 8 11 View or Reset Energy Metering Information 8 11 Energy Metering Updating and Stora...

Page 442: ......

Page 443: ...40 and 70 Hz This data is updated each second then stored in nonvolatile memory on a daily basis at 23 50 hours All the data listed above plus the present 81AC Off Frequency Time Accumulator values can be viewed or reset using the serial port PROFILE command Generator Hour Meters The relay provides three hour meters plus a Time Running percentage to help record generator utilization The relay cons...

Page 444: ...ed when the average MVAR in is less than the average MVAR out Off Frequency Operating Time Accumulators The relay tracks operating time by frequency in two manners both represented in the generator operating statistics record The first report is associated with the 81AC Off Frequency Time Accumulator Protection function When this function is enabled the relay PROFILE command response reports the p...

Page 445: ...nd note that for a given current value the 10 percent curve has only 1 10 of the close open operations of the 100 percent curve 10 Percent to 25 Percent Breaker Wear Refer to Figure 8 2 The current value changes from 7 0 kA to 2 5 kA 2 5 kA is interrupted 290 times 290 close open operations 480 190 pushing the breaker maintenance curve from the 10 percent wear level to the 25 percent wear level Co...

Page 446: ...e accumulated data can be reset only if the BRE R command is executed see the following discussion on the BRE R command Via Serial Port See BRE Command Breaker Monitor Data in Section 10 Serial Port Communications and Commands The BRE command displays the following information Accumulated number of relay initiated trips Accumulated interrupted current from relay initiated trips Accumulated number ...

Page 447: ... to logical 1 transition the relay reads in the current values Phases A B and C Now the decision has to be made where is this current and trip count information accumulated Is it under relay initiated trips or externally initiated trips To make this determination the status of the TRIP Relay Word bit is checked at the instant BKMON newly asserts TRIP is the logic output of Figure 4 6 If TRIP is as...

Page 448: ... SEL 300G Instruction Manual Number of Close Open Operations kA Interrupted per Operation 5 10 1 2 4 3 7 6 5 9 10 8 2 3 5 4 6 7 9 8 100 2 3 DWG M300G132 30 20 40 50 6 4 5 6 8 7 9 1000 10 2 4 3 5 7 8 10 000 9 100 Figure 8 1 Breaker Monitor Accumulates 10 Wear ...

Page 449: ... Manual Date Code 20060731 DWG M300G133 10 100 10 000 1000 2 3 4 5 6 7 8 9 100 2 3 4 5 6 7 8 9 10 2 3 4 5 6 7 8 9 1 2 3 4 5 6 7 8 9 50 40 30 20 10 Number of Close Open Operations kA Interrupted per Operation 5 25 Figure 8 2 Breaker Monitor Accumulates 25 Wear ...

Page 450: ...EL 300G Instruction Manual DWG M300G134 100 10 000 1000 2 3 4 5 6 7 8 9 100 2 3 4 5 6 7 8 9 10 2 3 4 5 6 7 8 9 1 2 3 4 5 6 7 8 9 50 40 30 20 10 Number of Close Open Operations kA Interrupted per Operation 5 25 50 Figure 8 3 Breaker Monitor Accumulates 50 Wear ...

Page 451: ...n Manual Date Code 20060731 Number of Close Open Operations kA Interrupted per Operation 10 5 1 2 3 4 7 5 6 9 8 10 6 3 2 4 5 7 8 100 9 2 DWG M300G135 30 20 40 50 5 3 4 6 7 1000 8 9 2 3 4 9 6 5 7 8 50 10 000 100 Figure 8 4 Breaker Monitor Accumulates 100 Wear ...

Page 452: ...age See Standard Event Reports in Section 11 Event Reports and SER Functions The station dc battery voltage is displayed in column Vdc in the example event report in Figure 11 2 Changes in station dc battery voltage for an event e g circuit breaker tripping can be observed Use the EVE command to retrieve event reports as discussed in Section 12 Maintain and Troubleshoot Relay Station DC Battery Vo...

Page 453: ...age waveform rather than the average DIFFERENTIAL METERING View Differential Metering Information Via Serial Port See MET Command Metering Data MET DIF Differential Metering Model 0300G1 and Model 0300G3 in Section 10 Serial Port Communications and Commands The MET DIF command displays the following values Operate Currents Winding 1 Winding 2 and Winding 3 in multiples of TAP and percent serial po...

Page 454: ...9 MVARh it starts over at zero Note If you are using Modbus RTU Communications Protocol to retrieve energy metering data from the SEL 300G you are limited to a maximum of 65535 MWh or 65535 MVARh The energy meter values do not reset automatically but they can be reset either locally front panel or serial port or from a Modbus master location when they reach the maximum value mentioned above MAXIMU...

Page 455: ... voltage values the voltage is above 13 V secondary For neutral voltage values the voltage is above 0 05 V secondary For third harmonic voltage values the voltage is above 0 05 V secondary For current values the currents are above 0 05 A secondary 5 A nominal A secondary 1 A nominal Megawatt and megavar values are subject to the above voltage and current thresholds The SEL 300G stores maximum mini...

Page 456: ......

Page 457: ...trol State Retained When Relay De energized 9 9 Rotating Default Display 9 9 TABLES Table 9 1 SEL 300G Relay Front Panel Target LED Definitions 9 1 FIGURES Figure 9 1 SEL 300G Relay Front Panel Pushbuttons Overview 9 2 Figure 9 2 SEL 300G Relay Front Panel Pushbuttons Primary Functions 9 3 Figure 9 3 SEL 300G Relay Front Panel Pushbuttons Primary Functions continued 9 4 Figure 9 4 SEL 300G Relay F...

Page 458: ......

Page 459: ...ined 51VT time overcurrent element trip was picked up when the last trip occurred 6 50 A definite time overcurrent element was timed out when the last trip occurred 7 51 A time overcurrent element was timed out when the last trip occurred 8 N A neutral overcurrent element was timed out when the last trip occurred occurs with 50 or 51 9 24 A volts hertz element was timed out when the last trip occu...

Page 460: ...l functions primary secondary A primary function is selected first e g METER pushbutton After a primary function is selected the pushbuttons revert to operating on their secondary functions CANCEL SELECT left right arrows up down arrows EXIT For example after the METER pushbutton is pressed the up down arrows are used to scroll through the front panel metering screens The primary functions are act...

Page 461: ...aries View Self Test Status HIS STA Function Description Corresponding Serial Port Commands at Access Level 1 Front panel pushbutton functions that correspond to Access Level 1 serial port commands do not require the entry of the Access Level 1 password through the front panel MET MET D MET E MET M MET RD MET RE MET RM MET RP MET DIF MET T Figure 9 2 SEL 300G Relay Front Panel Pushbuttons Primary ...

Page 462: ... available through the serial port and does not require the entry of a password Access Level B2 Access Level 23 View or Reset Breaker Monitor Data View or Change Date or Time View Asserted Relay Word Bits BRE DAT TIM TAR BRE R View or Change Group Global or Serial Port Settings Change Passwords SHO n SHO G SHO P SET n SET G SET P PAS Pulse Output Contacts4 View or Operate Local Control5 PUL GRO GR...

Page 463: ...ng Digit Scroll Up on Display Increment Setting Value Scroll Down on Display Decrement Setting Value Function Description Select Displayed Option or Setting SELECT Exit Entirely and Return to Default Display EXIT The front panel display gives indication of the arrow button to use Displays symbols QUI Function Description Corresponding Serial Port Commands at Access Level 1 Front panel pushbutton f...

Page 464: ...OGIC control equations see Table 4 6 Local control can emulate the following switch types in Figure 9 5 through Figure 9 7 OFF position logical 0 ON position DWG M300G144 Relay Word Bit LBn Logical 1 n 1 through 16 Figure 9 5 Local Control Switch Configured as an ON OFF Switch OFF position logical 0 MOMENTARY position DWG M300G143 Relay Word Bit LBn Logical 1 n 1 through 16 Figure 9 6 Local Contro...

Page 465: ... with the rotating default display messages Press CNTRL for Local Control Press the CNTRL pushbutton and the first set local control switch displays shown here with factory default settings GEN SHUTDOWN Position RETURN RETURN logical 0 TRIP GEN SHUTDOWN DWG M300G141 Local Bit LB1 Logical 1 The GEN SHUTDOWN RETURN TRIP switch is an OFF MOMENTARY switch see Figure 9 6 There are no more local control...

Page 466: ...fter momentarily being in the TRIP position Technically the GEN SHUTDOWN switch being an OFF MOMENTARY type switch is in the TRIP position for one processing interval 1 4 cycle long enough to assert the corresponding local bit LB1 to logical 1 and then returns to the RETURN position local bit LB1 deasserts to logical 0 again On the display the GEN SHUTDOWN switch is shown to be in the TRIP positio...

Page 467: ... or metering quantities are enabled for display The Press CNTRL for Local Control message displays if at least one local control switch is operational It is a reminder of how to access the local control function See the preceding discussion in this section and Local Control Switches in Section 4 SELOGIC Control Equations for more information on local control If display point labels and or rotating...

Page 468: ......

Page 469: ...ns 10 12 Access Level 0 Commands 10 12 Access Level 1 Commands 10 13 Access Level B Commands 10 34 Access Level 2 Commands 10 36 Serial Port Error Messages 10 40 Command Summary 10 43 TABLES Table 10 1 SEL 300G Relay Available Serial Ports 10 1 Table 10 2 Pinout Functions for EIA 232 Serial Ports 2 3 and F 10 2 Table 10 3 Terminal Functions for EIA 485 Serial Port 1 10 2 Table 10 4 Serial Communic...

Page 470: ......

Page 471: ...nications Processors the SEL 2600 Series and the SEL 2800 You can use a variety of terminal emulation programs on your personal computer to communicate with the relay Examples of PC based terminal emulation programs include ACSELERATOR QuickSet SEL 5030 software see Appendix G for detail ProComm Plus Relay Gold Microsoft Windows HyperTerminal SmartCOM and CROSSTALK For the best display use VT 100 ...

Page 472: ...ector it should not be input into Serial Port 2 and vice versa Table 10 2 Pinout Functions for EIA 232 Serial Ports 2 3 and F Pin Port 2 Port 3 Port F 1 N C or 5 Vdca N C or 5 Vdca N C 2 RXD RXD RXD 3 TXD TXD TXD 4 IRIG B N C N C 5 9 GND GND GND 6 IRIG B N C N C 7 RTS RTS RTS 8 CTS CTS CTS a Refer to EIA 232 Serial Port Voltage Jumpers on page 5 34 in Section 5 Installation Table 10 3 Terminal Fun...

Page 473: ... C234A GND 5 TXD 3 RXD 2 GND 9 CTS 8 7 GND 3 RXD 2 TXD 1 RTS 4 CTS 5 GND 6 8 20 SEL 300G Relay 9 Pin Male D Subconnector 9 Pin DTE Device 25 Pin Female D Subconnector Cable C227A SEL 300G to Modem GND 5 TXD 3 RTS 7 RXD 2 GND 9 CTS 8 7 GND 2 TXD IN 20 DTDR IN 3 RXD OUT 1 GND 8 CD OUT SEL 300G Relay 9 Pin Male D Subconnector DCE Device 25 Pin Female D Subconnector Cable C222 DTE Data Terminal Equipm...

Page 474: ...D 2 RXD 3 TXD 7 RTS 8 CTS 9 GND SEL PRTU 9 Pin Male Round Conxall SEL 300G Relay 9 Pin Male D Subconnector Cable C231 SEL 300G to SEL Communications Processors RXD 2 TXD 3 IRIG 4 GND 5 IRIG 6 RTS 7 CTS 8 3 TXD 2 RXD 4 IRIG 5 GND 6 IRIG 8 CTS 7 RTS SEL Communications Processor 9 Pin Male Round Conxall SEL 300G Relay 9 Pin Male D Subconnector Cable C273A ...

Page 475: ... of Fiber Optic Transceivers Contact SEL for more details on these devices COMMUNICATIONS PROTOCOL Hardware Protocol All EIA 232 serial ports support RTS CTS hardware handshaking RTS CTS handshaking is not supported on the EIA 485 Serial Port 1 To enable hardware handshaking use the SET P command or front panel SET push to set RTSCTS Y Disable hardware handshaking by setting RTSCTS N If RTSCTS N t...

Page 476: ... would become EVE 1 Enter Upper and lower case characters may be used without distinction except in passwords Note The ENTER key on most keyboards is configured to send the ASCII character 13 M for a carriage return This manual instructs you to press the ENTER key after commands which should send the proper ASCII code to the relay 2 The relay transmits all messages in the following format STX MESS...

Page 477: ... Distributed Port Switch Protocol LMD permits multiple SEL relays to share a common communications channel The protocol is selected by setting the port setting PROTO LMD See Appendix C SEL Distributed Port Switch Protocol for more information on SEL Distributed Port Switch Protocol LMD SEL Fast Meter Protocol SEL Fast Meter protocol supports binary messages to transfer metering and control message...

Page 478: ...PORT ACCESS LEVELS Commands can be issued to the relay via the serial port to view metering values change relay settings etc The available serial port commands are listed in Table 10 6 The commands can be accessed only from the corresponding access level as shown in Table 10 6 The access levels are Access Level 0 the lowest access level Access Level 1 Access Level B Access Level 2 the highest acce...

Page 479: ... Access Level 1 B or 2 in the Command Explanations subsection for more detail Enter the BAC command at the Access Level 1 prompt BAC Enter Access Level B When the relay is in Access Level B the relay sends the prompt Commands ACC through PUL in Table 10 6 are available from Access Level B For example enter the CLO command at the Access Level B prompt to close the circuit breaker CLO Enter The 2AC ...

Page 480: ...erial port commands in a lower access level The commands are shown in uppercase letters but they can also be entered with lowercase letters Table 10 6 Serial Port Command Summary Access Level Prompt Serial Port Command Command Description Corresponding Front Panel Pushbutton 0 ACC Go to Access Level 1 0 CAS Compressed ASCII configuration data 0 HELP Display available commands 1 2AC Go to Access Le...

Page 481: ... 300G3 The relay responds with Invalid Access Level if a command is entered from an access level lower than the specified access level for the command The relay responds Invalid Command to commands not listed above or entered incorrectly Many of the command responses display the following header at the beginning GENERATOR Date 03 05 97 Time 17 03 26 484 TERMINAL The definitions are GENERATOR This ...

Page 482: ...erate similarly ACC moves from Access Level 0 to Access Level 1 BAC moves from Access Level 1 to Access Level B 2AC moves from Access Level 1 or B to Access Level 2 Password Requirements and Default Passwords Passwords are required if the main board Password jumper is not in place Password jumper OFF Passwords are not required if the main board Password jumper is in place Password jumper ON Refer ...

Page 483: ...es directly to Access Level 1 The relay responds GENERATOR Date 01 17 98 Time 09 46 47 237 TERMINAL Level 1 The prompt indicates the relay is now in Access Level 1 The above two examples demonstrate how to go from Access Level 0 to Access Level 1 The procedure to go from Access Level 1 to Access Level B Access Level 1 to Access Level 2 or Access Level B to Access Level 2 is much the same with comm...

Page 484: ...history in Compressed ASCII format For details on this and other Compressed ASCII commands see Appendix E Compressed ASCII Commands DAT Command View Change Date DAT displays the date stored by the internal calendar clock If the date format setting DATE_F is set to MDY the date is displayed as month day year If the date format setting DATE_F is set to YMD the date is displayed as year month day To ...

Page 485: ...f the LER length of event report setting The relay saves up to twenty nine 15 cycle fifteen 30 cycle eight 60 cycle or two 180 cycle reports if the setting LER is 15 30 60 and 180 respectively The event summaries include the date and time the event was triggered the type of event the maximum phase current in the event the power system frequency the number of the active setting group and the front ...

