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GE DGP Series Instruction Manual

Digital generator protection relay
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GE Power Management
215 Anderson Avenue, Markham, Ontario
Canada L6E 1B3
Tel: (905) 294-6222 Fax: (905) 294-8512
Internet: http://www.GEindustrial.com/pm
Digital Generator Protection Relay™
All relays must be powered up at least once per year
to avoid deterioration of electrolytic capacitors and
subsequent relay failure.
DGP
Instruction Manual
DGP Revisions: V210.12000P
V210.10000F
V211.32000J
V210.22000D
Manual P/N: GEK-100666D
Copyright © 2000 GE Power Management
GE Power Management
Manufactured under an
ISO9002 Registered system.

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Summary of Contents for GE DGP Series

  • Page 1 DGP Revisions: V210.12000P V210.10000F V211.32000J V210.22000D Manual P/N: GEK-100666D Copyright © 2000 GE Power Management All relays must be powered up at least once per year to avoid deterioration of electrolytic capacitors and NOTE subsequent relay failure. GE Power Management...
  • Page 3 These instructions do not purport to cover all details or variations in equipment nor provide for every possible contingency to be met in connection with installation, operation, or maintenance. Should further information be desired or should particular problems arise which are not covered sufficiently for the purchaser’s purpose, the matter should be referred to the General Electric Company.

  • Page 5: Table Of Contents

    103: SEL TVM – SELECT TRIP VOLTAGE MONITORING ......2-10 104: SEL TCM – SELECT TRIP CURRENT MONITORING ......2-10 105: SELPRIM – SELECT PRIMARY/SECONDARY UNITS ....... 2-10 106: CT RATIO – CURRENT TRANSFORMER RATIO....... 2-10 GE Power Management DGP Digital Generator Protection System...
  • Page 6 BASIC CONSTRUCTION ................3-4 3.2.3 IDENTIFICATION ..................3-4 3.3 XTM TEST PLUGS 3.3.1 DESCRIPTION ..................3-6 3.3.2 TERMINAL DESIGNATION ............... 3-6 3.3.3 XTM TEST-CIRCUIT CONNECTIONS ............3-6 3.3.4 TEST PLUG INSERTION ................3-6 DGP Digital Generator Protection System GE Power Management...
  • Page 7 4.4 USING GE-LINK 4.4.1 DESCRIPTION ..................4-5 4.4.2 HARDWARE SETUP ................. 4-5 4.4.3 SOFTWARE SETUP.................. 4-5 a LOAD & START GE-LINK................4-5 b SET UP A NEW TEST UNIT..............4-5 4.4.4 RELAY SETUP ..................4-6 4.4.5 LOGGING INTO THE RELAY..............4-6 4.4.6 SETTING CHANGES.................
  • Page 8 5.3.13 T16: UNDERFREQUENCY UNIT #1 81-1U ..........5-14 5.3.14 T17: OVERFREQUENCY UNIT #1 81-1O..........5-15 5.3.15 T18: VOLTAGE TRANSFORMER FUSE FAILURE VTFF ...... 5-15 5.3.16 T19: TOC GROUND OVERCURRENT 51GN ......... 5-16 DGP Digital Generator Protection System GE Power Management...
  • Page 9 5. DATE/TIME....................8-8 6. RELAY TEST....................8-9 7. MMI TEST....................8-9 8. FIX UP SETTINGS CRC ................8-9 9. ENTER PASSWORD................8-10 10. CHANGE PASSWORD ................8-10 11. DIGITAL OUTPUT TEST................ 8-10 ........................8-11 GE Power Management DGP Digital Generator Protection System...
  • Page 10 RESPONSE ..................... 9-10 9.3.5 FUNCTION CODE 56: RETRANSMIT LAST PACKET ......9-10 a DESCRIPTION ..................9-10 b QUERY ....................9-10 c RESPONSE ..................... 9-10 9.4 MODBUS ERRORS 9.4.1 ERROR RESPONSES................9-11 DGP Digital Generator Protection System GE Power Management...
  • Page 11 9.5.12 STATION & GENERATOR ID REGISTER MAP ........9-24 9.5.13 DATE & TIME ..................9-24 9.5.14 MEMORY MAP ..................9-25 9.6 COIL COMMANDS 9.6.1 DESCRIPTION ..................9-49 9.7 FACTORY SETTINGS (GE FACTORY TESTS ONLY) 9.7.1 DESCRIPTION ..................9-50 10. GE-LINK SOFTWARE 10.1 INTRODUCTION 10.1.1 OVERVIEW....................10-1 10.1.2 SYSTEM REQUIREMENTS ..............
  • Page 12 ADDITIONS TO DGP MANUAL..............B-1 B.1.3 CHANGES TO DGP MANUAL ..............B-3 C. DGP FAQ C.1 DGP FAQ C.1.1 FREQUENTLY ASKED QUESTIONS ............C-1 C.1.2 NOT-SO-FREQUENTLY ASKED QUESTIONS ........C-4 D. WARRANTY D.1 DGP WARRANTY DGP Digital Generator Protection System GE Power Management viii...

  • Page 13: Product Description

    6. Refer to Figure 9–1: DGP COMMUNICATIONS WIRING on page 9–3 for the internal wiring of the cable. 7. GE-Link, the communications software required to access the relay from a PC, is included on the GE Power Management Products CD or available from the GE Power Management web site at www.ge.com/ indsys/pm.

  • Page 14: Order Codes & Selection Guide

    Two Power Supplies, 48 V DC Two Power Supplies, 110 to 125 V DC Test Blocks With Test Blocks Without Test Blocks Protocol GE Modem Protocol Modbus RTU Protcol (DGP***BCA only) Functions and Functions and Features – see DGP selection guide below. Features Revision DGP Revision A Firmware Table 1–2: DGP SELECTION GUIDE...

  • Page 15: Special Models

    DGP relay can be selected for DEC output relay assignment. The DEC 1000 is connected via the DGP printer port PL2. The DEC 1000 expansion unit is only compatible with the DGPFFFFFC units. NOTE GE Power Management DGP Digital Generator Protection System...

  • Page 16: Introduction

    These samples are used to compute current and voltage phasors that are used for the protection-function algorithms. The DGP™ system uses a man-machine interface (MMI) and GE-Link software for local and remote communication respectively.
  • Page 17 VOLT CURRENT VOLTAGE INPUTS TRIP A (DRY) CONTROL POWER TRIP A TRIP B (DRY) GROUND 94G1 GE Power Management TRIP B TRIP C (DRY) 94G2 Digital Generator Protection TRIP C TRIP D (DRY) 94G3 GENERATOR OFF LINE TRIP D TURBINE...

  • Page 18: Protection Features

    Accidental Energization A single-line diagram for the DGP is shown below. Transf. GEN. POWER SYSTEM 64G1 27NT 64G2 51GN VTFF 64G2 VTFF RS232 RS232 ALARM TRIP LAPTOP MODEM Figure 1–2: SINGLE LINE DIAGRAM DGP Digital Generator Protection System GE Power Management...

  • Page 19: Stator Differential (87G)

    40-2 function for security during stable power system swing condi- tions. Figure 2–7: MHO CHARACTERISTICS FOR 40-1 & 40-2 FUNCTIONS on page 2–21 shows the charac- teristics of this function. GE Power Management DGP Digital Generator Protection System...

  • Page 20: Anti-Motoring (32)

    Alternately, 64G1 can be used as a generator-bus ground detector in a high-impedance grounded or an ungrounded system. For this application, the VN input must be a zero-sequence voltage derived from the generator bus, and functions 64G2/27TN must be disabled. DGP Digital Generator Protection System GE Power Management...

  • Page 21: Ground Overcurrent (51Gn)

    Function 24T can be configured to operate different output relays for generator on-line and off-line conditions. This function incorporates a user-settable linear reset characteristic to mimic machine cooling. The figures in Section 2.3.12: OVEREXCITATION TRIP (VOLTS/HERTZ: 24T) show the characteristics of this function. GE Power Management DGP Digital Generator Protection System...

  • Page 22: Overvoltage (59)

    Detection of VTFF energizes the 74FF (Fuse Failure alarm) relay, de-energizes the 74CR (critical alarm) relay, and turns the status LED red, even though all protection functions except 40 and 51V are unaffected. DGP Digital Generator Protection System GE Power Management...