Page 486: ...DATA ERROR If an IRIG B signal is present the relay synchronizes its internal clock with IRIG B It is not necessary to issue the IRI command to synchronize the relay clock with IRIG B Use the IRI command to determine if the relay is properly reading the IRIG B signal MET Command Metering Data The MET commands provide access to the relay metering data Metering quantities include phase voltages and ...

Page 487: ...ge is below 13 V the relay will display Nominal Frequency setting FNOM with an asterisk e g FRQ 60 on front panel Station DC VDC V Voltage at POWER terminals input into station battery monitor Volts Hertz V Hz Generator volts hertz percent of nominal voltage frequency Field Insulation Rf kOhms Generator field winding insulation resistance If 64FOPT EXT and 64FFLT Relay Word bit equals zero the ins...

Page 488: ...V0 MAG 905 199 6 096 4 286 7 911 0 008 0 004 ANG DEG 4 94 124 45 90 93 0 07 99 02 48 37 FREQ Hz 60 01 VDC V 122 5 V Hz percent 99 60 FIELD INSULATION Rf kOhms 16666 6 MET D Demand Metering The MET D command displays the demand and peak demand values of the following quantities Currents IA B C N IG 3I2 Input currents A primary Residual ground current A primary IG 3I0 IA IB IC Negative sequence curr...

Page 489: ...l Metering Models 0300G1 and 0300G3 The MET DIF command displays the following differential element quantities Operate Currents A B and C phase IOP1 IOP2 and IOP3 respectively in multiples of TAP and percent of their respective restraint quantities Restraint Currents A B and C phase IRT1 IRT2 and IRT3 respectively in multiples of TAP Second Harmonic Currents A B and C phase I1F2 I2F2 and I3F2 resp...

Page 490: ...4 7 4 7 14 1 LAST RESET 01 19 98 16 50 09 245 For more information on energy metering see Energy Metering in Section 8 Monitoring and Metering Functions MET M Maximum Minimum Metering The MET M command displays the maximum and minimum values of the following quantities Currents IA B C N Input currents A primary IG Residual ground current A primary IG 3I0 IA IB IC IA87 B87 C87 Input currents A prim...

Page 491: ...8 726 21 4 01 19 98 16 58 15 446 MVAR3P 2 1 01 19 98 20 07 20 752 0 0 01 19 98 16 55 37 509 LAST RESET 01 19 98 16 49 41 243 All values will display RESET until new maximum minimum values are recorded For more information on maximum minimum metering see Maximum Minimum Metering in Section 8 Monitoring and Metering Functions MET RD Reset the accumulated demand values using the MET RD command MET RE...

Page 492: ...s Generator time of operation in 0 1 Hz frequency bands from 40 0 to 69 9 Hz To view the generator operation profile enter the command PRO Enter The output from an SEL 300G is shown PRO Enter GENERATOR Date 01 17 98 Time 09 47 45 114 TERMINAL 81AC Off Frequency Time Accumulators Since 01 17 98 09 46 Frequency Band 1 59 5 to 58 8 0 0s or 0 0 of limit setting Frequency Band 2 58 8 to 58 0 0 0s or 0 ...

Page 493: ... 00 0 00 00 00 0 00 00 00 0 00 00 00 69 5 69 6 69 7 69 8 69 9 0 00 00 00 0 00 00 00 0 00 00 00 0 00 00 00 0 00 56 56 Section 8 Monitoring and Metering Functions provides additional information on the SEL 300G generator operating profile function QUI Command Quit Access Level The QUI command returns the relay to Access Level 0 To return to Access Level 0 enter the command QUI Enter The relay sets t...

Page 494: ... append an A to the SHO command e g SHO 1 A Following are sample SHOWSET commands for the SEL 300G model 0300G10 showing all the setting categories The settings for the other SEL 300G models are similar SHO Enter Group 1 RID GENERATOR TID TERMINAL CTR 100 CTRD 100 CTRN 100 PTR 100 00 PTRN 100 00 PTRS 100 00 VNOM 115 0 INOM 5 0 EBUP D ELE N E24 Y E25 Y E27 Y E32 Y E40 Y E46 Y E50 Y E50_87 N E51 Y E...

Page 495: ...TURN to continue UBND1 59 5 LBND1 58 8 TBND1 3000 00 LBND2 58 0 TBND2 540 00 LBND3 57 5 TBND3 100 00 LBND4 57 0 TBND4 14 00 LBND5 56 5 TBND5 2 40 LBND6 40 0 TBND6 1 00 62ACC 0 16 ONLINE 27B81 3PO TAP1 5 00 TAPD 5 00 U87P 10 0 O87P 0 30 SLP1 40 87B 0 RTDOPT NONE DMTC 15 PDEMP 5 50 NDEMP 1 00 GDEMP 1 00 QDEMP 2 50 INAD SV2T 50L INADPU 0 25 INADDO 0 13 SV1 27V1 40Z2 Press RETURN to continue SV1PU 0 2...

Page 496: ...R2 TR2 TR3 SV3 LT1 ULTR3 TR3 TR4 SV3 ULTR4 TR4 CLEN 1 CL 0 ULCL 1 CLSD 0 00 ER 24C2 32P1 46Q2 51N 51C 51V 64G1 64G2 60LOP 81D1 81D2 81D1 81D2 BNDA BNDT INAD OUT101 TRIP1 Press RETURN to continue OUT102 TRIP2 OUT103 TRIP3 OUT104 TRIP4 OUT105 CLOSE OUT106 60LOP OUT107 24D1T 46Q1T BCW BNDA BNDT DCLO DCHI OUT201 0 OUT202 0 OUT203 0 OUT204 0 OUT205 0 OUT206 0 OUT207 0 OUT208 0 OUT209 0 OUT210 0 OUT211 ...

Page 497: ...B3 NLB4 NLB5 NLB6 Press RETURN to continue NLB7 NLB8 NLB9 NLB10 NLB11 NLB12 NLB13 NLB14 NLB15 NLB16 FP_I Y FP_VPP Y FP_VP N FP_MW Y FP_FR Y FP_87 N DP1 IN101 DP1_1 GEN BKR CLOSED DP1_0 GEN BKR OPEN DP2 IN102 DP2_1 FIELD BKR CLOSED DP2_0 FIELD BKR OPEN DP3 SG1 DP3_1 GROUP 1 ACTIVE DP3_0 GROUP 2 ACTIVE DP4 SV2T Press RETURN to continue DP4_1 INAD ARMED DP4_0 DP5 LT2 DP5_1 INAD TRIP DP5_0 DP6 LT1 DP6...

Page 498: ...TR TRIPPED RESET ALIAS7 TRIP3 PRIME_MVR_TR TRIPPED RESET ALIAS8 TRIP4 86_TRIP TRIPPED RESET ALIAS9 BNDA FREQ_AC_AL ALARM RESET ALIAS10 BNDT FREQ_AC_TR TRIPPED RESET Press RETURN to continue ALIAS11 LB1 LCL_SHUTDOWN TRIP RESET ALIAS12 RB1 REM_SHUTDOWN TRIP RESET ALIAS13 LT3 DC_FAULT FAULT RESET ALIAS14 DP3 GROUP_CHANGE GROUP_1_ACTIVE GROUP_2_ACTIVE ALIAS15 TRGTR TARGET_RESET PRESSED RELEASED ALIAS1...

Page 499: ...voltages in millivolts for the current and voltage channels The MOF master status is the dc offset in the A D circuit when a grounded input is selected PS PS Power Supply displays power supply voltages in Vdc for the power supply outputs TEMP Displays the internal relay temperature in degrees Celsius RAM ROM CR_RAM critical RAM and EEPROM These tests verify the relay memory components The columns ...

Page 500: ...ay Word bits and are listed in rows of eight called Relay Word rows For additional information on individual Relay Word bits refer to Section 4 SELOGIC Control Equations A Relay Word bit is either at a logical 1 asserted or a logical 0 deasserted Relay Word bits are used in SELOGIC control equations See Section 6 Enter Relay Settings and Section 4 SELOGIC Control Equations The serial port TAR comm...

Page 501: ...the specific Relay Word bit name If n is not specified the last default row is displayed k specifies a repeat count of the command for the serial port display The default is 1 X allows remapping of the LEDs to a Relay Word row without changing the default row The default row number returns to 0 when the serial port times out the QUI command is executed or the TAR R command is executed The front pa...

Page 502: ... TAR 13 BKMON BCW BCWA BCWB BCWC FAULT DCLO DCHI TAR 14 81D1 81D2 81D3 81D4 81D5 81D6 3PO 52A TAR 15 81D1T 81D2T 81D3T 81D4T 81D5T 81D6T 27B81 50L TAR 16 ONLINE BND1A BND1T BND2A BND2T BND3A BND3T BNDA TAR 17 TRGTR BND4A BND4T BND5A BND5T BND6A BND6T BNDT TAR 18 TRIP TRIP1 TRIP2 TRIP3 TRIP4 OC1 OC2 OC3 TAR 19 TR1 TR2 TR3 TR4 ULTR1 ULTR2 ULTR3 ULTR4 TAR 20 LB1 LB2 LB3 LB4 LB5 LB6 LB7 LB8 TAR 21 LB9...

Page 503: ...RST13 RST14 RST15 RST16 TAR 50 LT1 LT2 LT3 LT4 LT5 LT6 LT7 LT8 TAR 51 LT9 LT10 LT11 LT12 LT13 LT14 LT15 LT16 TAR 52 OTHTRIP OTHALRM AMBTRIP AMBALRM BRGTRIP BRGALRM WDGTRIP WDGALRM TAR 53 RTDFLT 2600IN TAR 54 RTD4TR RTD4AL RTD3TR RTD3AL RTD2TR RTD2AL RTD1TR RTD1AL TAR 55 RTD8TR RTD8AL RTD7TR RTD7AL RTD6TR RTD6AL RTD5TR RTD5AL TAR 56 RTD12TR RTD12AL RTD11TR RTD11AL RTD10TR RTD10AL RTD9TR RTD9AL Comm...

Page 504: ...989 TERMINAL Event TRIG Frequency 60 00 Targets Currents A Pri ABCNGQ 1 1 1 1 2 1 See Section 11 Event Reports and SER Functions for more information on event reports Access Level B Commands CLO Command Close Breaker The CLO Close command asserts the CLOSE Relay Word bit if CLEN logical 1 which can be programmed to an output contact e g OUT105 CLOSE to close circuit breakers See Figure 4 8 To issu...

Page 505: ...rol For example assume setting Group 1 is the active setting group and the SS1 setting is asserted to logical 1 e g SS1 IN104 and optoisolated input IN104 is asserted An attempt to change to setting Group 2 with the GRO 2 command will not be accepted GRO 2 Enter No group change see manual Active Group 1 For more information on setting group selection see Section 4 SELOGIC Control Equations OPE n C...

Page 506: ...Table 5 6 If the Breaker is not in place Breaker jumper OFF the relay does not execute the PUL command and responds Aborted No Breaker Jumper The relay generates an event report if any of the OUT101 through OUT107 contacts or OUT201 through OUT212 Models 0300G_1 are pulsed The PUL command is used primarily for testing purposes Access Level 2 Commands BRE n Command Preload Reset Breaker Wear Use th...

Page 507: ...Control subcommand you wish to perform see Table 10 8 The following example shows the steps necessary to pulse Remote Bit 5 RB5 CON 5 Enter CONTROL RB5 PRB 5 Enter You must enter the same remote bit number in both steps in the command If the bit numbers do not match the relay responds Invalid Command Table 10 8 SEL 300G Relay Control Subcommands Subcommand Description SRB n Set Remote Bit n ON pos...

Page 508: ...AS Command View Change Passwords PAS allows you to inspect or change existing passwords The factory default passwords for Access Levels 1 B and 2 are Access Level Factory Default Password 1 OTTER B EDITH 2 TAIL To inspect passwords type PAS Enter 1 OTTER B EDITH 2 TAIL WARNING This device is shipped with default passwords Default passwords should be changed to private passwords at installation Fai...

Page 509: ...d jumper ON Refer to Table 5 6 for Password jumper information If you wish to disable password protection for a specific access level even if Password jumper is not in place Password jumper OFF simply set the password to DISABLE For example PAS 1 DISABLE disables password protection for Level 1 SET Command Change Settings The SET command allows the user to view or change the relay settings see Tab...

Page 510: ...e proper access level to execute the command Move to the correct Access Level using the ACC BAC and 2AC commands and associated passwords Invalid Command Any Command Command was not recognized by the relay Use the HELP command to find the commands available at the present Access Level Invalid Command COPY Copy source or destination is unknown Use COPY 1 2 to copy from Group 1 settings to Group 2 o...

Page 511: ... or detected by relay Verify cabling and connections then retry the command No group change see manual GROUP SS1 or SS2 asserted during group change SS1 and SS2 control equations have precedence over serial port command group selection Verify that SS1 or SS2 should be asserted at this time based on your application No SER Data SER The SER data buffer is empty Execute the SER command again after on...

Page 512: ......

Page 513: ...rrent wear CEV n Show compressed event report number n with 1 4 cycle resolution You can use parameters Ly SEC Sx R C and DIF with CEV similar to EVE commands described later Use CEV commands to save event reports for SEL 5601 Analytic Assistant CHIS Show compressed history CST Show compressed status report DAT Show date DAT m d y Enter date in this manner if Date Format setting DATE_F MDY DAT y m...

Page 514: ... Access Level 0 Terminate Distributed Port Switch Protocol connection SER m n Show rows m through n in the Sequential Events Recorder SER event report SER n Show the latest n rows in the Sequential Events Recorder SER event report SER d1 Show rows in the Sequential Events Recorder SER event report from date d1 SER d1 d2 Show rows in the Sequential Events Recorder SER event report from date d1 to d...

Page 515: ...cess Level 1 and Access Level B commands are available from Access Level 2 The screen prompt is BRE n Enter BRE W to preload breaker wear Enter BRE R to reset breaker monitor data CON n Control Relay Word bit RBn Remote Bit n n 1 through 8 Execute CON n and the relay responds CONTROL RBn Then reply with one of the following SRB n set Remote Bit n assert RBn CRB n clear Remote Bit n deassert RBn PR...

Page 516: ......

Page 517: ...ime Average 11 21 Reset the Breaker Close Time Average 11 22 Example Standard 15 Cycle Event Report 11 22 Example Sequential Events Recorder SER Report 11 31 Differential Event Report Headers 11 32 TABLES Table 11 1 Event Types 11 4 Table 11 2 Standard Event Report Current Voltage and Frequency Columns 11 7 Table 11 3 Output Input and Protection and Control Element Event Report Columns 11 8 Table ...

Page 518: ......

Page 519: ...n example standard 15 cycle event report The relay adds lines in the SER report for a change of state of a programmable condition The SER lists date and time stamped lines of information each time a programmed condition changes state The relay stores the latest 512 lines of the SER report in nonvolatile memory If the report fills up newer rows overwrite the oldest rows in the report See Figure 11 ...

Page 520: ...rt if the SEL 300G is not already generating a report that encompasses the new transition The factory setting is ER 24C2 32P1 46Q2 51N 51C 51V 64G1 64G2 60LOP 81D1 81D2 81D1 81D2 BNDA BNDT INAD Note the rising edge operator in front of some of these elements Rising edge operators are especially useful in generating an event report at fault inception and then generating another later if a breaker f...

Page 521: ...summary in the standard event report The identifiers date and time appear at the top of the standard event report and the other information follows See Figure 11 2 The example event summary in Figure 11 1 corresponds to the full length standard 15 cycle event report in Figure 11 2 Note Figure 11 2 is on multiple pages GENERATOR Date 01 30 00 Time 10 20 24 811 TERMINAL Event TRIP Frequency 60 16 Ta...

Page 522: ...nnel IC Neutral N channel IN Calculated residual IG 3I0 calculated from channels IA IB and IC Negative sequence Q 3I2 calculated from channels IA IB and IC Retrieving Full Length Standard Event Reports The latest event reports are stored in nonvolatile memory Each event report includes four sections Current voltage station battery frequency contact outputs optoisolated inputs Protection and contro...

Page 523: ...r detail GND Specifies a special report for Stator Ground element 64G This report shows rms secondary magnitudes of third harmonic neutral third harmonic terminal and fundamental neutral voltages at quarter cycle intervals It also includes status of related elements See Figure 11 3 for a typical EVE GND report Below are example EVE commands Serial Port Command Description EVE Display the most rece...

Page 524: ...he relay select the unfiltered event report e g EVE R Use the unfiltered event reports to observe Power system harmonics on channels IA IB IC IN VA VB VC VN Decaying dc offset during fault conditions on IA IB IC Optoisolated input contact bounce on IN101 through IN106 Transients on the station dc battery channel Vdc power input terminals Z25 and Z26 The filters for ac current voltage and station b...

Page 525: ...measured by channel VS primary kV Vdc Voltage measured at power input terminals Z25 and Z26 Vdc Freq Frequency of channel VA Hz Note that the ac values change from plus to minus values in Figure 11 2 indicating the sinusoidal nature of the waveforms Other figures help in understanding the information available in the event report current columns Figure 11 4 shows how event report current column da...

Page 526: ...Output contact OUT107 asserted A Output contact ALARM asserted Out 7A b Both OUT107 and ALARM asserted IN101 IN102 1 Optoisolated input IN101 asserted 2 Optoisolated input IN102 asserted In 12 b Both IN101 and IN102 asserted IN103 IN104 3 Optoisolated input IN103 asserted 4 Optoisolated input IN104 asserted In 34 b Both IN103 and IN104 asserted IN105 IN106 5 Optoisolated input IN105 asserted 6 Opt...

Page 527: ...ANG2 setting b Both 25A1 and 25A2 are picked up 25A C 25C picked up GENVHI GENVLO GENVHI picked up indicating generator voltage is higher than system voltage GENV GENVLO picked up indicating generator voltage is lower than system voltage GENFHI GENFLO GENFHI picked up indicating slip frequency greater than 25SHI setting GENF GENFLO picked up indicating slip frequency less than 25SLO setting 27P1 2...

Page 528: ... picked up 32P2T timed out 40Z1 40Z1T 1 Zone 1 loss of field element picked up 40Z1 Z 40Z1 picked up 40Z1T timed out 40Z2 40Z2T 2 Zone 2 loss of field element picked up 40Z2 Z 40Z2 picked up 40Z2T timed out 46Q1 46Q1T 1 Negative sequence definite time overcurrent element 46Q1 picked up 46Q1 Q 46Q1 picked up 46Q1T timed out 46Q2 46Q2T 46Q2R 2 Negative sequence inverse time overcurrent element 46Q2 ...

Page 529: ...ercurrent element picked up b B Phase Level 2 instantaneous 87 input phase overcurrent element picked up c C Phase Level 2 instantaneous 87 input phase overcurrent element picked up Two or more Level 2 instantaneous 87 input phase overcurrent elements picked up 50H2 H Level 2 87 input phase overcurrent element picked up and time delay expired 50Q1 50Q2 1 Level 1 instantaneous 87 input negative seq...

Page 530: ...1V 51VT 51VR v Voltage restrained time overcurrent element picked up and timing V Voltage restrained time overcurrent element timed out 51V r Time overcurrent element reset 59P1 59P2 1 Level 1 instantaneous phase overvoltage element picked up 2 Level 2 instantaneous phase overvoltage element picked up 59P b Both Level 1 and Level 2 phase overvoltage elements picked up 59V1 59V1 V Positive sequence...

Page 531: ... out T64G T64G T Relay Word T64G asserted N64G N64G N Relay Word N64G asserted SWING S The Relay Word bit SWING picked up OOS O The Relay Word bit OOS picked up 78 OOST T The Relay Word bit OOST picked up 81D1 81D2 81D3 1 Frequency element 81D1 asserted 81D4 81D5 81D6 2 Frequency element 81D2 asserted 3 Frequency element 81D3 asserted 4 Frequency element 81D4 asserted 5 Frequency element 81D5 asse...

Page 532: ... asserted LB3 LB4 3 Local bit LB3 asserted 4 Local bit LB4 asserted LCL34 b Both LB3 and LB4 asserted LB5 LB6 5 Local bit LB5 asserted 6 Local bit LB6 asserted LCL56 b Both LB5 and LB6 asserted LB7 LB8 7 Local bit LB7 asserted 8 Local bit LB8 asserted LCL78 b Both LB7 and LB8 asserted RB1 RB2 1 Remote bit RB1 asserted 2 Remote bit RB2 asserted REM12 b Both RB1 and RB2 asserted RB3 RB4 3 Remote bit...

Page 533: ...meter element QDEM picked up DEMPQ PDEM QDEM b Both PDEM and QDEM picked up NDEM GDEM N Neutral ground demand ammeter element NDEM picked up G Residual ground demand ammeter element GDEM picked up DEMNG b Both NDEM and GDEM picked up TR1 TR2 1 Trip bit TRIP1 asserted 2 Trip bit TRIP2 asserted TR12 b Both TRIP1 and TRIP2 asserted TR3 TR4 3 Trip bit TRIP3 asserted 4 Trip bit TRIP4 asserted TR34 b Bo...

Page 534: ...and was retrieved with the EVE DIF command The columns contain ac current differential element output input and operate restraint and second harmonic current magnitude information Current Columns Table 11 4 summarizes the differential event report current columns Table 11 4 Differential Event Report Current Columns Column Heading Definition IA Current measured by channel IA primary A IB Current me...

Page 535: ...7 asserted A Output contact ALARM asserted b Both OUT107 and ALARM asserted In 12 IN101 IN102 1 Optoisolated input IN101 asserted 2 Optoisolated input IN102 asserted b Both IN101 and IN102 asserted In 34 IN103 IN104 3 Optoisolated input IN103 asserted 4 Optoisolated input IN104 asserted b Both IN103 and IN104 asserted In 56 IN105 IN106 5 Optoisolated input IN105 asserted 6 Optoisolated input IN106...

Page 536: ...element changes state the relay time tags the changes in the SER For example setting SER1 contains time overcurrent element pickups 51N and 51C instantaneous overcurrent element 50N1 Thus any time one of these overcurrent elements picks up or drops out the relay time tags the change in the SER The relay adds a message to the SER to indicate power up or settings change to active setting group condi...

Page 537: ... bottom of the report Reverse chronological progression through the report is down the page and in ascending row number SER 3 30 97 If SER is entered with one date following it date 3 30 97 in this example all the rows on that date are displayed if they exist They display with the oldest row at the beginning top of the report and the latest row at the end bottom of the report for the given date Ch...

Page 538: ...ects phase for the Generator Voltage based on the SYNCP setting and reports its magnitude after compensating for the 25RCF factor see VPc in Figure 4 10 SYN Enter GENERATOR Date 06 23 98 Time 13 35 12 975 TERMINAL CLOSE 25C 25A1 25A2 Asserted At 06 23 98 13 08 09 609 Synch Check Conditions when CLOSE Asserted Slip Freq 0 12Hz Generator Freq 60 11Hz System Freq 59 99Hz Voltage Diff 1 96 Generator V...

Page 539: ... you review a SYN report from a 25C supervised CLOSE the slip compensated angle should closely equal the CANGLE setting The slip compensated angle tells us what the relay expects the phase angle to be when the breaker actually closes TCLOSD seconds after CLOSE initiation SYN Report Closure For the vast majority of breaker close operations the breaker will close and the three pole open condition 3P...

Page 540: ... The circled numbers in Figure 11 2 correspond to the SER row numbers in Figure 11 6 The row explanations follow Figure 11 6 In Figure 11 2 the arrow in the column following the Freq column identifies the trigger row This is the row that corresponds to the Date and Time values at the top of the event report The asterisk in the column following the Freq column identifies the row with the maximum ph...

Page 541: ... 01 b 1016 396 1238 33 1858 7 9 3 1 9 6 4 6 123 60 01 b 11 974 60 628 236 286 7 5 0 5 4 9 0 7 123 60 01 bb b 996 398 1250 38 1848 7 7 3 1 9 7 4 6 123 60 01 bb b 994 68 606 235 320 7 7 0 5 4 7 0 8 123 60 01 bb b 980 394 1264 42 1850 7 6 3 0 9 8 4 5 123 60 01 bb b 12 1014 72 580 235 362 7 8 0 6 4 5 0 8 123 60 01 bb b 960 394 1270 46 1836 7 5 3 0 9 9 4 5 123 60 01 bb b 620 0 626 234 6 7 9 0 6 4 4 0 9...

Page 542: ...1 V 3 bb T r 1 r 1 nrr 1 V 3 bb T Two cycles of data not shown in this example 15 r 1 r 1 nrr 1 V 3 bb T r 1 r 1 nrr 1 V 3 bb T r 1 r 1 nrr 1 V 3 bb T r 1 r 1 nrr 1 V 3 bb T Event TRIG Frequency 60 01 Targets Currents A Pri ABCNGQ 1471 424 1336 181 1880 112 Group 1 Settings RID GENERATOR TID TERMINAL CTR 100 CTRN 100 PTR 100 PTRN 100 VNOM 115 0 INOM 5 0 EBUP D E24 Y E27 Y E32 Y E40 Y E46 Y E50 Y E...

Page 543: ... 0 64G1D 0 75 64G2P 2 5 64RAT 1 0 64G2D 0 08 64GTC 1 78FWD 8 0 78REV 8 0 78R1 6 0 78R2 6 0 78TD 0 00 78TDURD 3 00 50ABC 0 25 OOSTC 1 27B81P 20 00 81D1P 59 10 81D1D 0 03 UBND1 59 5 LBND1 58 8 TBND1 3000 00 LBND2 58 0 TBND2 540 00 LBND3 57 5 TBND3 100 00 LBND4 57 0 TBND4 14 00 LBND5 56 5 TBND5 2 40 LBND6 40 0 TNBD6 1 00 62ACC 0 16 ONLINE 27B81 3PO 87N1P 0 50 87N1D 0 10 87N2P 1 50 87N2D 0 00 87NTC 1 ...

Page 544: ... SV3 SV4 ULTR2 TR2 TR3 SV3 LT1 ULTR3 TR3 TR4 SV3 ULTR4 TR4 CLEN 1 CL 0 ULCL 1 CLSD 0 00 ER 24C2 32P1 46Q2 51N 51C 51V 64G1 64G2 60LOP 81D1 81D2 81D1 81D2 BNDA BNDT INAD OUT101 TRIP1 OUT102 TRIP2 OUT103 TRIP3 OUT104 TRIP4 OUT105 CLOSE OUT106 60LOP OUT107 24D1T 46Q1T BCW BNDA BNDT DCLO DCHI OUT201 0 OUT202 0 OUT203 0 OUT204 0 OUT205 0 OUT206 0 OUT207 0 OUT208 0 OUT209 0 OUT210 0 OUT211 0 OUT212 0 Gl...

Page 545: ...B10 NLB11 NLB12 NLB13 NLB14 NLB15 NLB16 FP_I Y FP_VPP Y FP_VP N FP_MW Y FP_FR Y DP1 IN101 DP1_1 GEN BKR CLOSED DP1_0 GEN BKR OPEN DP2 IN102 DP2_1 FIELD BKR CLOSED DP2_0 FIELD BKR OPEN DP3 SG1 DP3_1 GROUP 1 ACTIVE DP3_0 GROUP 2 ACTIVE DP4 SV2T DP4_1 INAD ARMED DP4_0 DP5 LT2 DP5_1 INAD TRIP DP5_0 DP6 LT1 DP6_1 SHUTDOWN TRIP DP6_0 DP7 LT5 DP7_1 AB OP TRIP DP7_0 DP8 0 DP8_1 DP8_0 DP9 0 DP9_1 DP9_0 DP1...

Page 546: ...2 05 2 52 0 01 2 05 2 52 0 00 Thirteen cycles of data not shown in this example 15 4 04 0 65 0 09 2 N 4 03 0 65 0 09 2 N 4 05 0 75 0 08 2 N 4 04 0 75 0 08 2 N Figure 11 3 Example EVE GND Command Report Figure 11 4 and Figure 11 5 look in detail at 1 cycle of A phase current channel IA identified in Figure 11 2 Figure 11 4 shows how the event report ac current column data relates to the actual samp...

Page 547: ...A peak 2 1472 A RMS multiply by 2 1 940 842 906 1160 multiply by 2 1 1329 1190 1281 1640 IA peak 2081 A peak 940 842 906 1160 I A cyc 1 4 t Figure 11 4 Derivation of Event Report Current Values and RMS Current Values From Sampled Current Waveform In Figure 11 4 note that any two rows of current data from the event report in Figure 11 2 1 4 cycle apart can be used to calculate rms current values ...

Page 548: ...40 842 906 1160 event report column DWG M300G154 906 1160 2 2 1472 X present sample Y previous 1 4 cycle Magnitude X 1160 Y 906 Real Axis Axis Imaginary Angle Arctan Arctan Y X 38 0 o 906 1160 IA cyc 1 4 t Figure 11 5 Derivation of Phasor RMS Current Values From Event Report Current Values ...

Page 549: ... 09 58 714 86_TRIP TRIPPED 17 01 20 98 09 09 58 714 PRIME_MVR_TR TRIPPED 16 01 20 98 09 09 58 714 FIELD_BKR_TR TRIPPED 15 01 20 98 09 09 58 714 GEN_MAIN_TR TRIPPED 14 01 20 98 09 09 58 714 FAULT_TRIP TRIPPED 13 01 20 98 09 09 58 760 GEN_MAIN_BKR OPENED 12 01 20 98 09 09 58 810 60LOP Asserted 11 01 20 98 09 09 58 826 51N Deasserted 10 01 20 98 09 09 58 826 50N1T Deasserted 9 01 20 98 09 09 58 826 5...

Page 550: ... to declining generator phase voltages 11 10 9 8 7 Declining neutral current allows the 51N 50N1 and 50N1T neutral overcurrent elements to deassert This allows the SV3 variable FAULT_TRIP to deassert The field circuit breaker auxiliary contact connected to IN102 opens deasserting the input and causing the message FIELD_BKR OPENED 6 Declining neutral voltage allows the 64G1 element to deassert 5 4 ...

Page 551: ...4X Z001001 D20000217 CID 04B0 8 7 Out In Currents Amps Pri UB 1357 135 IA IB IC IA87 IB87 IC87 RL 246A 246 1 488 1824 1332 486 1823 1333 7 1820 488 1333 1816 488 1334 7 488 1824 1332 487 1823 1334 7 1821 488 1333 1816 488 1334 7 2 Differential Current Magnitudes and Control Elements 8 8 8 Operate Restraint 2nd Harm 7 7 7 8 Multiples of TAP U R B 7 I1 I2 I3 I1 I2 I3 I1 I2 I3 123 123 123 B 1 0 00 0 ...

Page 552: ......

Page 553: ...e 20060731 TABLE OF CONTENTS SECTION 12 MAINTAIN AND TROUBLESHOOT RELAY 12 1 Relay Maintenance Testing 12 1 Relay Misoperation 12 2 Relay Troubleshooting 12 3 Inspection Procedure 12 3 Troubleshooting Procedure 12 3 Relay Calibration 12 4 ...

Page 554: ......

Page 555: ... the relay protection elements are operating properly Using the event report input and output data you can determine that the relay is asserting outputs at the correct instants and that auxiliary equipment is operating properly We recommend you review all relay event reports and perform detailed reviews of reports for operations that are not nominal Periodically verify that the relay is making cor...

Page 556: ...isplay messages from the front panel LCD display 3 Press the front panel STATUS pushbutton If the relay STATUS is OK continue with Step 4 If STATUS indicates a WARN or FAIL condition use the Up and Down arrow pushbuttons and note the failed self test condition Contact the factory or your local Technical Service Center for assistance 4 Using a PC establish Access Level 1 communication with the rela...