  • Page 23: Accidental Energization (Ae)

    It should also be noted that the pickup flag of function 51V is used as signal 50; therefore this logic will automatically be disabled if function 51V is disabled. GE Power Management DGP Digital Generator Protection System...
  • Page 24 (2) Each of the available protection functions can be configured to operate any combination of the 8 output relays (4-Trip and 4-Alarm). Figure 1–3: SIMPLE LOGIC DIAGRAM – 87G, 32, 27, 59, AND AE DGP Digital Generator Protection System GE Power Management...
  • Page 25 8 output relays (4-Trip and 4-Alarm). D S P L G C 2 . V S D Figure 1–4: SIMPLE LOGIC DIAGRAM – 46, 40, AND 51V GE Power Management DGP Digital Generator Protection System...
  • Page 26 (2) Each of the available protection functions can be configured to operate any combination of the 8 output relays (4-Trip and 4-Alarm). Figure 1–5: SIMPLE LOGIC DIAGRAM – 64G1, 64G2, 51GN, AND 24 DGP Digital Generator Protection System GE Power Management...
  • Page 27 (2) Each of the available protection functions can be configured to operate any combination of the 8 output relays (4-Trip and 4-Alarm). Figure 1–6: SIMPLE LOGIC DIAGRAM – 81-O AND 81-U GE Power Management DGP Digital Generator Protection System...
  • Page 28 * = 1 FOR 5 AMP RATED DGPs. D G P _ V T F F . V S D * = 5 FOR 1 AMP RATED DGPs. Figure 1–7: SIMPLE LOGIC DIAGRAM – VT FUSE FAILURE DGP Digital Generator Protection System GE Power Management...

  • Page 29: Other Features

    A time synchronizing signal can be connected to the DGP for synchronization to within 1 ms of a reference clock. Either IRIG-B or GE's G-NET system signal can be used. This signal is required only if it is necessary to synchronize the DGP to an external reference clock.

  • Page 30: Start-Up Self-Tests

    DEC1000 Contact Expansion Unit provides eleven additional output relays that can be factory configured to user specifications. Refer to the GE Power Management Product Catalog, the GE Power Management Prod- ucts CD, or instruction book GEK-105561 for additional details on the DEC1000.

  • Page 31: Adaptive Sampling Frequency

    The event list contains power system events, operator actions, and self-test alarms. The sequence of events can be accessed, either locally or remotely, by a PC via one of the RS232 ports. A full description of this function is contained in the Chapter 8: INTERFACE. GE Power Management DGP Digital Generator Protection System...

  • Page 32: Time Synchronization

    PL-3 may be used to synchronize the clock. In both cases, the clock in a given DGP is synchronized to within ±1 millisecond of any other digital relay clock, provided the two relays are wired to the same synchronizing sig- nal. DGP Digital Generator Protection System GE Power Management...

  • Page 33: Fault Report & Oscillography Data

    Oscillography data includes station and generator identification, a complete list of settings, the fault report, internal flags, and a selected number of pre-fault and post-fault waveform cycles. This data can be displayed using the GE-Link software program. See Chapter 10: GE-LINK SOFTWARE for details. 1.4.10 LOCAL MAN-MACHINE INTERFACE A local man-machine interface (MMI), incorporating a keypad, LED display, and 19 target LEDs, is provided to allow the user to enter settings, display present values, view fault target information, and access stored data.

  • Page 34: Remote Communications

    2. control operations 3. settings changes Refer to the Chapter 8: INTERFACE for a description of MMI password usage, and refer to Chapter 10: GE- LINK SOFTWARE for a description of GE-Link password usage. 1.4.15 REMOTE COMMUNICATIONS – MODBUS PROTOCOL The RS232 serial ports can be used with an optional RS485 to RS232 converter.

  • Page 35: Elementary Diagrams

    1 PRODUCT DESCRIPTION 1.5 ELEMENTARY DIAGRAMS 1.5 ELEMENTARY DIAGRAMS Figure 1–9: ELEMENTARY DIAGRAM WITH TEST BLOCKS, WYE VTs GE Power Management DGP Digital Generator Protection System...
  • Page 36 1.5 ELEMENTARY DIAGRAMS 1 PRODUCT DESCRIPTION Figure 1–10: ELEMENTARY DIAGRAM WITH TEST BLOCKS, DELTA VTs DGP Digital Generator Protection System GE Power Management...
  • Page 37 1 PRODUCT DESCRIPTION 1.5 ELEMENTARY DIAGRAMS Figure 1–11: ELEMENTARY DIAGRAM WITHOUT TEST BLOCKS, WYE VTs GE Power Management DGP Digital Generator Protection System...
  • Page 38 1.5 ELEMENTARY DIAGRAMS 1 PRODUCT DESCRIPTION Figure 1–12: ELEMENTARY DIAGRAM WITHOUT TEST BLOCKS, DELTA VTs DGP Digital Generator Protection System GE Power Management...
  • Page 39 1 PRODUCT DESCRIPTION 1.5 ELEMENTARY DIAGRAMS 0286A2925ASH1.DWG 0286A4911 SH9.DWG Figure 1–13: DIGITAL RELAY SYMBOL LEGEND GE Power Management DGP Digital Generator Protection System...
  • Page 40 1.5 ELEMENTARY DIAGRAMS 1 PRODUCT DESCRIPTION DGP Digital Generator Protection System GE Power Management...

  • Page 41: Calculation Of

    A sample generator system diagram is shown on the following page; it will be used to demonstrate the exam- ple settings for a typical DGP protection system. GE Power Management DGP Digital Generator Protection System...
  • Page 42 1 2 0 0 0 : 2 4 0 V 1 . 4 5 O h m S A M P G E N . V S D Figure 2–1: SAMPLE GENERATOR SYSTEM DGP Digital Generator Protection System GE Power Management...
  • Page 43 DQG 97 LQSXWV ODEHOHG $ % DQG & RQ WKH '*3 PXVW EH FRQQHFWHG WR V\VWHP SKDVHV $ % DQG & IRU FRUUHFW RSHUDWLRQ 6HWWLQJYDOXH QRW DYDLODEOH LQ '*3 $%$ PRGHOV 6HWWLQJYDOXH QRW DYDLODEOH LQ '*3 $$$ PRGHOV 6HWWLQJYDOXH QRW DYDLODEOH LQ '*3 &$ PRGHOV GE Power Management DGP Digital Generator Protection System...
  • Page 44 DQG 97 LQSXWV ODEHOHG $ % DQG & RQ WKH '*3 PXVW EH FRQQHFWHG WR V\VWHP SKDVHV $ % DQG & IRU FRUUHFW RSHUDWLRQ 6HWWLQJYDOXH QRW DYDLODEOH LQ '*3 $%$ PRGHOV 6HWWLQJYDOXH QRW DYDLODEOH LQ '*3 $$$ PRGHOV 6HWWLQJYDOXH QRW DYDLODEOH LQ '*3 &$ PRGHOV DGP Digital Generator Protection System GE Power Management...
  • Page 45 DQG 97 LQSXWV ODEHOHG $ % DQG & RQ WKH '*3 PXVW EH FRQQHFWHG WR V\VWHP SKDVHV $ % DQG & IRU FRUUHFW RSHUDWLRQ 6HWWLQJYDOXH QRW DYDLODEOH LQ '*3 $%$ PRGHOV 6HWWLQJYDOXH QRW DYDLODEOH LQ '*3 $$$ PRGHOV 6HWWLQJYDOXH QRW DYDLODEOH LQ '*3 &$ PRGHOV GE Power Management DGP Digital Generator Protection System...
  • Page 46 DQG 97 LQSXWV ODEHOHG $ % DQG & RQ WKH '*3 PXVW EH FRQQHFWHG WR V\VWHP SKDVHV $ % DQG & IRU FRUUHFW RSHUDWLRQ 6HWWLQJYDOXH QRW DYDLODEOH LQ '*3 $%$ PRGHOV 6HWWLQJYDOXH QRW DYDLODEOH LQ '*3 $$$ PRGHOV 6HWWLQJYDOXH QRW DYDLODEOH LQ '*3 &$ PRGHOV DGP Digital Generator Protection System GE Power Management...
  • Page 47 DQG 97 LQSXWV ODEHOHG $ % DQG & RQ WKH '*3 PXVW EH FRQQHFWHG WR V\VWHP SKDVHV $ % DQG & IRU FRUUHFW RSHUDWLRQ 6HWWLQJYDOXH QRW DYDLODEOH LQ '*3 $%$ PRGHOV 6HWWLQJYDOXH QRW DYDLODEOH LQ '*3 $$$ PRGHOV 6HWWLQJYDOXH QRW DYDLODEOH LQ '*3 &$ PRGHOV GE Power Management DGP Digital Generator Protection System...
  • Page 48 DQG 97 LQSXWV ODEHOHG $ % DQG & RQ WKH '*3 PXVW EH FRQQHFWHG WR V\VWHP SKDVHV $ % DQG & IRU FRUUHFW RSHUDWLRQ 6HWWLQJYDOXH QRW DYDLODEOH LQ '*3 $%$ PRGHOV 6HWWLQJYDOXH QRW DYDLODEOH LQ '*3 $$$ PRGHOV 6HWWLQJYDOXH QRW DYDLODEOH LQ '*3 &$ PRGHOV DGP Digital Generator Protection System GE Power Management...
  • Page 49 DQG 97 LQSXWV ODEHOHG $ % DQG & RQ WKH '*3 PXVW EH FRQQHFWHG WR V\VWHP SKDVHV $ % DQG & IRU FRUUHFW RSHUDWLRQ 6HWWLQJYDOXH QRW DYDLODEOH LQ '*3 $%$ PRGHOV 6HWWLQJYDOXH QRW DYDLODEOH LQ '*3 $$$ PRGHOV 6HWWLQJYDOXH QRW DYDLODEOH LQ '*3 &$ PRGHOV GE Power Management DGP Digital Generator Protection System...