Page 557: ...inputs 4 Measure and record the state of all output relays Troubleshooting Procedure All Front Panel LEDs Dark 1 Input power not present or fuse is blown 2 Self test failure Cannot See Characters on Relay LCD Screen 1 Relay is de energized Check to see if the ALARM contact is closed 2 LCD contrast is out of adjustment Use the steps below to adjust the contrast a Remove the relay front panel by rem...

Page 558: ...board loose or defective 5 Failed relay self test RELAY CALIBRATION The SEL 300G Relay is factory calibrated If you suspect that the relay is out of calibration please contact the factory FACTORY ASSISTANCE We appreciate your interest in SEL products and services If you have questions or comments please contact us at Schweitzer Engineering Laboratories Inc 2350 NE Hopkins Court Pullman WA USA 9916...

Page 559: ...nt Transformer Connection and Ratio Compensation 13 16 Restrained Differential Element Operating Characteristics 13 17 TABLES Table 13 1 Connection and TAP Compensation 13 16 FIGURES Figure 13 1 87N Element Logic Diagram 13 3 Figure 13 2 Fundamental and Second Harmonic Filters Provide Current Inputs to Differential Elements 13 4 Figure 13 3 Operate Restraint and Second Harmonic Blocking Current Ca...

Page 560: ......

Page 561: ...ed they cannot provide ground fault coverage for 100 percent of the stator windings They do however offer selective ground fault protection because they do not respond to ground faults beyond the generator phase current transformers This quality makes the element well suited to protect generators connected to multiple unit buses or for generators connected to a load bus such as might be found in a...

Page 562: ... severe external fault Level 2 Ground Differential Pickup 0 1 CTR CTRN 15 A 5 A models 87N2P 1 5 0 02 CTR CTRN 3 A 1 A models Level 2 Ground Differential Time Delay 0 00 to 400 00 s 87N2D 0 00 Set the 87N2P element less sensitively to detect severe ground faults high in the generator windings or on the generator bushings The higher overcurrent setting allows a shorter or zero time delay 87N Elemen...

Page 563: ...em during the generator fault increases the relay sensitivity When the protected generator is connected to a bus which can source ground fault current set 87N2P approximately equal to I diff calculated above 87N1P can be set more sensitively to achieve additional sensitivity and operate with time delay for external fault security Ground Differential Element Tripping Because the ground differential...

Page 564: ...tion function includes a sensitive percentage restrained differential element and an unrestrained element that must be set less sensitively When E87 G or T the relay measures the fundamental frequency currents from the phase inputs IA1 IB1 and IC1 and the differential inputs IA871 IB871 and IC871 See Figure 13 2 The relay also measures the second harmonic current quantities for each set of inputs ...

Page 565: ...Calculations The front panel and serial port METER DIF commands report the present values of IOP1 IOP2 IOP3 IRT1 IRT2 and IRT3 in multiples of TAP These magnitudes also are reported in the differential format event report obtained using the EVE DIF serial port command The METER DIF command response also reports the operate currents in per unit of the individual restraint currents These values are ...

Page 566: ...LP1 SLP2 100 87U2 87U3 _ IRT1 Restraint Current PCT2 OFF Setting 0 1 Second Harmonic Blocking Current I1F2 _ 87BL1 87BL2 87BL3 similar 87R2 87R3 similar 87U2 87U3 similar IRS1 Setting I1F2 100 PCT2 IRT1 SLP1 100 Figure 13 4 Differential Element Logic Diagram 87R1 87R2 87B 87R Relay Word Bit DWG M300G168 87R3 Relay Word Bits Setting Figure 13 5 Restrained Differential Element Logic When E87 G ...

Page 567: ...169 87R3 Relay Word Bit Relay Word Bits 87BL1 87BL2 87B Setting 87BL3 Figure 13 6 Restrained Differential Element Logic When E87 T and IHBL N 87R1 87BL1 87R DWG M300G170 Setting 87B 87R2 87BL2 87R3 87BL3 Relay Word Bits Relay Word Bit Figure 13 7 Restrained Differential Element Logic When E87 T and IHBL Y ...

Page 568: ...d below Enable Differential Protection G T N E87 G Set E87 G to enable differential protection elements in most generator differential applications If differential protection is not required set E87 N When E87 N the 87B 87BL1 87BL2 87BL3 87R 87R1 87R2 87R3 87U 87U1 87U2 and 87U3 Relay Word bits are inactive and the following relay settings are hidden and do not need to be entered Phase Input TAP V...

Page 569: ...quation 87B 0 The percentage restrained differential element is disabled when the 87B SELOGIC control equation result is a logical 1 Most applications permit the 87 elements to be enabled all the time suggesting the 87B should be set to logical 0 When E87 G the relay hides the following settings and uses their default values in the element definition XFMR Connection TRCON GEN 87 Input CT Connectio...

Page 570: ...ncreases the required operate current in direct proportion to the measured restraint current by a settable amount SLP1 If the CT error for each of the two CTs is 10 and the relay differential measurement error is 5 then the minimum SLP1 setting is 25 Fixed Settings SLP2 IRS1 PCT2 When E87 G the relay fixes the values of SLP2 100 IRS1 3 per unit of TAP and PCT2 OFF These settings disable second har...

Page 571: ...C DABDAB DABY DACY TRCON DABY 87 Input CT Connection Y DAB DAC CTCON DAB Phase Input TAP Value TAP1 Derived Quantity 87 Input TAP Value TAPD Derived Quantity Unrestrained Element Pickup multiple of TAP 1 0 20 0 U87P 10 0 Restrained Element Pickup multiple of TAP 0 04 1 00 O87P 0 30 Restraint Slope 1 Percentage 5 100 SLP1 40 When a generator step up transformer is included in the differential zone ...

Page 572: ...OFF 50 200 SLP2 100 Restraint Slope 1 Limit multiple of TAP 1 0 16 0 IRS1 3 0 Second Harmonic Blocking Percent OFF 5 100 PCT2 12 Independent Harmonic Blocking Y N IHBL N The SLP2 and IRS1 settings define the second percentage restraint slope As shown in Figure 13 8 the SLP2 slope is effective when the measured restraint current is greater than IRS1 times TAP If a second slope is not desired set SL...

Page 573: ... nonpolarity side of the C phase CT See Appendix H Differential Connection Diagrams for example connection diagrams Derived Tap Settings TAP1 TAPD When E87 T and VWDGD is not OFF the relay derives the values of TAP1 and TAPD TAP1 automatically is set equal to the generator nominal current in secondary amps defined by the INOM setting TAPD is set equal to the same current placed in terms of seconda...

Page 574: ...reased sensitivity but high enough to avoid incorrect operation caused by steady state CT error Figure 13 8 shows that the O87P setting determines the minimum amount that the operate current must exceed the restraint current to cause a restrained differential trip If the current transformers on either side of the generator are sufficiently mismatched then it may be possible that load current or a ...

Page 575: ...ment second harmonic blocking level Setting PCT2 OFF disables second harmonic blocking and the relay hides the IHBL setting When PCT2 is not set to OFF if the differential current contains more than PCT2 percent of second harmonic due to magnetizing inrush or CT saturation the restrained differential element is blocked The unrestrained element is not affected In transformer differential applicatio...

Page 576: ... for certain combinations of CT and transformer connection Table 13 1 and the following discussion fully define the Connection and TAP Compensation referred to in Figure 13 3 Table 13 1 Connection and TAP Compensation TRCON CTCON CON1 CON2 GEN Y Y Y DACDAC Y Y Y DABDAB Y Y Y DABY DAB Y Y DACY DAC Y Y YY Y DAB DAB YDAC Y DAC Y YDAB Y DAB Y DABY Y Y DAB DACY Y Y DAC For CON1 Y I1W1F1 IA1 TAP1 I2W1F1...

Page 577: ...71 I187F1 TAPD 3 IA871 IB871 I287F1 TAPD 3 IB871 IC871 I387F1 TAP and connection compensation for the second harmonic currents is similar RESTRAINED DIFFERENTIAL ELEMENT OPERATING CHARACTERISTICS IRS1 IRT Multiples of TAP O87P U87P Multiples of TAP IOP SLP1 SLP2 87R Operate Region 87U Operate Region 87R Restraint Region DWG M300G171 Figure 13 8 Differential Element Operating Characteristics ...

Page 578: ......

Page 579: ...ay Self Tests B 15 H Verify Settings Calibration Status Breaker Wear and Metering B 17 I Return the Relay to Service B 19 Ethernet Port Firmware Upgrade Instructions B 19 Introduction B 19 Required Equipment B 20 Upgrade Procedure B 20 APPENDIX C SEL DISTRIBUTED PORT SWITCH PROTOCOL C 1 Settings C 1 Operation C 1 APPENDIX D CONFIGURATION FAST METER AND FAST OPERATE COMMANDS D 1 Introduction D 1 Me...

Page 580: ...S RTU COMMUNICATIONS PROTOCOL F 1 Introduction F 1 Modbus RTU Communications Protocol F 1 Modbus Queries F 1 Modbus Responses F 2 Supported Modbus Function Codes F 2 Modbus Exception Responses F 2 Cyclical Redundancy Check F 3 01h Read Coil Status Command F 3 02h Read Input Status Command F 5 03h Read Holding Register Command F 8 04h Read Input Registers Command F 9 05h Force Single Coil Command F...

Page 581: ...e Coil Command F 10 Table F 11 SEL 300G Relay Command Coils FC05h F 11 Table F 12 06h Preset Single Register Command F 12 Table F 13 07h Read Exception Status Command F 13 Table F 14 08h Loopback Diagnostic Command F 14 Table F 15 10h Preset Multiple Registers Command F 14 Table F 16 64h Scattered Register Read Command F 15 Table F 17 SEL 300G Relay Modbus Command Region F 16 Table F 18 Modbus Com...

Page 582: ...yed Window B 23 Figure H 1 Protected Generator With No Step Up Transformer H 1 Figure H 2 Delta Wye Power Transformer With Wye High Side CT Connections H 1 Figure H 3 Delta Wye Power Transformer With Wye High Side CT Connections H 2 Figure H 4 Delta Wye Power Transformer With Delta High Side CT Connections H 2 Figure H 5 Delta Wye Power Transformer With Delta High Side CT Connections H 3 Figure H ...

Page 583: ... SEL 300G Rxxx Vxxxxxxxxxx Zxxxxxx Dxxxxxxxx The firmware revision number is after the R and the release date is after the D The string of xs after SEL 300G is the firmware part number and depends on the features ordered with the relay refer to the SEL 300G Model Option Tables Model Option Tables can be obtained from the factory or from our website www selinc com For example FID SEL 300G R204 V00H...

Page 584: ...nth Revision Model SEL 0300G0Y Tenth Revision Improved 51V sensitivity by adding voltage measurement phase compensation introduced by delta wye step up transformers No settings changes 20060731 This firmware differs from the previous versions as follows SEL 300G R323 Z301301 D20060508 Model SEL 0300G30 Fourteenth Revision Model SEL 0300G31 Fourteenth Revision Model SEL 0300G20 Fourteenth Revision ...

Page 585: ...300G1Y Eighth Revision Model SEL 0300G0W Eighth Revision Model SEL 0300G0Y Eighth Revision Two wire EIA 485 Modbus communications improvements No Settings Changes 20041019 This firmware differs from the previous versions as follows SEL 300G R321 Z300300 D20040903 Model SEL 0300G30 Twelfth Revision Model SEL 0300G31 Twelfth Revision Model SEL 0300G20 Twelfth Revision Model SEL 0300G21 Twelfth Revis...

Page 586: ...sion Model SEL 0300G21 Eleventh Revision Model SEL 0300G10 Eleventh Revision Model SEL 0300G11 Eleventh Revision Model SEL 0300G00 Twelfth Revision Model SEL 0300G01 Twelfth Revision Model SEL 0300G3W Sixth Revision Model SEL 0300G3Y Sixth Revision Model SEL 0300G2W Sixth Revision Model SEL 0300G2Y Sixth Revision Model SEL 0300G1W Sixth Revision Model SEL 0300G1Y Sixth Revision Model SEL 0300G0W S...

Page 587: ...ixth Revision Model SEL 0300G2W Sixth Revision Model SEL 0300G2Y Sixth Revision Model SEL 0300G1W Sixth Revision Model SEL 0300G1Y Sixth Revision Model SEL 0300G0W Sixth Revision Model SEL 0300G0Y Sixth Revision Added File Transfer Capability for SEL 5030 Increased PTR Resolution Increased CTR and CTRD Range Increased VNOM Range for Y Connected PT Enhance 51VC Element added new setting 51VCA Added...

Page 588: ...Revision Model SEL 0300G3Y Fifth Revision Model SEL 0300G2W Fifth Revision Model SEL 0300G2Y Fifth Revision Model SEL 0300G1W Fifth Revision Model SEL 0300G1Y Fifth Revision Model SEL 0300G0W Fifth Revision Model SEL 0300G0Y Fifth Revision Added File Transfer Capability for SEL 5030 Increased PTR Resolution Increased CTR and CTRD Range Increased VNOM Range for Y Connected PT Enhance 51VC Element a...

Page 589: ...vision Model SEL 0300G1Y Fifth Revision Model SEL 0300G0W Fifth Revision Model SEL 0300G0Y Fifth Revision Added support for faster CPU Added Modbus RTU protocol 20020206 This firmware differs from the previous versions as follows SEL 300G R208 Z004003 D20011003 Model SEL 0300G30 Ninth Revision Model SEL 0300G31 Ninth Revision Model SEL 0300G20 Ninth Revision Model SEL 0300G21 Ninth Revision Model ...

Page 590: ...Model SEL 0300G21 Eighth Revision Model SEL 0300G10 Eighth Revision Model SEL 0300G11 Eighth Revision Model SEL 0300G00 Ninth Revision Model SEL 0300G01 Ninth Revision Model SEL 0300G3W Third Revision Model SEL 0300G3Y Third Revision Model SEL 0300G2W Third Revision Model SEL 0300G2Y Third Revision Model SEL 0300G1W Third Revision Model SEL 0300G1Y Third Revision Model SEL 0300G0W Third Revision M...

Page 591: ...Model SEL 0300G11 Seventh Revision Model SEL 0300G00 Eighth Revision Model SEL 0300G01 Eighth Revision Model SEL 0300G3W Second Revision Model SEL 0300G3Y Second Revision Model SEL 0300G2W Second Revision Model SEL 0300G2Y Second Revision Model SEL 0300G1W Second Revision Model SEL 0300G1Y Second Revision Model SEL 0300G0W Second Revision Model SEL 0300G0Y Second Revision Added compatibility with ...

Page 592: ...SEL 0300G1W First Revision Model SEL 0300G1Y First Revision Model SEL 0300G0W First Revision Model SEL 0300G0Y First Revision Display points increased from 8 to 16 Remote latch and local bits increased from 8 to 16 Revised miscellaneous items to improve the performance of the relay Added Out of Step Element 78 Added Connectorized Versions 0300G_W and 0300G_Y Added 110 Vdc Control Power Modified FI...

Page 593: ...1 D981204 Model SEL 0300G30 Second Revision Model SEL 0300G31 Second Revision Model SEL 0300G20 Second Revision Model SEL 0300G21 Second Revision Model SEL 0300G10 Third Revision Model SEL 0300G11 Third Revision Model SEL 0300G00 Fourth Revision Model SEL 0300G01 Fourth Revision Corrected scaling error in directional power and phase distance elements 1 A Models only Corrected positive sequence imp...

Page 594: ...Added 87N elements to 0300G0 0300G2 Removed 51P element from all models Added single phase overcurrent elements to 0300G1 0300G3 19980717 This firmware differs from the previous versions as follows SEL 300G R102 D980429 Model SEL 0300G10 First Revision Model SEL 0300G11 First Revision Model SEL 0300G00 Second Revision Model SEL 0300G01 Second Revision Corrected problem with 40 Loss of Field elemen...