  • Page 50: Configuration Settings

    101: UNITID – UNIT ID NUMBER UNITID is a decimal number between 0 and 9999 (for units with GE Modem protocol only) or 1 to 127 (for units with Modbus protocol) stored in non-volatile memory that uniquely identifies a DGP relay system. When the DGP is accessed via one of its serial ports, the UNITID is required to establish communication, thus providing a measure of security.

  • Page 51: 108: Commport - Communications Port

    PC. Normally, 1 stop bit is selected. However, certain modems or other communications hardware might dictate using 2 stop bits. GE-Link communications software can be configured to match the DGP setting for baud rate, parity, and stop bits.

  • Page 52: 112: Preflt - Prefault Cycles

    NOM VOLT = 114.3 volts SELPRIM = PRIMARY (0) RATEDCUR = 4.25 amps CT RATIO = 1600 VT CONN = WYE (0) VT RATIO = 157.5 NCTRATIO = 1600 COMMPORT = 2401 DGP Digital Generator Protection System GE Power Management...

  • Page 53: Protection Function Settings

    CTs are not of identical design or if a higher CT error margin is desired. For the sample generator system, set K1 = 2% and PICKUP = 0.3 A. GE Power Management DGP Digital Generator Protection System...
  • Page 54 External Fault No CT Error (I = I ) MARGIN FOR CT ERROR Amperes Gen. to bus Bus to Gen. DGP/87G Figure 2–2: 87G CHARACTERISTICS – K1 = 1%, PICKUP = 0.3 A DGP Digital Generator Protection System GE Power Management...
  • Page 55 External Fault No CT Error (I = I ) MARGIN FOR CT ERROR Amperes Gen. to bus Bus to Gen. DGP/87G Figure 2–3: 87G CHARACTERISTICS – K1 = 2%, PICKUP = 0.3 A GE Power Management DGP Digital Generator Protection System...
  • Page 56 External Fault No CT Error (I = I ) MARGIN FOR CT ERROR Amperes Gen. to bus Bus to Gen. DGP/87G Figure 2–4: 87G CHARACTERISTICS – K1 = 5%, PICKUP = 0.3 A DGP Digital Generator Protection System GE Power Management...
  • Page 57 (I = I ) TRIP AREA FOR INTERNAL FAULTS MARGIN FOR CT ERROR Amperes Gen. to bus Bus to Gen. DGP/87G Figure 2–5: 87G CHARACTERISTICS – K1 = 10%, PICKUP = 0.3 A GE Power Management DGP Digital Generator Protection System...

  • Page 58: Current Unbalance Alarm 46A

    This function should be set at or below the negative-sequence current capability of the machine. For the sample generator system, set PICKUP capability of the machine 211765 × 0.08 ---------------------------------------------- - × × 1.732 1600 0.34 A secondary set K2 = machine capability = 10 DGP Digital Generator Protection System GE Power Management...
  • Page 59 2 CALCULATION OF SETTINGS 2.3 PROTECTION FUNCTION SETTINGS 10000.0 1000.0 100.0 Time Factor K 10.0 0.01 Negative Sequence Current / Rated Current Figure 2–6: TIME CURRENT CHARACTERISTIC OF 46T FUNCTION GE Power Management DGP Digital Generator Protection System...

  • Page 60: Loss Of Excitation 40, 40-1, 40-2

    RADIUS 7.77 ohms -------------- - TL12 0.06 seconds Set the 40-2 setpoints to the following values: 30.57 3.36 CENTER 16.97 ohms -------------------------------- - 30.57 RADIUS 15.28 ohms -------------- - TL12 0.5 seconds DGP Digital Generator Protection System GE Power Management...

  • Page 61: Anti-Motoring (Reverse Power)

    Timer TL2, associated with 32-2, should be set to override the power swings expected during normal system operations. A setting of 10 to 60 seconds is suggested. Setting 803: SQ TR EN can be set to YES or NO, depending on the generator tripping strategy used. GE Power Management DGP Digital Generator Protection System...

  • Page 62: Overcurrent With Voltage Restraint (51V)

    , then 65.5 is used as its value in the equation. ⁄ 5. Reset Time: Linear reset with maximum of 1.4 seconds. Table 2–2: 51V RESTRAINT VOLTAGES CURRENT RESTRAINT VOLTAGES PHASE → VT → DELTA DELTA DGP Digital Generator Protection System GE Power Management...
  • Page 63 5.93 × % restraint = ---------- - 32.9%   1.76 × TIME FAC (K) = 0.75 -------------- - 1 0.985 or higher –   0.329 set TIME FAC = 1.0 GE Power Management DGP Digital Generator Protection System...
  • Page 64 2.3 PROTECTION FUNCTION SETTINGS 2 CALCULATION OF SETTINGS Time Factor K 0.25 0.01 Multiple of Pickup Setting Figure 2–8: 51V TIME-CURRENT CHARACTERISTICS FOR 0 TO 30% RESTRAINT DGP Digital Generator Protection System GE Power Management...
  • Page 65 2 CALCULATION OF SETTINGS 2.3 PROTECTION FUNCTION SETTINGS Time Factor K 0.25 0.01 Multiple of Pickup Setting Figure 2–9: 51V TIME-CURRENT CHARACTERISTICS FOR 50% RESTRAINT GE Power Management DGP Digital Generator Protection System...
  • Page 66 2.3 PROTECTION FUNCTION SETTINGS 2 CALCULATION OF SETTINGS Time Factor K 0.25 0.01 Multiple of Pickup Setting Figure 2–10: 51V TIME-CURRENT CHARACTERISTICS FOR 75% RESTRAINT DGP Digital Generator Protection System GE Power Management...
  • Page 67 2 CALCULATION OF SETTINGS 2.3 PROTECTION FUNCTION SETTINGS Time Factor K 0.25 0.01 Multiple of Pickup Setting Figure 2–11: 51V TIME-CURRENT CHARACTERISTICS FOR 100% RESTRAINT GE Power Management DGP Digital Generator Protection System...

  • Page 68: Stator Ground Fault 64G-1

    Settings 3005: FORPWR-L and 3006: FORPWR-H, which can be set at 47 and 85 watts (based on margin of about 5%) respectively to inhibit the function between the limits. This function can also be blocked when the generator is off-line; refer to Setting 2501: SELBKDI1. DGP Digital Generator Protection System GE Power Management...

  • Page 69: Overexcitation Alarm (Volts/Hertz: 24A)

    2. V and V values used are phase-ground voltages for wye-connected VTs. However, phase-phase volt- ages are used for delta-connected VTs. The following table shows the voltages used by each of the three GE Power Management DGP Digital Generator Protection System...
  • Page 70 For the sample generator system, using CURVE #4 (definite time) and operating time of 45 seconds: set INV PU = 1.10 per unit set TIME FAC = 45 seconds set INST PU = 1.18 per unit set TL7 = 2 seconds set RESET = 30 seconds DGP Digital Generator Protection System GE Power Management...
  • Page 71 2 CALCULATION OF SETTINGS 2.3 PROTECTION FUNCTION SETTINGS Time Factor K Multiple of "INV PU" Figure 2–12: TIME CHARACTERISTICS OF FUNCTION 24T (CURVE 1) GE Power Management DGP Digital Generator Protection System...
  • Page 72 2.3 PROTECTION FUNCTION SETTINGS 2 CALCULATION OF SETTINGS Time Factor K Multiple of "INV PU" Figure 2–13: TIME CHARACTERISTICS OF FUNCTION 24T (CURVE 2) DGP Digital Generator Protection System GE Power Management...
  • Page 73 2 CALCULATION OF SETTINGS 2.3 PROTECTION FUNCTION SETTINGS Time Factor K Multiple of "INV PU" Figure 2–14: TIME CHARACTERISTICS OF FUNCTION 24T (CURVE 3) GE Power Management DGP Digital Generator Protection System...

  • Page 74: Overvoltage 59

    For determining the time factor K (assuming CURVE #1 is used), use an operating time of about 45 seconds at 115% of PICKUP voltage. Voltage ( V ) = 1.15 × 126 = 144.9 volts   144.9 ⋅ Time Factor K = -------------- - 1 6.75 –   DGP Digital Generator Protection System GE Power Management...
  • Page 75 2 CALCULATION OF SETTINGS 2.3 PROTECTION FUNCTION SETTINGS 1000 Time Factor K Percent of Pickup Figure 2–15: 59 TIME-VOLTAGE CHARACTERISTICS GE Power Management DGP Digital Generator Protection System...