Page 595: ...rom the previous version as follows 20060508 Section 1 Added Field Ground Protection 64F element information Section 2 Added Field Ground Protection 64F element information Section 4 Added new Relay Word bits Section 5 Added SEL 2664 information Setting Sheets Added settings for the 64F element Section 7 Added SEL 2664 information Section 10 Expanded descriptions of commands Appendix A Updated for...

Page 596: ... Added mounting information updated drawings Section 6 Revised Introduction Table 6 3 and Settings Sheets Section 7 Miscellaneous edits for clarification Section 8 Miscellaneous edits Section 9 Miscellaneous edits Section 10 Added CAS CEV n CHIS CST EVE SEC and EVE GND commands Section 11 Increased event report length added new Relay Word bits Section 12 Removed firmware upgrade instructions Secti...

Page 597: ...s 20010824 Section 1 Updated UL CSA certifications Section 7 Updated Differential Element Commissioning Worksheet This manual differs from the previous versions as follows 20010615 Section 6 Added error message to Table 6 3 Settings Sheet Revised ranges of CTR CTRD 87N1P 87N2P Section 10 Added reference to AB phase clarified FREQ Section 11 Changed symbols for 64G1 and 64G2 Section 12 Changed upgr...

Page 598: ...tings Sheets to reflect increased local remote and latch bits and display points Section 7 Added commissioning details for the 78 element Section 9 Increased local bits to 16 Section 10 Added references to SEL 2030 wherever applicable added new screen captures to reflect addition of 78 element revised Relay Word bit tables reduced number of 15 cycle event reports to 29 revised Table 10 7 Section 1...

Page 599: ...he section Section 8 Clarified Differential Metering quantities on page 8 12 Section 10 SHO Command Show View Settings Reworded sentence at the bottom of Page 10 23 Section 13 Changed IRS1 equation to read IRS1 3 per unit of TAP on Pages 13 10 and 13 15 Appendix A Updated firmware versions This manual differs from the previous versions as follows 19980731 Add danger warnings in English and French ...

Page 600: ... follows 19980320 Added Section 13 Differential Element Settings Added differential element test information and Differential Element Commissioning Worksheet to Section 7 Relay Commissioning Moved VNOM and INOM settings from Global to Group setting Added MET DIF and EVE DIF command descriptions Clarified the calculation of the 64G2P setting 19980130 Initial Release ...

Page 601: ...location of the relay and with a direct connection from the personal computer to one of the relay serial ports Do not load firmware from a remote location problems can arise that you will not be able to address from a distance When upgrading at the substation do not attempt to load the firmware into the relay through an SEL communications processor Perform the firmware upgrade process in the follo...

Page 602: ...voltage sources or output contact wiring to disable relay control functions Step 2 Apply power to the relay Step 3 From the relay front panel press the SET pushbutton Step 4 Use the arrow pushbuttons to navigate to PORT Step 5 Press the SELECT pushbutton Step 6 Use the arrow pushbuttons to navigate to the relay serial port you plan to use usually the front port Step 7 Press the SELECT pushbutton S...

Page 603: ...change this computer serial port to a different port in order to establish communication between the relay and the computer Step 2 Disconnect any other serial port connection s Step 3 From the computer open HyperTerminal On a personal computer running Windows you would typically click Start Programs Accessories Step 4 Enter a name select any icon and click OK Figure B 1 Figure B 1 Establishing a C...

Page 604: ...at correspond to the relay settings you recorded in Step 9 under A Prepare the Relay If the computer settings do not match the relay settings change the computer settings to match the relay settings b Click OK Figure B 3 Determining Communications Parameters for the Computer Step 7 Set terminal emulation to VT100 a From the File menu choose Properties b Select the Settings tab in the Firmware Upgr...

Page 605: ... B 7 Figure B 5 Terminal Emulation Startup Prompt Failure to Connect If you do not see the Access Level 0 prompt press Enter again If you still do not see the Access Level 0 prompt you have either selected the incorrect serial communications port on the computer or the computer speed setting does not match the data transmission rate of the relay Perform the following steps to reattempt a connectio...

Page 606: ...m the filename Properties dialog box shown in Figure B 6 click Configure You will see a dialog box similar to Figure B 7 b Change settings in the appropriate list boxes to match the settings you recorded in Step 9 under A Preparing the Relay and click OK twice to return to the terminal emulation window Figure B 7 Correcting the Communications Parameters Step 12 Press Enter In the terminal emulatio...

Page 607: ... the firmware upgrade process However interruption of relay power during the upgrade process can cause the relay to lose settings Make a copy of the original relay settings in case you need to reenter the settings Use either the SEL 5010 Relay Assistant software or ACSELERATOR to record the existing relay settings and proceed to D Start SELBOOT on page B 8 Otherwise perform the following steps Ste...

Page 608: ...e identification string FID a From the File menu choose Properties b Select the Settings tab in the Properties dialog box Figure B 4 c Click ASCII Setup You should see a dialog box similar to Figure B 8 d Under ASCII Receiving select the check box to Append line feeds to incoming line ends Figure B 8 Preparing HyperTerminal for ID Command Display e Click OK twice to go back to the terminal emulati...

Page 609: ... computer will display the SELBOOT prompt Step 4 Press Enter to confirm that the relay is in SELBOOT You will see another SELBOOT prompt Commands Available in SELBOOT For a listing of commands available in SELBOOT type HELP Enter You should see a screen similar to Figure B 9 HELP Enter SELboot 3xx R100 bau rate Set baud rate to 300 1200 2400 4800 9600 19200 or 38400 baud era Erase the existing rel...

Page 610: ...erial communication is successful Figure B 10 Matching Computer to Relay Parameters E Download Existing Firmware Copy the firmware presently in the relay in case the new firmware upload is unsuccessful To make a backup of the existing firmware the computer will need as much as 3 MB of free disk space This backup procedure takes 5 10 minutes at 38400 bps Step 1 Type SEN Enter at the SELBOOT prompt ...

Page 611: ...Start SELBOOT on page B 8 and click OK SEL lists the firmware revision number first then the product number Figure B 12 Example Filename Identifying Old Firmware Version If Xmodem times out before the download completes repeat the process from Step 1 on page B 10 Note HyperTerminal stored any pathname you entered in Step 1 and any filename you entered in Step 6 during the earlier download attempt ...

Page 612: ...lick on the file and select the directory on the hard drive where you want to access the uncompressed files Verify that these uncompressed files have an s19 extension Step 2 Type REC Enter at the SELBOOT prompt to command the relay to receive new firmware REC Enter Caution This command erases the relays firmware If you erase the firmware new firmware must be loaded into the relay before it can be ...

Page 613: ...re B 15 Incrementing numbers in the Packet box and a bar advancing from left to right in the File box indicate that a transfer is in progress Receiving software takes 10 15 minutes at 38400 bps depending on the relay If you see no indication of a transfer in progress within a few minutes after clicking Send use the REC command again and reattempt the transfer After the transfer completes the relay...

Page 614: ...increase the serial connection data speed Then resume the firmware upgrade process at F Upload New Firmware No Access Level 0 Prompt If no Access Level 0 prompt appears in the terminal emulation window one of three things could have occurred Refer to Table B 1 to determine the best solution Table B 1 Troubleshooting New Firmware Upload Problem Solution The restart was successful but the relay data...

Page 615: ...vel 0 prompt If you see the Access Level 0 prompt proceed to G Check Relay Self Tests The restart was unsuccessful in which case the relay is in SELBOOT Reattempt to upload the new firmware beginning at Step 5 under Establish a High Speed Connection on page B 9 or contact the factory for assistance G Check Relay Self Tests The relay can display various self test fail status messages The troublesho...

Page 616: ... a If you have SEL 5010 Relay Assistant software or ACSELERATOR restore original settings by following the instructions for the respective software b If you do not have the SEL 5010 Relay Assistant software or ACSELERATOR restore original settings by issuing the necessary SET n commands where n can be 1 6 G P L T R X or Y depending upon the settings classes in the relay Step 8 Use the PAS command ...

Page 617: ...Relay Assistant software or ACSELERATOR restore the original settings by issuing the necessary SET n commands where n can be 1 6 G P L T R X or Y depending upon the settings classes available in the relay Step 10 Use the PAS command to set the relay passwords For example type PAS 1 Enter to set the Access Level 1 password Use a similar format for other password levels SEL relay passwords are case ...

Page 618: ...Command Display e Click OK twice to return to the terminal emulation window f Type ID Enter and compare the number the relay displays against the number from the firmware envelope label g If the label FID and part number match the relay display proceed to e h For a mismatch between a displayed FID or part number and the firmware envelope label reattempt the upgrade or contact the factory for assis...

Page 619: ...y is now ready for your commissioning procedure ETHERNET PORT FIRMWARE UPGRADE INSTRUCTIONS Introduction Perform the firmware upgrade process in the following sequence A Prepare the Relay B Establish an FTP Connection C Transfer New Firmware D Establish a Telnet Connection E Verify Firmware Transfer A new default CID file might have been included with your firmware upgrade Do not load this file in...

Page 620: ... 10 201 0 1 ETELNET Y TPORTC 1024 EFTPSERV Y FTPUSER 2AC B Establish an FTP Connection The following instructions use Internet Explorer operating on Microsoft Windows XP as the FTP client to establish communications between the relay and a personal computer The instructions assume both devices are on the same side of any firewalls Step 1 Connect an Ethernet communications cable between the relay E...

Page 621: ...sh an FTP Connection You can omit the user name and the password if you want to enter the user name and password using the following form Ensure there is no trailing forward slash Step 4 Enter the user name and the 2AC password when the window shown in Figure B 18 appears Step 5 Click the Log On button ...

Page 622: ...EL 300G Instruction Manual Figure B 18 Alternate Method of Establishing an FTP Connection Step 6 Right click on the file that you would like to copy Step 7 Click Copy to Folder Figure B 19 Step 8 Browse for folder Step 9 Click OK Figure B 19 Read Open File ...

Page 623: ...ot The relay will take up to a minute to reinitialize after rebooting Step 1 Right click on Start and click on Explore to launch Windows Explorer Step 2 Locate the folder containing the new firmware extension s19 Step 3 Click and drag the file to the Internet Explorer window The Copying dialog box appears until the upload is complete If the Confirm File Replace dialog box appears click on Yes and ...

Page 624: ...t E Verify Firmware Transfer To verify the firmware transfer completed properly perform the following steps after establishing a Telnet connection Step 1 Issue a STA command Step 2 Verify that the STA report does not include any warnings or failures Step 3 Verify that the STA report includes Device Enabled at the end of the report Step 4 Verify that the STA report FID matches the FID of the firmwa...

Page 625: ...The default is 01 SETTLE Time in seconds that transmission is delayed after the request to send RTS line asserts This delay accommodates transmitters with a slow rise time OPERATION The relay ignores all input from this port until it detects the prefix character and the two byte address Upon receipt of the prefix and address the relay enables echo and message transmission Wait until you receive a ...

Page 626: ......

Page 627: ... the separate data streams to exploit this feature The binary commands and ASCII commands can also be accessed by a device that does not interleave the data streams SEL Application Guide AG95 10 Configuration and Fast Meter Messages is a comprehensive description of the SEL binary messages Below is a description of the messages provided in the SEL 300G Relay MESSAGE LISTS Binary Message List Reque...

Page 628: ...e bit A5C100000000 Fast Meter configuration message 0004 Settings change bit A5C200000000 Demand Fast Meter configuration message 0004 Settings change bit A5C300000000 Peak Demand Fast Meter configuration message 0004 Settings change bit 444E410D0000 DNA command 0004 Settings change bit 49440D000000 ID command 0100 SEL protocol Fast Operate 0101 LMD protocol Fast Operate 0002 Modbus protocol 00 Re...

Page 629: ...t Meter message When relay setting DELTA_Y Y 564100000000 Analog channel name VA 01 Analog channel type FF Scale factor type 0000 Scale factor offset in Fast Meter message 564200000000 Analog channel name VB 01 Analog channel type FF Scale factor type 0000 Scale factor offset in Fast Meter message 564300000000 Analog channel name VC 01 Analog channel type FF Scale factor type 0000 Scale factor off...

Page 630: ...ne Configuration Sum of one value for each group Group 1 x 0 ABC x 1 ACB Group 2 x 0 Y connected x 2 D connected 0x Standard Power Calculations x 0 if DELTA_Y Y x 1 if DELTA_Y D FFFF No Deskew angle FFFF No Rs compensation FFFF No Xs compensation 00 IA channel index 01 IB channel index 02 IC channel index 04 VA channel index 05 VB channel index 06 VC channel index 00 Reserved checksum 1 byte check...

Page 631: ...alog channel type FF Scale factor type 0000 Scale factor offset in Fast Meter message When relay setting DELTA_Y Y 564100000000 Analog channel name VA 01 Analog channel type FF Scale factor type 0000 Scale factor offset in Fast Meter message 564200000000 Analog channel name VB 01 Analog channel type FF Scale factor type 0000 Scale factor offset in Fast Meter message 564300000000 Analog channel nam...

Page 632: ... Fast Meter message 465245510000 Analog channel name FREQ 01 Analog channel type FF Scale factor type 0000 Scale factor offset in Fast Meter message 564443000000 Analog channel name VDC 01 Analog channel type FF Scale factor type 0000 Scale factor offset in Fast Meter message 526600000000 Analog channel name Rf 01 Analog channel type float FF Scale factor type no scale factor 0000 Scale factor off...

Page 633: ...100000000 Analog channel name IA 01 Analog channel type FF Scale factor type 0000 Scale factor offset in Fast Meter message 494200000000 Analog channel name IB 01 Analog channel type FF Scale factor type 0000 Scale factor offset in Fast Meter message 494300000000 Analog channel name IC 01 Analog channel type FF Scale factor type 0000 Scale factor offset in Fast Meter message 494E00000000 Analog ch...

Page 634: ...Fast Meter message 564E00000000 Analog channel name VN 01 Analog channel type FF Scale factor type 0000 Scale factor offset in Fast Meter message 465245510000 Analog channel name FREQ 01 Analog channel type FF Scale factor type 0000 Scale factor offset in Fast Meter message 564443000000 Analog channel name VDC 01 Analog channel type FF Scale factor type 0000 Scale factor offset in Fast Meter messa...

Page 635: ...2 of samples per channel 3A of digital banks 01 of calculation blocks 0004 Analog channel offset 007C Time stamp offset 0084 Digital offset 494100000000 Analog channel name IA 01 Analog channel type FF Scale factor type 0000 Scale factor offset in Fast Meter message 494200000000 Analog channel name IB 01 Analog channel type FF Scale factor type 0000 Scale factor offset in Fast Meter message 494300...

Page 636: ...pe FF Scale factor type 0000 Scale factor offset in Fast Meter message 565300000000 Analog channel name VS 01 Analog channel type FF Scale factor type 0000 Scale factor offset in Fast Meter message 564E00000000 Analog channel name VN 01 Analog channel type FF Scale factor type 0000 Scale factor offset in Fast Meter message 494138370000 Analog channel name IA87 01 Analog channel type FF Scale facto...

Page 637: ...sation FFFF No Xs compensation 00 IA channel index 01 IB channel index 02 IC channel index 04 VA channel index 05 VB channel index 06 VC channel index 00 Reserved checksum 1 byte checksum of all preceding bytes For Rf Values 0 0 20000 0 Rf readings are valid Rf 0 neg Rf readings are invalid check If Relay Word bit 64FFLT 1 Rf failure occurred Else 64F element turned off A5D1 Fast Meter Data Block ...