  • Page 76: Undervoltage Cutoff Of 81

    Refer to the Nomenclature Guide for available functions Note that for DGP***ABA models, some of the SELBKDI1 settings are functionally redundant; any one of such settings may be used to obtain the specified functionality. DGP Digital Generator Protection System GE Power Management...
  • Page 77 ALARM codes (Settings 1001 and 1002) to 0000. This is in addition to the normal way of disabling function AE by setting its TRIP and ALARM codes (Settings 2701 and 2702) to 0000. For the sample generator system, set AE ARM = 0 (AND) GE Power Management DGP Digital Generator Protection System...
  • Page 78 For the sample generator system, 27 can be set as follows: CURVE # = 2 (Definite Time) PICKUP = 102 V (< 90% of NOM VOLT of 114.3 V) TIME FAC = 1.0 second DGP Digital Generator Protection System GE Power Management...
  • Page 79 2 CALCULATION OF SETTINGS 2.3 PROTECTION FUNCTION SETTINGS Time Factor K Multiple of Pickup Setting Figure 2–16: 51GN TIME-CURRENT CHARACTERISTICS GE Power Management DGP Digital Generator Protection System...
  • Page 80 2.3 PROTECTION FUNCTION SETTINGS 2 CALCULATION OF SETTINGS Time Factor K Percent of Pickup Figure 2–17: 27 TIME-VOLTAGE CHARACTERISTICS DGP Digital Generator Protection System GE Power Management...
  • Page 81 Pickup level Amps CURRENT UNBALANCE – ALARM: 46A ALARM Configure alarm outputs PICKUP Pickup current (Negative sequence) Amps TL14 Timer TL14 setting Sec. CURRENT UNBALANCE – TRIP: 46T TRIP Configure trip outputs GE Power Management DGP Digital Generator Protection System...
  • Page 82 Sec. ANTI-MOTORING #2: 32-2 TRIP Configure trip outputs ALARM Configure alarm outputs REV PWR Reverse power pickup Watts Timer TL2 setting Sec. OVERCURRENT WITH VOLTAGE RESTRAINT: 51V 1001 TRIP Configure trip outputs DGP Digital Generator Protection System GE Power Management...
  • Page 83 Per Unit 1408 Timer TL7 setting Sec. 1409 RESET Reset time Sec. OVERVOLTAGE: 59 1501 TRIP Configure trip outputs 1502 ALARM Configure alarm outputs 1503 PICKUP Inverse function pickup voltage (positive- sequence) Volts GE Power Management DGP Digital Generator Protection System...
  • Page 84 OVERFREQUENCY SETPOINT 1: 81-1O 2101 TRIP Configure trip outputs 2102 ALARM Configure alarm outputs 2103 SET PNT Set point 2104 TL15 Timer TL15 setting Sec. OVERFREQUENCY SETPOINT 2: 81-2O 2201 TRIP Configure trip outputs DGP Digital Generator Protection System GE Power Management...
  • Page 85 Configure alarm outputs VOLTAGE TRANSFORMER FUSE FAILURE: VTFF 2601 VTFF Enable/Disable VTFF ACCIDENTAL ENERGIZATION: AE 2701 TRIP Configure trip outputs 2702 ALARM Configure alarm outputs 2703 AE ARM Arming logic, Accidental Energization GE Power Management DGP Digital Generator Protection System...
  • Page 86 CURRENT UNBALANCE – ALARM: 46A ALARM Configure alarm outputs PICKUP Pickup current (Negative sequence) Amps TL14 Timer TL14 setting Sec. CURRENT UNBALANCE – TRIP: 46T TRIP Configure trip outputs ALARM Configure alarm outputs DGP Digital Generator Protection System GE Power Management...
  • Page 87 1002 ALARM Configure alarm outputs 1003 PICKUP Pickup current Amps 1004 TIME FAC Time factor Sec. STATOR GROUND – ZONE 1: 64G1 1101 TRIP Configure trip outputs 1102 ALARM Configure alarm outputs GE Power Management DGP Digital Generator Protection System...
  • Page 88 UVCUTOFF Undervoltage cutoff level for functions 81 Volts UNDERFREQUENCY SETPOINT 1: 81-1U 1701 TRIP Configure trip outputs 1702 ALARM Configure alarm outputs 1703 SET PNT Set point 1704 Timer TL8 setting Sec. DGP Digital Generator Protection System GE Power Management...

  • Page 89: Voltage Transformer Fuse Failure Vtff

    Define DI6 Function VOLTAGE TRANSFORMER FUSE FAILURE: VTFF 2601 VTFF Enable/Disable VTFF ACCIDENTAL ENERGIZATION: AE 2701 TRIP Configure trip outputs 2702 ALARM Configure alarm outputs 2703 AE ARM Arming logic, Accidental Energization GE Power Management DGP Digital Generator Protection System...

  • Page 90: Ground Overcurrent 51Gn

    UNDERVOLTAGE: 27 2901 TRIP Configure trip outputs 2902 ALARM Configure alarm outputs 2903 PICKUP Pickup voltage (Positive sequence) Volts 2904 TIME FAC Time factor sec. 2905 CURVE # Curve number (1-Inverse, 2-Def. Time) DGP Digital Generator Protection System GE Power Management...

  • Page 91: Dgp Aca Settings Table

    Configure trip outputs ALARM Configure alarm outputs K factor PICKUP Pickup level Amps CURRENT UNBALANCE – ALARM: 46A ALARM Configure alarm outputs PICKUP Pickup current (Negative sequence) Amps TL14 Timer TL14 setting Sec. GE Power Management DGP Digital Generator Protection System...
  • Page 92 Enable sequential trip REV PWR Reverse power pickup Watts Timer TL1 setting Sec. ANTI-MOTORING #2: 32-2 TRIP Configure trip outputs ALARM Configure alarm outputs REV PWR Reverse power pickup Watts Timer TL2 setting Sec. DGP Digital Generator Protection System GE Power Management...
  • Page 93 1406 TIME FAC Time factor Sec. 1407 INST PU Pickup - V/Hz (Instantaneous) Per Unit 1408 Timer TL7 setting Sec. 1409 RESET Reset time Sec. OVERVOLTAGE: 59 1501 TRIP Configure trip outputs GE Power Management DGP Digital Generator Protection System...
  • Page 94 Configure trip outputs 2002 ALARM Configure alarm outputs 2003 SET PNT Set point 2004 TL11 Timer TL11 setting Sec. OVERFREQUENCY SETPOINT 1: 81-1O 2101 TRIP Configure trip outputs 2102 ALARM Configure alarm outputs DGP Digital Generator Protection System GE Power Management...
  • Page 95 Configure alarm outputs 2507 DI4 TIMR Pickup delay, DI4 timer sec. 2508 DI6 FUNC Define DI6 Function VOLTAGE TRANSFORMER FUSE FAILURE: VTFF 2601 VTFF Enable/Disable VTFF ACCIDENTAL ENERGIZATION: AE 2701 TRIP Configure trip outputs GE Power Management DGP Digital Generator Protection System...
  • Page 96 Pickup voltage (3rd Harmonic at generator neutral) Volts 3004 TL20 Timer TL20 setting Sec. 3005 FORPWR-L Lower limit of Forward Power window Watts 3006 FORPWR-H Upper limit of Forward Power window Watts DGP Digital Generator Protection System GE Power Management...

  • Page 97: Warning

    PL3 is used for IRIG-B signal input to the DGP. Note that the PL2 and PL3 connectors are not included on all DGP models; see Section 1.1.2: ORDER CODES & SELECTION GUIDE on page 1–2 for details. GE Power Management DGP Digital Generator Protection System...
  • Page 98 3.1 CASE ASSEMBLY 3 HARDWARE DESCRIPTION Figure 3–1: DGP OUTLINE DRAWING DGP Digital Generator Protection System GE Power Management...
  • Page 99 VT INPUTS: 6 phase CT inputs 3 phase vt inputs, 1 residual CT input wye or delta 1 residual/neutral CT input 1 neutral vt input 704752A8.CDR Figure 3–2: FRONT AND REAR VIEW GE Power Management DGP Digital Generator Protection System...

  • Page 100: Circuit Board Modules

    Each module has its own identification number, consisting of a three-letter code followed by a three-digit num- ber. These are found at the bottom of each front panel. Figure 3–3: DGP POWER SUPPLY MODULE DGP Digital Generator Protection System GE Power Management...
  • Page 101 3 HARDWARE DESCRIPTION 3.2 CIRCUIT BOARD MODULES Figure 3–4: DGP MMI MODULE GE Power Management DGP Digital Generator Protection System...

  • Page 102: Xtm Test Plugs

    When the test plugs are inserted into the receptacle, parts of the power system become isolated from the DGP. Refer to the elementary diagrams in Section 1.5: ELEMENTARY DIAGRAMS on page 1–23 for the TP points associated with each of the test plugs. DGP Digital Generator Protection System GE Power Management...

  • Page 103: Installation

    If damage resulting from rough handling is evident, file a damage claim at once with the transportation com- pany and promptly notify the nearest GE Power Management Sales Office. If the equipment is not to be installed immediately, it should be stored indoors in a location that is dry and protected from dust, metallic chips, and severe atmospheric conditions.
  • Page 104 3.4 INSTALLATION 3 HARDWARE DESCRIPTION DGP Digital Generator Protection System GE Power Management...