Page 638: ... Rf in 4 byte IEEE FPS 8 bytes Time stamp 58 bytes 58 Digital banks TAR0 TAR57 1 byte Reserved checksum 1 byte checksum of all preceding bytes In response to the A5D1 request Model SEL 0300G3 Relays send the following block Data Description A5D1 Command C0 Length 1 byte 1 Status Byte 120 bytes X and Y components of IA IB IC IN VA VB VC VS VN IA87 IB87 IC87 Freq Vdc and Rf in 4 byte IEEE FPS 8 byte...

Page 639: ...000 Analog channel name IG 02 Analog channel type FF Scale factor type 0000 Scale factor offset in Fast Meter message 334932000000 Analog channel name 3I2 02 Analog channel type FF Scale factor type 0000 Scale factor offset in Fast Meter message 50412B000000 Analog channel name PA 02 Analog channel type FF Scale factor type 0000 Scale factor offset in Fast Meter message 50422B000000 Analog channel...

Page 640: ... Scale factor offset in Fast Meter message 50432D000000 Analog channel name PC 02 Analog channel type FF Scale factor type 0000 Scale factor offset in Fast Meter message 50332D000000 Analog channel name P3 02 Analog channel type FF Scale factor type 0000 Scale factor offset in Fast Meter message 51412D000000 Analog channel name QA 02 Analog channel type FF Scale factor type 0000 Scale factor offse...

Page 641: ...l device should request the A5C1 A5C2 and A5C3 messages The external device can then determine if the scale factors or line configuration parameters have been modified A5CE Fast Operate Configuration Block In response to the A5CE request the relay sends the following block Data Description A5CE Command 3C Length 01 Support 1 circuit breaker 0010 Support 16 remote bit set clear commands 01 Allow re...

Page 642: ... remote bit RB11 0B Operate code clear remote bit RB12 2B Operate code set remote bit RB12 4B Operate code pulse remote bit RB12 0C Operate code clear remote bit RB13 2C Operate code set remote bit RB13 4C Operate code pulse remote bit RB13 0D Operate code clear remote bit RB14 2D Operate code set remote bit RB14 4D Operate code pulse remote bit RB14 0E Operate code clear remote bit RB15 2E Operat...

Page 643: ... controls the timing of the output contact assertion You can use any remote bit RB1 through RB16 and any SELOGIC control equation timer SV1 through SV16 to control any of the output contacts OUT101 through OUT107 For example to pulse output contact OUT104 for 30 cycles with Remote Bit RB4 and SELOGIC control equation timer SV4 issue the following relay settings via the SET L command SV4 RB4 SV4 in...

Page 644: ...digit firmware checksum DEVCODE is the Modbus Device ID Code for the SEL 300G PARTNO is the part number that matches the Model Option Table number CONFIG is configuration string for SEL internal use only bbbbbb is the 6 digit configuration code SPECIAL is Special Configuration Designators for future use ETX is the ETX character 03 The ID message is available from Access Level 0 and higher DNA Mess...

Page 645: ...V7T SV8T 0BCC SV9 SV10 SV11 SV12 SV9T SV10T SV11T SV12T 0CD6 SV13 SV14 SV15 SV16 SV13T SV14T SV15T SV16T 0D44 DP8 DP7 DP6 DP5 DP4 DP3 DP2 DP1 09C4 DP16 DP15 DP14 DP13 DP12 DP11 DP10 DP9 0B15 ER OOST IN106 IN105 IN104 IN103 IN102 IN101 0C61 ALARM OUT107 OUT106 OUT105 OUT104 OUT103 OUT102 OUT101 0FC8 87B 87BL1 87BL2 87BL3 87R 87R1 87R2 87R3 0B58 87U 87U1 87U2 87U3 50H1 50H1T 50H2 50H2T 0B48 50Q1 50Q...

Page 646: ... Messages for other relay models may be derived from Table 4 6 SEL 300G Relay Word Bits of this manual using the above format BNA Message In response to the BNA command the relay sends names of the bits transmitted in the Status Byte in the A5D1 message The first name is the MSB the last name is the LSB The BNA message is STX STSET yyyy ETX where yyyy is the 4 byte ASCII representation of the chec...

Page 647: ...omputer to extract data from other Compressed ASCII commands To obtain the configuration message for the Compressed ASCII commands available in an SEL relay type CAS CR The relay sends STX CAS n yyyy CR COMMAND 1 ll yyyy CR H xxxxx xxxxx xxxxx yyyy CR D ddd ddd ddd ddd ddd yyyy CR COMMAND 2 ll yyyy CR h ddd ddd ddd yyyy CR D ddd ddd ddd ddd ddd yyyy CR COMMAND n ll yyyy CR H xxxxx xxxxx xxxxx yyyy...

Page 648: ...or a 10 character string yyyy is the 4 byte hex ASCII representation of the checksum A Compressed ASCII command may require multiple header and data configuration lines If a Compressed ASCII request is made for data that are not available e g the history buffer is empty or invalid event request the relay responds with the following message STX No Data Available 0668 CR ETX CASCII COMMAND SEL 300G ...

Page 649: ... 1D I I I I I I I yyyy CR 15H FREQ SAM CYC_A SAM CYC_D NUM_OF_CYC EVENT TARGETS IA IB IC IN IG 3I2 yyyy CR 1D F I I I 6S 56S I I I I I I I I I yyyy CR 14H IA IB IC IN IG VA kV VB kV VC kV VN kV VDC FREQ TRIG Names of elements in the relay word rows 2 57 separated by spaces yyyy CR 240D I I I I I F F F F F I F 2S 88S yyyy CR CEV R 1 yyyy CR 1H FID yyyy CR 1D 46S yyyy CR 7H MONTH DAY YEAR HOUR MIN S...

Page 650: ... TRIG Names of elements in the relay word rows 2 57 separated by spaces yyyy CR 60D I I I I I F F F F F I F 2S 88S yyyy CR CEV C 1 yyyy CR 1H FID yyyy CR 1D 46S yyyy CR 7H MONTH DAY YEAR HOUR MIN SEC MSEC yyyy CR 1D I I I I I I I yyyy CR 15H FREQ SAM CYC_A SAM CYC_D NUM_OF_CYC EVENT TARGETS IA IB IC IN IG 3I2 IA87 IB87 IC87 yyyy CR 1D F I I I 6S 56S I I I I I I I I I yyyy CR 14H IA IB IC IN IG VA ...

Page 651: ...IN SEC MSEC yyyy CR 1D I I I I I I I yyyy CR 15H FREQ SAM CYC_A SAM CYC_D NUM_OF_CYC EVENT TARGETS IA IB IC IN IG 3I2 yyyy CR 1D F I I I 6S 56S I I I I I I I I I yyyy CR 14H IA IB IC IN IG VA kV VB kV VC kV VN kV VS kV VDC FREQ TRIG Names of elements in the relay word rows 2 57 separated by spaces yyyy CR 60D I I I I I F F F F F I F 2S 88S yyyy CR CEV C 1 yyyy CR 1H FID yyyy CR 1D 46S yyyy CR 7H M...

Page 652: ...9S 9S 9S 9S 9S 9S 9S 9S 9S 9S 9S 9S 9S 9S 9S 9S 9S 9S yyyy CR CHI 1 yyyy CR 1H FID yyyy CR 1D 46S yyyy CR 13H REC_NUM MONTH DAY YEAR HOUR MIN SEC MSEC EVENT CURR FREQ GROUP TARGETS yyyy CR 30D I I I I I I I I 6S I F I 56S yyyy CR CEV 1 yyyy CR 1H FID yyyy CR 1D 46S yyyy CR 7H MONTH DAY YEAR HOUR MIN SEC MSEC yyyy CR 1D I I I I I I I yyyy CR 15H FREQ SAM CYC_A SAM CYC_D NUM_OF_CYC EVENT TARGETS IA ...

Page 653: ... kV VS kV VDC FREQ TRIG Names of elements in the relay word rows 2 57 separated by spaces yyyy CR 256D I I I I I F F F F I F 2S 88S yyyy CR ETX See the CEVENT command for definition of the Names of elements in the Relay Word Rows 2 57 separated by spaces field CSTATUS COMMAND SEL 300G Display status data in Compressed ASCII format by sending CST CR Model SEL 0300G0 Relay sends STX FID yyyy CR Rela...

Page 654: ...xxx xxxx yyyy CR IA IB IC IN VA VB VC VN MOF VS 5V_PS 5V_REG 5V_REG 12V_PS 12V_PS 15V_PS 15V_PS TEMP RAM ROM A D CR_RAM EEPROM IO_BRD yyyy CR xxxx xxxx xxxx xxxx xxxx xxxx xxxx xxxx xxxx xxxx xxxx xxxx xxxx xxxx xxxx xxxx xxxx xxxx xxxx xxxx xxxx xxxx xxxx xxxx yyyy CR ETX Model SEL 0300G3 Relay sends STX FID yyyy CR Relay FID string yyyy CR MONTH DAY YEAR HOUR MIN SEC MSEC yyyy CR xxxx xxxx xxxx ...

Page 655: ...MAND SEL 300G Display event report in Compressed ASCII format by sending CEV n Sx sec Ly w R C DIF parameters in are optional where n event number 1 29 if LER 15 1 15 if LER 30 defaults to 1 Sx x samples per cycle 4 or 16 defaults to 4 sec Displays sampled values in secondary Amperes and Volts instead of primary Amperes and kV Ly y cycles event report length 1 LER for filtered event reports 1 LER ...

Page 656: ...le 4 or 16 SAM CYC_D is the number of digital data samples per cycle 4 or 16 NUM_OF_CYC is the number of cycles of data in the event report EVENT is the event type TARGETS are the front panel tripping targets IA IB IC IN IG 3I2 is the fault current TRIG refers to the trigger record z is for the trigger row for the fault current row and empty for all others If the trigger row and fault current row ...

Page 657: ...urrents IA87 IB87 IC87 are the differential input currents IOP1 IOP2 IOP3 IRT1 IRT2 IRT3 I1F2 I2F2 I3F2 are the differential quantities TRIG refers to the trigger record z is for the trigger row for the fault current row and empty for all others If the trigger row and fault current row are the same both characters are included e g HEX ASCII Relay Word is the hex ASCII format of the Relay Word The ...

Page 658: ...T210 OUT211 OUT212 50H2A 50H2B 50H2C SET1 SET2 SET3 SET4 SET5 SET6 SET7 SET8 SET9 SET10 SET11 SET12 SET13 SET14 SET15 SET16 RST1 RST2 RST3 RST4 RST5 RST6 RST7 RST8 RST9 RST10 RST11 RST12 RST13 RST14 RST15 RST16 LT1 LT2 LT3 LT4 LT5 LT6 LT7 LT8 LT9 LT10 LT11 LT12 LT13 LT14 LT15 LT16 OTHTRIP OTHALRM AMBTRIP AMBALRM BRGTRIP BRGALRM WDGTRIP WDGALRM RTDFLT 2600IN RTD4TR RTD4AL RTD3TR RTD3AL RTD2TR RTD2A...

Page 659: ...he address of the desired slave device All of the slave devices receive the message but only the slave device with the matching address responds The SEL 300G Modbus communication allows a Modbus master device to Acquire metering monitoring and event data from the relay Control SEL 300G output contacts and remote bits Read the SEL 300G self test status and learn the present condition of all relay p...

Page 660: ...ve device response is formatted similarly to the query including the slave address function code data if applicable and a cyclical redundancy check value Supported Modbus Function Codes The SEL 300G supports the Modbus function codes shown in Table F 2 Table F 2 SEL 300G Relay Modbus Function Codes Codes Description 01h Read Coil Status 02h Read Input Status 03h Read Holding Registers 04h Read Inp...

Page 661: ...the master that the data field contains an error code instead of the requested data Cyclical Redundancy Check The SEL 300G calculates a 2 byte CRC value using the device address function code and data fields It appends this value to the end of every Modbus response When the master device receives the response it recalculates the CRC If the calculated CRC matches the CRC sent by the SEL 300G the ma...

Page 662: ...h 1 byte Bytes of data n n bytes Data 2 bytes CRC 16 To build the response the relay calculates the number of bytes required to contain the number of bits requested If the number of bits requested is not evenly divisible by eight the relay adds one more byte to maintain the balance of bits padded by zeroes to make an even byte The relay responses to errors in the query are shown below Error Error ...

Page 663: ...OUT205 33 RB13 14 OUT206 34 RB14 15 OUT207 35 RB14 16 OUT208 36 RB16 17 OUT209 37 CC 18 OUT210 38 OC1 19 OUT211 39 OC2 20 OUT212 40 OC3 02h Read Input Status Command Use function code 02h to read the On Off status of the selected bits inputs You may read the status of up to 2000 bits per query Note that the input addresses start at 0 e g Input 1 is located at address zero The input status is packe...

Page 664: ...7 SEL 300G Relay Inputs Description Input Number EN BKR CLOSED LOP 60 TRIP 21 51V 50 51 N 8 1 24 27 59 32 40 46 64G 81 87 16 9 IN106 IN105 IN104 IN103 IN102 IN101 24 17 IN208 IN207 IN206 IN205 IN204 IN203 IN202 IN201 32 25 ALARM OUT107 OUT106 OUT105 OUT104 OUT103 OUT102 OUT101 40 33 OUT201 OUT202 OUT203 OUT204 OUT205 OUT206 OUT207 OUT208 48 41 OUT209 OUT210 OUT211 OUT212 56 49 24TC 24D1 24D1T 24C2...

Page 665: ... 313 50Q1 50Q1T 50Q2 50Q2T 50R1 50R1T 50R2 50R2T 328 321 59VP 59VS CFA BKRCF BSYNCH 25C 25A1 25A2 336 329 59PP2 27PP2 SF VDIF GENVHI GENVLO GENFHI GENFLO 344 337 87NTC 87N1P 87N1T 87N2P 87N2T MPP1P MABC1P 27VS 352 345 21PTC 21P1P 21P1T 21P2P 21P2T MPP2P MABC2P 360 353 IN208 IN207 IN206 IN205 IN204 IN203 IN202 IN201 368 361 64FTC 64F1 64F1T 64F2 64F2T 64FFLT 376 369 OUT201 OUT202 OUT203 OUT204 OUT2...

Page 666: ...Map shown in Table F 20 You may read a maximum of 125 registers at once with this function code Most masters use 4X references with this function code If you are accustomed to 4X references with this function code for five digit addressing add 40001 to the standard database address Table F 8 03h Read Holding Register Command Bytes Field Requests from the master must have the following format 1 byt...

Page 667: ...he Modbus Register Map shown in Table F 20 You may read a maximum of 125 registers at once with this function code Most masters use 3X references with this function code If you are accustomed to 3X references with this function code for five digit addressing add 30001 to the standard database address Table F 9 04h Read Holding Register Command Bytes Field Requests from the master must have the fol...

Page 668: ...lue 03h Illegal Register Format error Illegal Data Value 03h Bad Packet Format Busy Slave is busy with other task 06h 05h Force Single Coil Command Use function code 05h to set or clear a coil Table F 10 05h Force Single Coil Command Bytes Field Requests from the master must have the following format 1 byte Slave Address 1 byte Function Code 05h 2 bytes Coil Reference 1 byte Operation Code FF for ...

Page 669: ...B16 9 PULSE OUT201 37 PULSE RB1 10 PULSE OUT202 38 PULSE RB2 11 PULSE OUT203 39 PULSE RB3 12 PULSE OUT204 40 PULSE RB4 13 PULSE OUT205 41 PULSE RB5 14 PULSE OUT206 42 PLUSE RB6 15 PULSE OUT207 43 PULSE RB7 16 PULSE OUT208 44 PULSE RB8 17 PULSE OUT209 45 PULSE RB9 18 PULSE OUT210 46 PULSE RB10 19 PULSE OUT211 47 PULSE RB11 20 PULSE OUT212 48 PULSE RB12 21 SET CLEAR RB1 49 PULSE RB13 22 SET CLEAR RB...