  • Page 105: Acceptance Tests

    • T29: Undervoltage, 27 * • T16: Overexcitation (Volts/Hz) Alarm, 24A • T30: 3rd Harmonic Neutral Undervoltage, 27TN * • T17: Overexcitation (Volts/Hz) Trip, 24T * Functions available in some models only. GE Power Management DGP Digital Generator Protection System...

  • Page 106: Test Equipment

    • Figure 1–7: SIMPLE LOGIC DIAGRAM – VT FUSE FAILURE on page 1–16 b) REFERENCES • Chapter 10: GE-LINK SOFTWARE • The DGP default settings shown in Table 2–1: DGP SYSTEM SETTINGS & RATINGS on page 2–3 4.2.3 EQUIPMENT GROUNDING All equipment used in testing the DGP relay should be connected to a common grounding point to provide noise immunity.

  • Page 107: General Instructions

    The decimal point is a character that can only be entered at the factory. This password must be changed before any Setting functions can be accessed. See Section 8.3.9: ACTIONS KEY [ACT] on page 8–7 for information on how to change the password. GE Power Management DGP Digital Generator Protection System...

  • Page 108: Entering The Test Mode

    [ENT] key. For DGP units with GE Modem protocol : If this is the first time the Control Level functions are used, the password has the factory value "5678.". The decimal point, ".", is part of the password that can only be entered at the factory.

  • Page 109: Using Ge-Link

    The following section is intended to give a step-by-step procedure to test the relay, from setting up communica- tions to the application of the voltages and current inputs. It will be necessary to be familiar with the GE-Link software. Refer to Chapter 10: GE-LINK SOFTWARE for detailed information on using GE-Link.

  • Page 110: Relay Setup

    1. To log on to the Test unit, click on the test unit IED to highlight it. Select the Communication > Connect Relay menu item and click on Connect. 2. When prompted by GE-Link, enter the password for the appropriate access levels (GE Modem protocol only).

  • Page 111: Setting Changes

    IED Settings folder shown below. Figure 4–2: GE-LINK SETTINGS MENU 2. Additional detail on changing Settings with GE-Link is provided in Chapter 10: GE-LINK SOFTWARE. 3. Once a setting has been modified, select the Control > Send Settings to Relay menu item.

  • Page 112: Initial Test Setup

    Select the current IED and use the File > Save Settings to File menu item to save the DGP settings to a file. GE-Link will prompt for a file name. More information on using this command can be found in Chapter 10: GE-LINK SOFTWARE.

  • Page 113: General Relay Tests 4.6.1 Note

    6. Enter the Setting Level password. Press the [SET] key followed by "103" to change the setting for the trip circuit monitor. 7. Enter Setting 103: SEL TVM = 0000. Press the [END] and then [ENT] keys. GE Power Management DGP Digital Generator Protection System...

  • Page 114: Display Test

    10. The display will prompt PRINTER TST?. if you do not have a printer or the printer port is not active, then press the [3/N] followed by the [ENT] key. Otherwise, press [1/Y] followed by the [ENT] key. DGP Digital Generator Protection System GE Power Management...

  • Page 115: T2: Digital Output Tests

    If GE-Link is used to perform this test, none of the outputs will operate unless Jumper J1 on the MMI module is removed. Refer to Figure 3–4: DGP MMI MODULE on page 3–5.
  • Page 116 (SEE TABLE TO LEFT) AG1 or TP1-1 RATED DC POWER RATED DC SUPPLY VOLTAGE 48, 125, 250 V DC AG2 or TP1-15 BH14 SURGE & CASE GROUND Figure 4–3: DIGITAL OUTPUT TEST CONNECTIONS DGP Digital Generator Protection System GE Power Management...

  • Page 117: T3: Digital Input Tests

    12. Apply DC across DI6 (BE2—BE1). Using the MMI and the INFORMATION–VALUES command, verify that DIG IN 6 (EXT VTFF) = CLOSE. 13. Remove DC from DI6 (BE2—BE1). Using the MMI and the INFORMATION–VALUES command, verify that DIG IN 6 (EXT VTFF) = OPEN. GE Power Management DGP Digital Generator Protection System...
  • Page 118 UNIT UNDER TEST AG1 or TP1-1 RATED DC POWER RATED DC SUPPLY VOLTAGE 48, 125, 250 V DC AG2 or TP1-15 BH14 SURGE & CASE GROUND Figure 4–4: DIGITAL INPUT TEST CONNECTIONS DGP Digital Generator Protection System GE Power Management...

  • Page 119: T4: Ac System Input Test

    Alternately, whenever the MMI display is blank, pressing the [CLR] key will automatically scroll through all of the present values. 5. Repeat steps 2 through 4 using the following source frequencies: 30.5 and 79.5 Hz. GE Power Management DGP Digital Generator Protection System...
  • Page 120 AH7 or TP2-13 AG1 or TP1-1 RATED DC POWER RATED DC SUPPLY VOLTAGE 48, 125, 250 V DC AG2 or TP1-15 – BH14 SURGE & CASE GROUND Figure 4–5: AC SYSTEM INPUT TEST CONNECTIONS DGP Digital Generator Protection System GE Power Management...

  • Page 121: Protection Tests

    2.Where appropriate, current levels are defined with two numbers as xx ( yy ); xx is the value to be used for relays rated at 5 amperes and ( yy ) is the value to be used for 1 ampere relays. GE Power Management DGP Digital Generator Protection System...

  • Page 122: T5: Generator Differential Test 87G

    5. Set IAS to 5 A (1 A) rms and test pickup and test trip should not operate. 6. Decrease IAS to 3 A (0.75 A) rms and test pickup and test trip should operate. 7. Repeat the above test for phases B (IBR, IBS) and C (ICR, ICS). DGP Digital Generator Protection System GE Power Management...
  • Page 123 7(50,1$/ %/2&. 7(50,1$/ %/2&. 7(50,1$/ 180%(5 180%(5 180%(5 180%(5 180%(5 180%(5 180%(5 180%(5 73 73 73 73 73 73 73 73 & 73 73 73 73 Figure 4–6: GENERATOR DIFFERENTIAL TEST CONNECTIONS GE Power Management DGP Digital Generator Protection System...
  • Page 124 T = the time between successive tests and Original Trip Time = the 5.5 to 5.7 seconds it originally took to trip the relay. If the time between successive trips is greater than 230 sec- onds, the relay will trip in the original trip time. DGP Digital Generator Protection System GE Power Management...
  • Page 125 BH8 or TP1-14 AG1 or TP1-1 RATED DC POWER RATED DC SUPPLY VOLTAGE 48, 125, 250 V DC AG2 or TP1-15 – BH14 SURGE & CASE GROUND Figure 4–7: CURRENT UNBALANCE TEST CONNECTIONS GE Power Management DGP Digital Generator Protection System...
  • Page 126 10. Set VA = 50 V rms ∠0°, IA = 2.7 (0.54) A rms ∠90°, and all other AC sources to 0 V. Verify that the test pickup and test trip do not operate. DGP Digital Generator Protection System GE Power Management...
  • Page 127 INLET VLV = OPEN. Check that the test trip contact has dropped out. 9. Change the following setting: (803) SQ TR EN = NO [3/N] 10. Repeat steps 7 to 8. GE Power Management DGP Digital Generator Protection System...
  • Page 128 PHASE C MAG. PHASE MAG. PHASE MAG. PHASE 0.45 (0.09) A 0° 0.45 (0.09) A –120° 0.45 (0.09) A –240° 2.0 (0.4) A 0° 2.0 (0.4) A –120° 2.0 (0.4) A –240° DGP Digital Generator Protection System GE Power Management...
  • Page 129 9. Verify that the test pickup and test trip operates in 5.00 to 5.05 seconds. VA, VB, and VC must change from 70 V rms to 29 V rms with the source voltage continuously NOTE GE Power Management DGP Digital Generator Protection System...
  • Page 130 RATED DC POWER RATED DC SUPPLY VOLTAGE 48, 125, 250 V DC AG2 or TP1-15 – BH14 SURGE & CASE G R O U N D Figure 4–8: STANDARD FUNCTIONAL TEST CONNECTIONS DGP Digital Generator Protection System GE Power Management...
  • Page 131 5. The following results should be obtained: Test A : Test pickup and test trip do not operate. Test B : Test pickup operates immediately and test trip operates in 110 to 130 ms. GE Power Management DGP Digital Generator Protection System...
  • Page 132 7. Apply DC voltage across DI1 (BG8—BG7). Repeat test B and verify that the test contacts do not operate. Remove DC from DI1 (BG8—BG7) and verify that test pickup operates immediately and test trip operates in 110 to 130 ms. DGP Digital Generator Protection System GE Power Management...
  • Page 133 TEST PICKUP TESTER AG1 or TP1-1 RATED DC POWER RATED DC SUPPLY VOLTAGE 48, 125, 250 V DC AG2 or TP1-15 – BH14 SURGE & CASE GROUND Figure 4–9: STATOR GROUND TEST CONNECTIONS GE Power Management DGP Digital Generator Protection System...
  • Page 134 Tests B, C, and D : Test pickup operates immediately and test trip operates in 1.00 to 1.05 seconds. Test E : Test pickup operates immediately and test trip operates in 1.20 to 1.40 seconds. DGP Digital Generator Protection System GE Power Management...
  • Page 135 RESET = Setting 1409. If the time between successive trips is greater than the RESET time, the relay will trip in the original trip time. GE Power Management DGP Digital Generator Protection System...
  • Page 136 Test C : Test pickup operates immediately and test trip operates in 540 to 570 ms (see note below). For DGP****CA models, the trip time should be approximately 30 ms since the instantaneous unit should operate before the inverse curve. NOTE DGP Digital Generator Protection System GE Power Management...
  • Page 137 5. Verify that test pickup and test trip do not operate. 6. Change the frequency of the voltage inputs to 59 Hz. 7. Verify that test pickup operates immediately and test trip operates in 2.0 to 2.1 seconds. GE Power Management DGP Digital Generator Protection System...
  • Page 138 5. Verify that test pickup and test trip do not operate. 6. Change the frequency of the voltage inputs to 59 Hz. 7. Verify that test pickup operates immediately and test trip operates in 2.0 to 2.1 seconds. DGP Digital Generator Protection System GE Power Management...
  • Page 139 5. Verify that the test pickup and test trip do not operate. 6. Change the frequency of the voltage inputs to 61 Hz. 7. Verify test pickup operates immediately and test trip operates in 2.0 to 2.1 seconds. GE Power Management DGP Digital Generator Protection System...
  • Page 140 5. Verify that the test pickup and test trip do not operate. 6. Change the frequency of the voltage inputs to 61 Hz. 7. Verify test pickup operates immediately and test trip operates in 2.0 to 2.1 seconds. DGP Digital Generator Protection System GE Power Management...
  • Page 141 1.30 to 1.45 seconds. 7. Repeat steps 4 and 5, but use 20 (4.0) A rms in step 4, and verify that test pickup operates immediately and test trip operates in 184 to 204 ms. GE Power Management DGP Digital Generator Protection System...
  • Page 142 7. Change IAS to 0.2 A ∠0°, 60Hz. Verify that test pickup and test trip do not operate. 8. Change IAS to 0.3 A ∠0°, 60Hz. Verify that test pickup operates immediately, and test trip operates in 2.0 to 2.1 seconds. DGP Digital Generator Protection System GE Power Management...
  • Page 143 AG1 or TP1-1 RATED DC POWER RATED DC SUPPLY VOLTAGE 48, 125, 250 V DC AG2 or TP1-15 – BH14 SURGE & CASE GROUND Figure 4–10: STATOR GROUND TEST FOR 27TN FUNCTION GE Power Management DGP Digital Generator Protection System...
  • Page 144 Print out or scroll through all of the settings. Compare them with the initial Settings of the relay, and change to initial values. If the initial settings were saved to a disk file before testing using GE-Link, download the file to the relay! DGP Digital Generator Protection System...
  • Page 145 2. Before beginning the test, the relay settings should be printed for reference and verification. If no printer is available, scroll through each setting and make sure they match the required settings of the relay. GE Power Management DGP Digital Generator Protection System...
  • Page 146 [ENT] key. If you have a printer, press the [1/Y] followed by the [ENT] key. The printout will be 40 characters, which include the alphabet, the numbers 0 through 9, as well as the “:”, “=”, “/” and “.” characters. Forty lines will be printed. DGP Digital Generator Protection System GE Power Management...
  • Page 147 6. End the test mode by scrolling to the END TEST MODE selection, then press the [ENT] key. Alternatively, [END] followed by the [ENT] can be pressed to end the test and re-enable protection. GE Power Management DGP Digital Generator Protection System...
  • Page 148 12. Apply DC across digital input DI6 (BE2—BE1). Using the MMI and the INFORMATION–VALUES com- mand, verify that DIG IN 6 = CLOSE. 13. Remove DC from digital input DI6 (BE2—BE1). Using the MMI and the INFORMATION–VALUES com- mand, verify that DIG IN 6 = OPEN. DGP Digital Generator Protection System GE Power Management...
  • Page 149 MMI display is blank, pressing the [CLR] key will automatically scroll through all of the present values. 8. Repeat steps 2 through 6 using the following source frequencies: 30.5 and 79.5 Hz. GE Power Management DGP Digital Generator Protection System...

  • Page 150: T6: Current Unbalance Alarm 46A

    TL14 seconds later the test trip relay should operate. Lower the negative- sequence current to PICKUP – 0.1 (0.02) =______ A rms and the test pickup and test trip relays should not operate. DGP Digital Generator Protection System GE Power Management...