Page 670: ...code If you are accustomed to 4X references with this function code for six digit addressing add 400001 to the standard database addresses Table F 12 06h Preset Single Register Command Bytes Field Requests from the master must have the following format 1 byte Slave Address 1 byte Function Code 06h 2 bytes Register Address 2 bytes Data 2 bytes CRC 16 Note The command response is identical to the co...

Page 671: ... OUT4 Status Bit 4 Alarm Output status Bit 5 Input 1 Status Bit 6 Input 2 Status Bit 7 Relay Status If the status bit is set to 1 the following are true for the status indicated by the bit Alarm contact is asserted Relay is disabled If the status bit is set to 0 the following are true for the status indicated by the bit Alarm contact is deasserted Relay is enabled The relay response to errors in t...

Page 672: ...Data Value 03h Illegal Function Code Op Code Format error Illegal Data Value 03h Bad Packet Format 10h Preset Multiple Registers Command This function code works much like code 06h except that it allows you to write multiple registers at once up to 100 per operation Refer to the Modbus Register Map in Table F 20 for a list of registers that can be written using this function code If you are accust...

Page 673: ...on Illegal Data Value 03h Bad Packet Format Illegal Write Invalid register data value Illegal Data Value 03h Illegal Write 64h Scattered Register Read The SEL 300G uses this function to allow a Modbus master to read noncontiguous registers in a single request A maximum of 100 registers can be read in a single query Table F 16 64h Scattered Register Read Command Bytes Field Requests from the master...

Page 674: ...egal Data Value 03h Bad Packet Format Invalid subfunction code Illegal Data Value 03h Illegal Function Code Op Code Illegal register address Illegal Data Address 02h Invalid Address Controlling Output Contacts and Remote Bits Using Modbus The SEL 300G Modbus Register Map Table F 20 includes three fields that allow a Modbus master to force the relay to perform a variety of operations Use Modbus fun...

Page 675: ...econd 06h 10h 12 Pulse OUT106 1 30 seconds duration defaults to 1 second 06h 10h 13 Pulse OUT107 1 30 seconds duration defaults to 1 second 06h 10h 14 Pulse Alarm 1 30 seconds duration defaults to 1 second 06h 10h 15 Pulse OUT201 1 30 seconds duration defaults to 1 second 06h 10h 16 Pulse OUT202 1 30 seconds duration defaults to 1 second 06h 10h 17 Pulse OUT203 1 30 seconds duration defaults to 1 ...

Page 676: ... which bit to control It is bitmasked for future expansion but only one bit can be controlled at a time The highest numbered bit will be controlled if more than one bit occurs in the parameter Bit Pattern Remote Bit Bit Pattern Remote Bit 0000 0000 0000 0001 RB1 0000 0001 0000 0000 RB9 0000 0000 0000 0010 RB2 0000 0010 0000 0000 RB10 0000 0000 0000 0100 RB3 0000 0100 0000 0000 RB11 0000 0000 0000 ...

Page 677: ...a detailed description The event report will contain both analog and digital data To download the event data using Modbus proceed as follows Write the event number you wish to download at address 02D1h Write the channel number you wish to download at address 02D2h Refer to Table F 19 for the channel number assignment Read the four sample per cycle raw event data from the Modbus Map Note that readi...

Page 678: ...Status Row 17a 33 Relay Element Status Row 18a 34 Relay Element Status Row 19a 35 Relay Element Status Row 20a 36 Relay Element Status Row 21a 37 Relay Element Status Row 22a 38 Relay Element Status Row 23a 39 Relay Element Status Row 24a 40 Relay Element Status Row 25a 41 Relay Element Status Row 26a 42 Relay Element Status Row 27a 43 Relay Element Status Row 28a 44 Relay Element Status Row 29a 4...

Page 679: ...t number for which there is no data available 8000h will be returned Reading History Data Using Modbus The Modbus Register Map Table F 20 provides a feature that allows you to download the complete history of the last 29 events via Modbus The history contains the date and time stamp type of event that triggered the report and the targets Please refer to Note 8 of the Modbus Map for a list of event...

Page 680: ...hannel VA offset value mV 5000 5000 1 1 0059 Channel VA status message 0 OK 1 Warn 2 fail 005A Channel VB offset value mV 5000 5000 1 1 005B Channel VB status message 0 OK 1 Warn 2 fail 005C Channel VC offset value mV 5000 5000 1 1 005D Channel VC status message 0 OK 1 Warn 2 fail 005E Channel VN offset value mV 5000 5000 1 1 005F Channel VN status message 0 OK 1 Warn 2 fail 0060 Channel IA87 offs...

Page 681: ...0 1500 1 0 01 0071 12_ps Power Supply Status 0 OK 1 Warn 2 fail 0072 12_ps Power Supply Value V 1500 0 1 0 01 0073 12_ps Power Supply Status 0 OK 1 Warn 2 fail 0074 15_ps Power Supply Value V 0 2000 1 0 01 0075 15_ps Power Supply Status0 OK 1 Warn 2 fail 0076 15_ps Power Supply Value V 2000 0 1 0 01 0077 15_ps Power Supply Status 0 OK 1 Warn 2 fail 0078 TEMP in degrees Celsius C 1000 1000 1 0 1 00...

Page 682: ... 009D Phase B Voltage Angle degrees 18000 18000 1 0 01 009E Phase C Voltage kV 0 65535 1 0 1 009F Phase C Voltage Angle degrees 18000 18000 1 0 01 00A0 Neutral Voltage sV 0 65535 1 0 01 00A1 Neutral Voltage Angle degrees 18000 18000 1 0 01 00A2 Sync Voltage kV 0 65535 1 0 1 00A3 Sync Voltage Angle degrees 18000 18000 1 0 01 00A4 Third Harmonic Terminal Voltage sV 0 65535 1 0 01 00A5 Third Harmonic...

Page 683: ...mps 0 65535 1 1 00BB Zero Sequence Current Angle degrees 18000 18000 1 0 01 00BC Positive Sequence Voltage V1 kV 0 65535 1 0 1 00BD Positive Sequence Voltage Angle degrees 18000 18000 1 0 01 00BE Negative Sequence Voltage V2 kV 0 65535 1 0 1 00BF Negative Sequence Voltage Angle degrees 18000 18000 1 0 01 00C0 Zero Sequence Voltage 3V0 kV 0 65535 1 0 1 00C1 Zero Sequence Voltage Angle degrees 18000...

Page 684: ...ps 0 65535 1 0 01 00D7 Percent of operate quantity for winding 2 0 65535 1 0 1 00D8 Second harmonic current in winding 3 Amps 0 65535 1 0 01 00D9 Percent of operate quantity for winding 3 0 65535 1 0 1 Demand 00DA Demand Current Phase A Amps 0 65535 1 1 00DB Demand Current Phase B Amps 0 65535 1 1 00DC Demand Current Phase C Amps 0 65535 1 1 00DD Demand Neutral Current IN Amps 0 65535 1 1 00DE Dem...

Page 685: ...2767 32767 1 0 1 Reset 00F0 Last Demand Reset Time ms 0 999 1 1 00F1 sec 0 59 1 1 00F2 minute 0 59 1 1 00F3 hour 1 23 1 1 00F4 Last Demand Reset Date day 1 31 1 1 00F5 month 1 12 1 1 00F6 year 1992 2999 1 1 Peak Demand 00F7 Peak Demand Current Phase A Amps 0 65535 1 1 00F8 Peak Demand Current Phase B Amps 0 65535 1 1 00F9 Peak Demand Current Phase C Amps 0 65535 1 1 00FA Peak Demand Neutral Curren...

Page 686: ...767 32767 1 0 1 010A Megavars Phase B DELTA_Y Y MVars 32767 32767 1 0 1 010B Megavars Phase C DELTA_Y Y MVars 32767 32767 1 0 1 010C Megavars 3 Phase MVars 32767 32767 1 0 1 Reset 010D Last Peak Demand Reset Time ms 0 999 1 1 010E sec 0 59 1 1 010F minute 0 59 1 1 0110 hour 1 23 1 1 0111 Last Peak Demand Reset Date day 1 31 1 1 0112 month 1 12 1 1 0113 year 1992 2999 1 1 Energy In 0114 Megawatts P...

Page 687: ...Reset Time ms 0 999 1 1 0125 sec 0 59 1 1 0126 minute 0 59 1 1 0127 hour 1 23 1 1 0128 Last Energy Reset Date day 1 31 1 1 0129 month 1 12 1 1 012A year 1992 2999 1 1 Min Max Metering See Note 3 012B Max Phase A Current Amps 0 65535 1 1 012C Max Phase A Current Time ms 0 999 1 1 012D sec 0 59 1 1 012E minute 0 59 1 1 012F hour 1 23 1 1 0130 Max Phase A Current Date day 1 31 1 1 0131 month 1 12 1 1...

Page 688: ...C Max Phase C Current Time ms 0 999 1 1 014D sec 0 59 1 1 014E minute 0 59 1 1 014F hour 1 23 1 1 0150 Max Phase C Current Date day 1 31 1 1 0151 month 1 12 1 1 0152 year 1992 2999 1 1 0153 Min Phase C Current Amps 0 65535 1 1 0154 Min Phase C Current Time ms 0 999 1 1 0155 sec 0 59 1 1 0156 minute 0 59 1 1 0157 hour 1 23 1 1 0158 Min Phase C Current Date day 1 31 1 1 0159 month 1 12 1 1 015A year...

Page 689: ...74 Min Residual Current Time ms 0 999 1 1 0175 sec 0 59 1 1 0176 minute 0 59 1 1 0177 hour 1 23 1 1 0178 Min Residual Current Date day 1 31 1 1 0179 month 1 12 1 1 017A year 1992 2999 1 1 017B Max Phase A Voltage kV 0 65535 1 0 1 017C Max Phase A Voltage Time ms 0 999 1 1 017D sec 0 59 1 1 017E minute 0 59 1 1 017F hour 1 23 1 1 0180 Max Phase A Voltage Date day 1 31 1 1 0181 month 1 12 1 1 0182 y...

Page 690: ... 0 1 019C Max Phase C Voltage Time ms 0 999 1 1 019D sec 0 59 1 1 019E minute 0 59 1 1 019F hour 1 23 1 1 01A0 Max Phase C Voltage Date day 1 31 1 1 01A1 month 1 12 1 1 01A2 year 1992 2999 1 1 01A3 Min Phase C Voltage kV 0 65535 1 0 1 01A4 Min Phase C Voltage Time ms 0 999 1 1 01A5 sec 0 59 1 1 01A6 minute 0 59 1 1 01A7 hour 1 23 1 1 01A8 Min Phase C Voltage Date day 1 31 1 1 01A9 month 1 12 1 1 0...

Page 691: ... Voltage sV 0 65535 1 0 01 01C4 Min Neutral Voltage Time ms 0 999 1 1 01C5 sec 0 59 1 1 01C6 minute 0 59 1 1 01C7 hour 1 23 1 1 01C8 Min Neutral Voltage Date day 1 31 1 1 01C9 month 1 12 1 1 01CA year 1992 2999 1 1 01CB Max Terminal 3rd Harmonic Voltage sV 0 65535 1 0 01 01CC Max Terminal 3rd Harmonic Voltage Time ms 0 999 1 1 01CD sec 0 59 1 1 01CE minute 0 59 1 1 01CF hour 1 23 1 1 01D0 Max Term...

Page 692: ...eutral 3rd Harmonic Voltage Time ms 0 999 1 1 01E5 sec 0 59 1 1 01E6 minute 0 59 1 1 01E7 hour 1 23 1 1 01E8 Min Neutral 3rd Harmonic Voltage Date day 1 31 1 1 01E9 month 1 12 1 1 01EA year 1992 2999 1 1 01EB Max Phase A 87 Current Amps 0 65535 1 1 01EC Max Phase A 87 Current Time ms 0 999 1 1 01ED sec 0 59 1 1 01EE minute 0 59 1 1 01EF hour 1 23 1 1 01F0 Max Phase A 87 Current Date day 1 31 1 1 0...

Page 693: ... 020B Max Phase C 87 Current Amps 0 65535 1 1 020C Max Phase C 87 Current Time ms 0 999 1 1 020D sec 0 59 1 1 020E minute 0 59 1 1 020F hour 1 23 1 1 0210 Max Phase C 87 Current Date day 1 31 1 1 0211 month 1 12 1 1 0212 year 1992 2999 1 1 0213 Min Phase C 87 Current Amps 0 65535 1 1 0214 Min Phase C 87 Current Time ms 0 999 1 1 0215 sec 0 59 1 1 0216 minute 0 59 1 1 0217 hour 1 23 1 1 0218 Min Ph...

Page 694: ... 1 0233 Min 3 Phase Mega Vars MVars 32767 32767 1 0 1 0234 Min 3 Phase Mega Vars Time ms 0 999 1 1 0235 sec 0 59 1 1 0236 minute 0 59 1 1 0237 hour 1 23 1 1 0238 Min 3 Phase Mega Vars Date day 1 31 1 1 0239 month 1 12 1 1 023A year 1992 2999 1 1 023B Last Reset Time ms 0 999 1 1 023C sec 0 59 1 1 023D minute 0 59 1 1 023E hour 1 23 1 1 023F Last Reset Date day 1 31 1 1 0240 month 1 12 1 1 0241 yea...

Page 695: ...7 1 1 024E Reserved 024F Reserved Relay Time and Date 0250 Time ss RW See Note 5 0 59 1 1 0251 minute RW 0 59 1 1 0252 hour RW 1 23 1 1 0253 Date day RW 1 31 1 1 0254 month RW 1 12 1 1 0255 year RW 1992 2999 1 1 0256 025F Reserved Relay Word 0260 Targets 1 EN BKR CLOSED LOP 60 TRIP 21 51V 50 51 N 0 65535 1 1 0261 Targets 2 24 27 59 32 40 46 64G 81 87 0 65535 1 1 0262 Input Contact Status 1 IN106 I...

Page 696: ...7 OUT106 OUT105 OUT104 OUT103 OUT102 OUT101 0 65535 1 1 0265 Output Contact Status 2 OUT201 OUT202 OUT203 OUT204 OUT205 OUT206 OUT207 OUT208 0 65535 1 1 0266 Output Contact Status 3 OUT209 OUT210 OUT211 OUT212 0 65535 1 1 0267 Row 2 24TC 24D1 24D1T 24C2 24C2T 24CR SS1 SS2 0 65535 1 1 0268 Row 3 27P1 27P2 27PP1 27V1 59P1 59P2 59G1 59G2 0 65535 1 1 0269 Row 4 32PTC 32P1 32P1T 32P2 32P2T 59V1 0 65535...

Page 697: ...TC 40Z1 40Z1T 40Z2 40Z2T SWING SG1 SG2 0 65535 1 1 026B Row 6 46QTC 46Q1 46Q1T 46Q2 46Q2T 46Q2R INAD INADT 0 65535 1 1 026C Row 7 78R1 78R2 78Z1 OOSTC 51CTC 51C 51CT 51CR 0 65535 1 1 026D Row 8 51GTC 51G 51GT 51GR 51NTC 51N 51NT 51NR 0 65535 1 1 026E Row 9 51VTC 51V 51VT 51VR PDEM QDEM GDEM NDEM 0 65535 1 1 026F Row 10 50P1 50P1T 50P2 50P2T 50G1 50G1T 50G2 0 65535 1 1 ...

Page 698: ...50N2 50N2T CC CL CLOSE ULCL 0 65535 1 1 0271 Row 12 64GTC 64G1 64G1T 64G2 64G2T OOS 60LOP CLEN 0 65535 1 1 0272 Row 13 BKMON BCW BCWA BCWB BCWC FAULT DCLO DCHI 0 65535 1 1 0273 Row 14 81D1 81D2 81D3 81D4 81D5 81D6 3PO 52A 0 65535 1 1 0274 Row 15 81D1T 81D2T 81D3T 81D4T 81D5T 81D6T 27B81 50L 0 65535 1 1 0275 Row 16 ONLINE BND1A BND1T BND2A BND2T BND3A BND3T BNDA 0 65535 1 1 ...