  • Page 151: T7: Current Unbalance Trip 46T

    T = the time between successive tests and Original Trip Time = the time to trip the relay when the test was first run. If the time between successive trips is greater than 230 seconds, the relay will trip in the original trip time. GE Power Management DGP Digital Generator Protection System...
  • Page 152 EXT VTFF = CLOSE. 9. Reapply the above phase current that placed the impedance inside the Mho circle. Verify that the test pickup operates and the test trip does not operate. DGP Digital Generator Protection System GE Power Management...
  • Page 153 10. Change Setting 803: SQ TR EN to NO (3/N). Leaving all of the AC signals applied, notice that the test pickup operates immediately and the test trip operates in 5.0 to 5.1 seconds. 11. Return Setting 803: SQ TR EN to its original value. GE Power Management DGP Digital Generator Protection System...
  • Page 154 10. While continuing to input the current, remove the DC from DI6 (BE2—BE1). The test pickup operates immediately and test trip operates after Trip Time expires. DGP Digital Generator Protection System GE Power Management...
  • Page 155 TL5 seconds later the test trip relay will operate. 6. Change Setting 2501: SELBKDI1 to BLK#2 (2). Apply DC voltage across DI1 (BG*—BG7). Re-apply the AC inputs of step 3 and verify that only the test pickup operates. GE Power Management DGP Digital Generator Protection System...
  • Page 156 This will cause the test pickup relay to operate and the test trip relay will operate after the Trip Time has expired. 7. Change the voltage of any one phase until Voltage/Frequency is equal to: V/Hz setting – 0.1 =______. The test pickup and test trip relays will not operate. DGP Digital Generator Protection System GE Power Management...
  • Page 157 RESET is Setting 1409. If the time between successive trips is greater than the RESET time, the relay will trip in the original trip time. GE Power Management DGP Digital Generator Protection System...
  • Page 158 6. Set the frequency at SET PNT + 0.04 =______ Hz. This will prevent the test pickup and the test trip from operating. 7. Change the frequency to SET PNT – 0.04 =______ Hz. This will cause the test pickup relay to operate and the test trip relay will operate TL8 seconds later. DGP Digital Generator Protection System GE Power Management...
  • Page 159 Verify that neither the test pickup nor the test trip operates. 5. Decrease the voltage in all three phases to 49 V rms. Verify that test pickup operates and that test trip operates in 12.4 to 13.0 seconds. GE Power Management DGP Digital Generator Protection System...
  • Page 160 The test pickup relay should operate immediately and the test trip relay should operate after the Trip Time has expired. 7. Lower the current to PICKUP – 0.1 (0.02) = ______ A rms and the test pickup and test trip relays should not operate. DGP Digital Generator Protection System GE Power Management...
  • Page 161 ______. This will cause the test pickup to operate and the test trip will operate after the Trip Time has expired. 7. Raise the positive-sequence voltage to PICKUP + 2 = ______. This will prevent the test pickup and the test trip relays from operating. GE Power Management DGP Digital Generator Protection System...
  • Page 162 If the initial settings were saved to a disk file before testing using DGP-Link, download the file to the relay. When testing is completed, verify that all settings are returned to your specified values. It is helpful to print out the settings and check them one by one. CAUTION DGP Digital Generator Protection System GE Power Management...
  • Page 163 Power down the relay by removing the test plugs or turn OFF the PS1 & PS2 switches before removing or inserting modules. Failure to do so can permanently damage the relay. CAUTION GE Power Management DGP Digital Generator Protection System...
  • Page 164 Critical, DGP will restart Digital Output Loop-back via parallel port Critical, DGP will restart Circuitry Real Time Clock Test of real time clock Operation and Non-Critical Interrupts LED display Self-test built in by manufacturer Non-critical DGP Digital Generator Protection System GE Power Management...
  • Page 165 Non-Critical DSP and DAP DSP finished flag Critical Communication Current Summation Check Critical Ground and Reference range check Critical Power Supply Range check +12V, _12V DAP, SSP Critical if no backup supply GE Power Management DGP Digital Generator Protection System...
  • Page 166 INFORMATION–STATUS command. After initial power up or loss of power exceeding 24 hours, the time and date will reset to 00:00:00 01/01/90. All event and fault data will be reset NOTE DGP Digital Generator Protection System GE Power Management...
  • Page 167 Re-apply power and the WARN message should clear. If the WARN message is gone, then the unit has been successfully repaired. If the message has changed, it is possible that another module requires replacement. GE Power Management DGP Digital Generator Protection System...
  • Page 168 CA = de-energizing the critical alarm relay. Table 6–5: MISCELLANEOUS MESSAGES MISCELLANEOUS MESSAGES DESCRIPTION INDICATION PROT OFF Protection off DIS OUTS Outputs Disabled RELAY TEST Relay in Test Mode D O TEST Digital Output test DGP Digital Generator Protection System GE Power Management...
  • Page 169 ANI:CONTROLLER ANI BOARD:CONTROLLER Critical ANI:SERIAL MEMRY ANI BOARD:SERIAL MEMORY Critical ANI:GROUND ANI BOARD:GROUND FAILURE Critical MGM1:SERIAL MEM MGM BOARD1:SERIAL MEMORY Critical MGM1:MODEL NUM MGM BOARD1:MODEL NUMBER Critical MGM2:SERIAL MEM MGM BOARD2:SERIAL MEMORY GE Power Management DGP Digital Generator Protection System...
  • Page 170 MMI BOARD:DIGITAL OUTPUT Noncrit MMI:SERIAL CHP 1 MMI BOARD:SERIAL CHIP #1 Noncrit MMI:LED DISPLAY MMI BOARD:LED DISPLAY Noncrit MMI:SERIAL CHP 2 MMI BOARD:SERIAL CHIP #2 Noncrit MMI:SERIAL CHP 3 MMI BOARD:SERIAL CHIP #3 DGP Digital Generator Protection System GE Power Management...
  • Page 171 ANI BOARD: SAMPLE CORRECTED Crit+Wdreset SSP:PROM SSP BOARD:PROM Crit+Wdreset SSP:SYSRAM CRC SSP BOARD:SYSRAM CRC Noncrit SSP:EEPROM SSP BOARD:EEPROM Noncrit SSP:TIMER SSP BOARD:TIMER Noncrit SSP:CAPRAM SSP BOARD:CAPRAM Crit+Wdreset MMI:DIG OUT MMI BOARD:DIGITAL OUTPUT GE Power Management DGP Digital Generator Protection System...
  • Page 172 POWER SUPPLY 1:(WARNING) _12V BAD Remnoncrit PS2:SELFTEST POWER SUPPLY 2:(WARNING SELFTEST) Remnoncrit PS2:+12V BAD POWER SUPPLY 2:(WARNING) +12V BAD Remnoncrit PS2:_12V BAD POWER SUPPLY 2:(WARNING) _12V BAD Noncrit DIT:DIG INP DIT BOARD:DIGITAL INPUT DGP Digital Generator Protection System GE Power Management...
  • Page 173 RS232 port – rear panel RS232 port – front panel Printer interface (serial) optional IRIG-B (demodulated) optional The printer interface and IRIB-B are optional functions. SPECIFICATONS ARE SUBJECT TO CHANGE WITHOUT NOTICE GE Power Management DLP Digital Line Protection System...
  • Page 174 Indicates an optional function. Refer to the DGP selection guide for available functions in a specific model. Timer range for Under Frequency Step 1 is 0.1 to 999.9 sec. Wider range available in DGP***ACA models; refer to Table 2–1 for detail. DLP Digital Line Protection System GE Power Management...
  • Page 175 The time-out interval is set to 10 seconds when the [END] and [ENT] keys are pressed successively; at the end of this time-out interval, the display is blanked. Time-out also causes the MMI access privilege to be set at View Level. GE Power Management DGP Digital Generator Protection System...
  • Page 176 TRIP message that is currently on the display. Figure 8–1: TARGET LEDS 8.2.2 TARGET RESET KEY The Target Reset Key is the [CLR] key on the keypad. Operation of the [CLR] key is explained in the section below. DGP Digital Generator Protection System GE Power Management...
  • Page 177 After scrolling through all of the items, the display is blanked. Both the fault data display and the present value display are stopped by a TRIP or a keypress. GE Power Management DGP Digital Generator Protection System...
  • Page 178 If entering numeric values, the [1/Y] and [3/N] keys are processed and displayed as 1 and 3. • If responding to a YES/NO prompt, the [1/Y] key is processed and displayed as YES and the [3/N] key is processed and displayed as NO. DGP Digital Generator Protection System GE Power Management...
  • Page 179 [END] [ENT] key sequence. This causes a transfer of settings from the buffer to EEPROM NOTE and re-initialization of protection. If the [END] [ENT] sequence is not performed and the DGP is allowed to time out, all of the settings in temporary storage will be lost. GE Power Management DGP Digital Generator Protection System...
  • Page 180 81-2O 81-3O 81-4O DIG. INP. VTFF 51GN NOTE: These menu items require the Setting password to make changes. * DGP****CA and DGP****BA-0005 models only 27TN * Figure 8–3: [SET] KEY MENU STRUCTURE DGP Digital Generator Protection System GE Power Management...
  • Page 181 If the user responds with YES, the action is performed, the message OUTPUTS ENABLED is dis- played, the status LED turns green, and the event LOCAL - ENABLE OUTPUTS is logged. GE Power Management DGP Digital Generator Protection System...
  • Page 182 6 digits followed by the [ENT] key. If the user presses any key other than [ENT], or the digits entered do not comprise a valid time, the old time is retained and an error message displayed. DGP Digital Generator Protection System GE Power Management...
  • Page 183 LOCAL – SETTINGS CHANGE DONE event is logged in the sequence of events. Once the Setting's CRC code has been calculated and EVERY DGP SETTING HAS BEEN EXAMINED , the [END] [ENT] key sequence is entered to resume Protection. GE Power Management DGP Digital Generator Protection System...
  • Page 184 [ENT] key. The test can also be stopped by pressing [END] [ENT] key sequence, which ends the DGP session. The available digital output tests are shown in Figure 8–4: [ACT] KEY MENU STRUCTURE on page 8–11. DGP Digital Generator Protection System GE Power Management...
  • Page 185 NOTE: The above menu items (except TIME/DATE) require an Action password to initiate the action. Resetting of the TIME/DATE requires a Setting password. Figure 8–4: [ACT] KEY MENU STRUCTURE GE Power Management DGP Digital Generator Protection System...
  • Page 186 The first item of the fault occurrence chosen is displayed as DATE: xx/xx/xx. Repeatedly pressing the [↑] key invokes the following displays: DATE: xx/xx/xx TIME: xx:xx:xx OP TIME: xx (time in ms) FAULT TYPE: xxx (examples: ABC,AB,AC) TRIP TYPE: xxx (see list below) DGP Digital Generator Protection System GE Power Management...