Page 699: ...GTR BND4A BND4T BND5A BND5T BND6A BND6T BNDT 0 65535 1 1 0277 Row 18 TRIP TRIP1 TRIP2 TRIP3 TRIP4 OC1 OC2 OC3 0 65535 1 1 0278 Row 19 TR1 TR2 TR3 TR4 ULTR1 ULTR2 ULTR3 ULTR4 0 65535 1 1 0279 Row 20 LB1 LB2 LB3 LB4 LB5 LB6 LB7 LB8 0 65535 1 1 027A Row 21 LB9 LB10 LB11 LB12 LB13 LB14 LB15 LB16 0 65535 1 1 027B Row 22 RB1 RB2 RB3 RB4 RB5 RB6 RB7 RB8 0 65535 1 1 ...

Page 700: ... RB11 RB12 RB13 RB14 RB15 RB16 0 65535 1 1 027D Row 24 21CTC 21C1P 21C1T 21C2P 21C2T ZLOAD T64G N64G 0 65535 1 1 027E Row 25 SV1 SV2 SV3 SV4 SV1T SV2T SV3T SV4T 0 65535 1 1 027F Row 26 SV5 SV6 SV7 SV8 SV5T SV6T SV7T SV8T 0 65535 1 1 0280 Row 27 SV9 SV10 SV11 SV12 SV9T SV10T SV11T SV12T 0 65535 1 1 0281 Row 28 SV13 SV14 SV15 SV16 SV13T SV14T SV15T SV16T 0 65535 1 1 ...

Page 701: ...P5 DP4 DP3 DP2 DP1 0 65535 1 1 0283 Row 30 DP16 DP15 DP14 DP13 DP12 DP11 DP10 DP9 0 65535 1 1 0284 Row 31 ER OOST IN106 IN105 IN104 IN103 IN102 IN101 0 65535 1 1 0285 Row 32 ALARM OUT107 OUT106 OUT105 OUT104 OUT103 OUT102 OUT101 0 65535 1 1 0286 Row 33 87B 87BL1 87BL2 87BL3 87R 87R1 87R2 87R3 0 65535 1 1 0287 Row 34 87U 87U1 87U2 87U3 50H1 50H1T 50H2 50H2T 0 65535 1 1 ...

Page 702: ...0R1 50R1T 50R2 50R2T 0 65535 1 1 0289 Row 36 59VP 59VS CFA BKRCF BSYNCH 25C 25A1 25A2 0 65535 1 1 028A Row 37 59PP2 27PP2 SF VDIF GENVHI GENVLO GENFHI GENFLO 0 65535 1 1 028B Row 38 87NTC 87N1P 87N1T 87N2P 87N2T MPP1P MABC1P 27VS 0 65535 1 1 028C Row 39 21PTC 21P1P 21P1T 21P2P 21P2T MPP2P MABC2P 0 65535 1 1 028D Row 40 IN208 IN207 IN206 IN205 IN204 IN203 IN202 IN201 0 65535 1 1 ...

Page 703: ...Scale Factor 028E Row 41 64FTC 64F1 64F1T 64F2 64F2T 64FFLT 0 65535 1 1 028F Row 42 OUT201 OUT202 OUT203 OUT204 OUT205 OUT206 OUT207 OUT208 0 65535 1 1 0290 Row 43 OUT209 OUT210 OUT211 OUT212 0 65535 1 1 0291 Row 44 50H2A 50H2B 50H2C 0 65535 1 1 0292 Row 45 0 65535 1 1 0293 Row 46 SET1 SET2 SET3 SET4 SET5 SET6 SET7 SET8 0 65535 1 1 ...

Page 704: ...2 SET13 SET14 SET15 SET16 0 65535 1 1 0295 Row 48 RST1 RST2 RST3 RST4 RST5 RST6 RST7 RST8 0 65535 1 1 0296 Row 49 RST9 RST10 RST11 RST12 RST13 RST14 RST15 RST16 0 65535 1 1 0297 Row 50 LT1 LT2 LT3 LT4 LT5 LT6 LT7 LT8 0 65535 1 1 0298 Row 51 LT9 LT10 LT11 LT12 LT13 LT14 LT15 LT16 0 65535 1 1 0299 Row 52 OTHTRIP OTHALRM AMBTRIP AMBALRM BRGTRIP BRGALRM WDGTRIP WDGALRM 0 65535 1 1 ...

Page 705: ... 0 65535 1 1 029C Row 55 RTD8TR RTD8AL RTD7TR RTD7AL RTD6TR RTD6AL RTD5TR RTD5AL 0 65535 1 1 029D Row 56 RTD12TR RTD12AL RTD11TR RTD11AL RTD10TR RTD10AL RTD9TR RTD9AL 0 65535 1 1 029E 029F Reserved Commands 02A0 Command Code W See Note 5 02A1 Parameter 1 W 02A2 Parameter 2 W 02A3 02AF Reserved History Records See Note 6 02B0 Number of History Records 0 29 02B1 History Selection RW see Note 6 1 29 ...

Page 706: ...pe Code See Note 8 02BE Current 0 65535 1 1 02BF Frequency 20 7000 1 0 01 02C0 Group 1 2 1 1 02C1 Targets 1 EN BKR CLOSED LOP 60 TRIP 21 51V 50 51 N 0 65535 1 1 02C2 Targets 2 24 27 59 32 40 46 64G 81 87 0 65535 1 1 02C3 02CF Reserved Event Reporting See Note 3 02D0 Number of Event Records 0 29 02D1 Event Record Selection RW See Note 5 1 29 1 1 02D2 Event Channel Selection RW See Note 6 1 68 1 1 0...

Page 707: ...32767 1 02E6 5 cycle 32767 32767 1 02E7 5 cycle 32767 32767 1 02E8 5 cycle 32767 32767 1 02E9 5 cycle 32767 32767 1 02EA 6 cycle 32767 32767 1 02EB 6 cycle 32767 32767 1 02EC 6 cycle 32767 32767 1 02ED 6 cycle 32767 32767 1 02EE 7 cycle 32767 32767 1 02EF 7 cycle 32767 32767 1 02F0 7 cycle 32767 32767 1 02F1 7 cycle 32767 32767 1 02F2 8 cycle 32767 32767 1 02F3 8 cycle 32767 32767 1 02F4 8 cycle 3...

Page 708: ...67 1 030E 15 cycle 32767 32767 1 030F 15 cycle 32767 32767 1 0310 15 cycle 32767 32767 1 0311 15 cycle 32767 32767 1 0312 16 cycle 32767 32767 1 0313 16 cycle 32767 32767 1 0314 16 cycle 32767 32767 1 0315 16 cycle 32767 32767 1 0316 17 cycle 32767 32767 1 0317 17 cycle 32767 32767 1 0318 17 cycle 32767 32767 1 0319 17 cycle 32767 32767 1 031A 18 cycle 32767 32767 1 031B 18 cycle 32767 32767 1 031...

Page 709: ...1 0336 25 cycle 32767 32767 1 0337 25 cycle 32767 32767 1 0338 25 cycle 32767 32767 1 0339 25 cycle 32767 32767 1 033A 26 cycle 32767 32767 1 033B 26 cycle 32767 32767 1 033C 26 cycle 32767 32767 1 033D 26 cycle 32767 32767 1 033E 27 cycle 32767 32767 1 033F 27 cycle 32767 32767 1 0340 27 cycle 32767 32767 1 0341 27 cycle 32767 32767 1 0342 28 cycle 32767 32767 1 0343 28 cycle 32767 32767 1 0344 2...

Page 710: ...5535 1 1 0359 Targets 2 24 27 59 32 40 46 64G 81 87 0 65535 1 1 035A Current Phase A Amps 0 65535 1 1 035B Current Phase B Amps 0 65535 1 1 035C Current Phase C Amps 0 65535 1 1 035D Neutral Current IN Amps 0 65535 1 1 035E Residual Current IG Amps 0 65535 1 1 035F Negative Sequence Current 3I2 Amps 0 65535 1 1 0360 Current IA87 Amps 0 65535 1 1 0361 Current IB87 Amps 0 65535 1 1 0362 Current IC87...

Page 711: ...7 month 1 12 1 1 0388 year 1992 2999 1 1 0389 Slip Frequency Hz 0 5000 1 0 01 038A Generator Frequency Hz 20 18000 1 0 01 038B System Frequency Hz 20 7000 1 0 01 038C Voltage Diff 0 65535 1 0 01 038D Generator Voltage kV 0 65535 1 0 01 038E System Voltage kV 0 65535 1 0 01 038F Slip Compensated Phase Angle Diff degree 18000 18000 1 0 01 0390 Uncompensated Phase Angle Diff degree 18000 18000 1 0 01...

Page 712: ... 1 03A8 Last Reset Date day 1 31 1 1 03A9 month 1 12 1 1 03AA year 1992 2999 1 1 03AB 03AF Reserved Breaker Monitor 03B0 Internal Trips 0 65535 1 1 03B1 IA Current Amps 0 65535 1 0 1 03B2 IB Current Amps 0 65535 1 0 1 03B3 IC Current Amps 0 65535 1 0 1 03B4 External Trips 0 65535 1 1 03B5 IA Current Amps 0 65535 1 0 1 03B6 IB Current Amps 0 65535 1 0 1 03B7 IC Current Amps 0 65535 1 0 1 03B8 wear ...

Page 713: ...0 1 03D9 Frequency Band 3 Time Accumulator sec 0 65535 1 0 1 03DA of limit setting 0 65535 1 0 1 03DB Frequency Band 4 Time Accumulator sec 0 65535 1 0 1 03DC of limit setting 0 65535 1 0 1 03DD Frequency Band 5 Time Accumulator sec 0 65535 1 0 1 03DE of limit setting 0 65535 1 0 1 03DF Frequency Band 6 Time Accumulator sec 0 65535 1 0 1 03E0 of limit setting 0 65535 1 0 1 03E1 Operating History S...

Page 714: ...3FD LEAD LAG Power Factor 0 LAG 1 LEAD 03FE 03FF Reserved Maximum Current Limit 0400 Multiplier Phase Current Amps 0 65535 1 1 0401 Scale Exponent 4 4 1 1 0402 Multiplier Phase Voltage kV 0 65535 1 1 0403 Scale Exponent 4 4 1 1 0404 Multiplier Total Power MWatts 0 65535 1 1 0405 Scale Exponent 4 4 1 1 0406 040F Reserved Communication Counter 0410 Number of messages received 0 65535 1 1 0411 Number...

Page 715: ...sters All other registers are read only Note 6 Event and History Reporting The Modbus Register Map listed above provides a feature that allows you to download complete event data History data SER data Sync Check Report data or Generator Operation Profile data via Modbus The SEL 300G stores the twenty nine latest event reports twenty nine latest event summaries History data 512 SER Generator Operat...

Page 716: ... index number defined in Table F 7 Element field 0xffff means that this is Relay newly powered up or settings changed Event State field in SER report will be 0 or 1 Note 10 If E81AC N then all data from row of 81AC Off Freq Time Accumulator Since to row of Frequency Band 6 Time Accumulator and of limit setting will be set as 0x8000 ...

Page 717: ...ger This document gives instructions for installing the ACSELERATOR QuickSet software A Quick Tour guide is available as part of the online help Note Like all SEL relay products the SEL 300G can also be set and operated by a simple ASCII teminal THE ACSELERATOR QUICKSET SYSTEM REQUIREMENTS CPU Pentium class recommended 90 MHz or faster Operating System Windows 98 Me NT4 SP3 with 32 MB ram 64 MB ra...

Page 718: ...ry to have the correct comctl32 dll file installed on your computer in order to see the toolbar buttons If you do not see the toolbar buttons run the 40ComUpd exe located in the install directory This file will install the proper windows system drivers STARTING THE ACSELERATOR QUICKSET SOFTWARE You can start the ACSELERATOR QuickSet software in one of the following ways Double click the ACSELERATO...

Page 719: ...B IC IC87 IB87 IA87 TRCON GEN CTCON Y or E87 G Generator SEL 300G Partial DWG M300G193 Figure H 1 Protected Generator With No Step Up Transformer A B C a c b IA IB IC IC87 IB87 IA87 TRCON DACY CTCON Y SEL 300G Partial A B C a c b Winding 1 Winding 2 Generator DWG M300G191 Figure H 2 Delta Wye Power Transformer With Wye High Side CT Connections ...

Page 720: ...300G Partial A B C a c b Winding 1 Winding 2 DWG M300G190 Generator Figure H 3 Delta Wye Power Transformer With Wye High Side CT Connections A B C A B C a c b a c b Winding 1 Winding 2 IA IB IC IC87 IB87 IA87 TRCON DACY CTCON DAC SEL 300G Partial DWG M300G188 Generator Figure H 4 Delta Wye Power Transformer With Delta High Side CT Connections ...

Page 721: ...7 IA87 TRCON DABY CTCON DAB SEL 300G Partial Generator DWG M300G196 Figure H 5 Delta Wye Power Transformer With Delta High Side CT Connections A B C a c b Winding 1 Winding 2 IA IB IC IC87 IB87 IA87 TRCON DACDAC CTCON Y SEL 300G Partial C A B c b a Generator DWG M300G187 Figure H 6 Delta Delta Power Transformer With Wye High Side CT Connections ...

Page 722: ...TRCON DABDAB CTCON Y SEL 300G Partial C A B c b a DWG M300G192 Generator Figure H 7 Delta Delta Power Transformer With Wye High Side Connections A B C a c b IA IB IC IC87 IB87 IA87 TRCON YDAC CTCON Y SEL 300G Partial Winding 1 C B A c Winding 2 b a DWG M300G194 Generator Figure H 8 Wye Delta Power Transformer With Wye High Side Connections ...

Page 723: ... SEL 300G Partial Winding 1 C B A c Winding 2 b a Generator DWG M300G195 Figure H 9 Wye Delta Power Transformer With Wye High Side Connections A B C a c b IA IB IC IC87 IB87 IA87 TRCON YY CTCON Y SEL 300G Partial Winding 1 C B A c a Winding 2 b Generator DWG M300G189 Figure H 10 Wye Wye Power Transformer With Wye High Side CT Connections ...

Page 724: ......

Page 725: ...rrent wear CEV n Show compressed event report number n with 1 4 cycle resolution You can use parameters Ly SEC Sx R C and DIF with CEV similar to EVE commands described later Use CEV commands to save event reports for SEL 5601 Analytic Assistant CHIS Show compressed history CST Show compressed status report DAT Show date DAT m d y Enter date in this manner if Date Format setting DATE_F MDY DAT y m...

Page 726: ... Access Level 0 Terminate Distributed Port Switch Protocol connection SER m n Show rows m through n in the Sequential Events Recorder SER event report SER n Show the latest n rows in the Sequential Events Recorder SER event report SER d1 Show rows in the Sequential Events Recorder SER event report from date d1 SER d1 d2 Show rows in the Sequential Events Recorder SER event report from date d1 to d...

Page 727: ...cess Level 1 and Access Level B commands are available from Access Level 2 The screen prompt is BRE n Enter BRE W to preload breaker wear Enter BRE R to reset breaker monitor data CON n Control Relay Word bit RBn Remote Bit n n 1 through 8 Execute CON n and the relay responds CONTROL RBn Then reply with one of the following SRB n set Remote Bit n assert RBn CRB n clear Remote Bit n deassert RBn PR...

Page 728: ......

Search results

Summary of Contents for SEL-300G

Reviews:

Related manuals for SEL-300G

Brands by name

Popular brands

Schweitzer Engineering Laboratories SEL-300G, Instruction Manual

Search results

Summary of Contents for SEL-300G

Reviews:

Related manuals for SEL-300G

Brands by name

Popular brands