  • Page 187 NOTE A more detailed fault report can be obtained by using GE-Link. See Chapter 10: SOFTWARE for details. The abbreviations for the trip and trigger types are as follows:...
  • Page 188 D G P m od els w ith function 2 7TN display the third harm o nic in volts. 6. W atts and vars are a utom atica lly displayed w ith prefix K fo r kilo and M for m ega as necessary. Figure 8–5: [INF] KEY MENU STRUCTURE DGP Digital Generator Protection System GE Power Management...
  • Page 189 MMI KEY ERROR: MMI received an invalid key code from keyboard. (Hardware error) ACT INVALID NOW: The current action that the user is attempting to perform is invalid because the setting's CRC code is in error. GE Power Management DGP Digital Generator Protection System...
  • Page 190 The communications passwords can only be viewed using the [INF] key and the MMI passwords can only be viewed from the Information menu in GE-Link. All passwords are displayed in encoded form. Use the follow- ing encryption table to decode the passwords.
  • Page 191 8 INTERFACE 8.5 PASSWORDS 8.5.2 ENCRYPTED PASSWORD CONVERSION TABLE Table 8–2: PASSWORD ENCRYPTION KEY TABLE Displayed Decoded Displayed Decoded Displayed Decoded (space) (space) " < & > " & GE Power Management DGP Digital Generator Protection System...
  • Page 192 8.5 PASSWORDS 8 INTERFACE DGP Digital Generator Protection System GE Power Management...
  • Page 193 The PC modem must be configured for intelligent operation (that is, command recognition enabled). The default settings listed above are valid for GE-Link. Those configuration settings critical to the operation of GE- Link are changed by the software. The configuration commands sent to the modem from GE-Link are:...
  • Page 194 A GE-Link setting establishes the baud rate, which must match the DGP baud rate setting. GE-Link then sets the specified PC serial port (i.e., COM1, COM2) to the proper baud rate, parity, data bits, and stop bits. If the PC modem is capable of operating at more than one baud rate, then it must be able to automatically configure its baud rate, character length, and parity setting by examining the AT command prefix.
  • Page 195 MALE / FEMALE TO RELAY MMI MODULE COMM D) REMOTE COMMUNICATIONS FROM MMI MODULE TO PC CABLES AVAILABLE AS GE PART NO. 0246A9866. SPECIFY CABLE TYPE AND CONNECTOR GENDER. Figure 9–1: DGP COMMUNICATIONS WIRING GE Power Management DGP Digital Generator Protection System...
  • Page 196 For computers without RS485 capability, a “master” SCI box is required as shown in the figure below. The SCI boxes are available from GE Power Management as catalog number S14200 X , where X specifies the voltage input. Please consult the SCI documentation for additional configuration informa- tion.
  • Page 197 0 is reserved for broadcast transmissions by the master as specified by the Modbus protocol. The DGP does not support the broadcast transmissions. The DGP will respond only if the slave address specified by the mas- ter request matches its Unit ID; otherwise the DGP relay will not respond. GE Power Management DGP Digital Generator Protection System...
  • Page 198 CRC field. If they are not equal an error message results. The CRC is calculated by first pre-loading a 16-bit register to all 1’s (in GE relays, all registers are pre-loaded with zeros). Then using a CRC polynomial specified by the CCITT, the CRC is computed (0xA001).
  • Page 199 Number of registers to read. Data 1 High Byte first then Low byte ..Data n High Byte first then Low byte CRC calculated by slave. High byte first, Low byte next GE Power Management DGP Digital Generator Protection System...
  • Page 200 05 Execute a coil command Coil Address Address of the command that has been executed Value FF00 Same as the master query CRC Calculated by Slave High byte first. Low byte next DGP Digital Generator Protection System GE Power Management...
  • Page 201 Address of the register that has been set to the value specified by the Master Value Same as the value specified by the master query. CRC Calculated by Slave High byte first. Low byte next GE Power Management DGP Digital Generator Protection System...
  • Page 202 9.3.5 FUNCTION CODE 56: RETRANSMIT LAST PACKET a) DESCRIPTION This function is not supported by the Modbus protocol as it is a GE specific enhancement. When this command is issued, the last response from the slave is simply repeated. b) QUERY Example of a query message.
  • Page 203 Exception Code CRC Calculated by Slave High byte first. Low byte next The DGP will implement the following exception response codes. 01: Illegal function 02: Illegal Data Value 03: Illegal Data Address GE Power Management DGP Digital Generator Protection System...
  • Page 204 8 is the event code (see DGP event code list below). If the requested event contains no data, then all 8 registers contain a value of 0. 12. SP: Special processing needed. Most of the registers are bit fields.. DGP Digital Generator Protection System GE Power Management...
  • Page 205 9.5.2 MEMORY MAP ORGANIZATION The register maps have been designed by function basis as for GE-Modem to facilitate ease of design. For example, the Set Date and Time function is implemented by writing to certain setpoint registers even though it is not a part of the actual settings group.
  • Page 206 The TRIP TYPE field is a 16-bit binary value representing the function that has tripped due to the fault. The bit assignments are as follows: bit 0 - 94G bit 1 - 94G1 bit 2 - 94G2 bit 3 - 94G3 bits 4 to 15 - reserved and presently set to zero DGP Digital Generator Protection System GE Power Management...
  • Page 207 17FFH. If the number is not valid the DGP slave responds with ILLEGAL DATA VALUE exception. GE Power Management DGP Digital Generator Protection System...
  • Page 208 7. Write the Cycle Num into register 17FEH. 8. Read the oscillography data from registers 1600H to 16FBH. 9. Increment the Cycle Num and go to step 6. 10. Finished reading Oscillography. DGP Digital Generator Protection System GE Power Management...
  • Page 209 38 FAIL - PS1 BOARD: +12 VOLTAGE FAILED 79 51V PHASE B ON 39 FAIL - PS1 BOARD: -12 VOLTAGE FAILED 80 51V PHASE C ON 40 FAIL - PS2 BOARD: LOGIC VOLTAGE FAILED 81 51V PHASE A OFF GE Power Management DGP Digital Generator Protection System...
  • Page 210 DIGITAL INPUT 6 OPEN 81-3U ON ACCIDENTAL ENGERGIZATION ON 81-3U OFF ACCIDENTAL ENGERGIZATION OFF 81-4U ON 27TN ON 81-4U OFF 27TN OFF 51GN ON " " 51GN OFF " " 27 ON " " DGP Digital Generator Protection System GE Power Management...
  • Page 211 DSP1 BOARD: FAILURE CLEARED PS BOARD: +12V FAILURE CLEARED DSP2 BOARD: FAILURE CLEARED PS BOARD: -12V FAILURE CLEARED DSP3 BOARD: FAILURE CLEARED ANI BOARD: CURRENT SUM FAILURE CLEARED SSP BOARD: FAILURE CLEARED GE Power Management DGP Digital Generator Protection System...
  • Page 212 22 = VTFF bit 8 = SSP CAPRAM Failure 23 = OSC bit 9 = SSP Real Time Clock Failure 24 = DI-3 bit 10 = Version Number Mismatch 25 = DI-4 DGP Digital Generator Protection System GE Power Management...
  • Page 213 0 = POWER SUPPLY 1: PWR1STAT: +12 V Warning bit 6-9 = Spare bit 1 = POWER SUPPLY 2: bit 10 = DSP2 Version Number Failure +12 V Warning bit 11-14 = Spare GE Power Management DGP Digital Generator Protection System...
  • Page 214 11 = 94G-A Trip Continuity Error bit 12 = 94G-B Trip Continuity Error bit 13 = 94G-C Trip Continuity Error bit 14 = 94G-D Trip Continuity Error bit 15 = Spare DGP Digital Generator Protection System GE Power Management...
  • Page 215 PRFLG1 assignment is same as pickup flags group 1. bit 10 51V-B 1613h: Protection function trip flags group 2. Bit PRFLG2 assignment is same as pickup flags group 2. bit 11 51V-C GE Power Management DGP Digital Generator Protection System...
  • Page 216 The master can change the date and time by writing into the registers starting at address 7F00H and by using the function code 10H. All these registers are write-only registers. The individual registers cannto be pro- grammed, either the date or time or both may be changed. DGP Digital Generator Protection System GE Power Management...
  • Page 217 INTO 1060 Third Harmonic PH VOLT INT1 1061 Third Harmonic N VOLT INT1 1062 Watts WATT LONG1 1064 VARS LONG1 1066 Gen OFFLINE BOOLEAN 1067 FUEL VALVE BOOLEAN 1068 BOOLEAN 1069 BOOLEAN GE Power Management DGP Digital Generator Protection System...
  • Page 218 Event 18 2193 Event 19 2201 Event 20 2209 Event 21 2217 Event 22 2225 Event 23 2233 Event 24 2241 Event 25 2249 Event 26 2257 Event 27 2265 Event 28 DGP Digital Generator Protection System GE Power Management...
  • Page 219 Event 52 2465 Event 53 2473 Event 54 2481 Event 55 2489 Event 56 2497 Event 57 2505 Event 58 2513 Event 59 2521 Event 60 2529 Event 61 2537 Event 62 GE Power Management DGP Digital Generator Protection System...
  • Page 220 Event 86 2737 Event 87 2745 Event 88 2753 Event 89 2761 Event 90 2769 Event 91 2777 Event 92 2785 Event 93 2793 Event 94 2801 Event 95 2809 Event 96 DGP Digital Generator Protection System GE Power Management...
  • Page 221 101F Fault VB VOLT LONG1 4129 1021 Fault VC VOLT LONG1 4131 1023 Fault VN VOLT LONG1 4133 1025 Fault IAS LONG2 4135 1027 Fault IBS LONG2 4137 1029 Fault ICS LONG2 GE Power Management DGP Digital Generator Protection System...
  • Page 222 LONG2 4376 1118 Prefault Watts F2 WATT LONG1 4378 111A Prefault Vars F2 LONG1 4380 111C Prefault SysFreq F2 INT2 4381 111D Fault VA VOLT LONG1 4383 111F Fault VB VOLT LONG1 DGP Digital Generator Protection System GE Power Management...
  • Page 223 4622 120E Prefault VB F3 VOLT LONG1 4624 1210 Prefault VC F3 VOLT LONG1 4626 1212 Prefault IAS F3 LONG2 4628 1214 Prefault IBS F3 LONG2 4630 1216 Prefault ICS F3 LONG2 GE Power Management DGP Digital Generator Protection System...
  • Page 224 4749 128D SOE12 F3 4757 1295 SOE13 F3 4765 129D SOE14 F3 OSCILLOGRAPHY SETTINGS 5120 1400 Unit ID INTO 5121 1401 SYS FREQ INTO 5122 1402 SEL TVM 5123 1403 SEL TCM DGP Digital Generator Protection System GE Power Management...
  • Page 225 141F 40-1 RADIUS INT2 5152 1420 40-1 TL12 INT2 5153 1421 40-2 TRIP 5154 1422 40-2 ALARM 5155 1423 40-2 CENTER INT2 5156 1424 40-2 RADIUS INT2 5157 1425 40-2 TL13 INT2 GE Power Management DGP Digital Generator Protection System...
  • Page 226 24T INV PU PER UNIT INT2 5187 1443 24T TIME FAC INT2 5188 1444 24T INST PU PER UNIT INT2 5189 1445 24T TL7 INT1 5190 1446 24T RESET INTO 5191 1447 59 TRIP DGP Digital Generator Protection System GE Power Management...
  • Page 227 INT2 5219 1463 81-2U TL9 INT2 5220 1464 81-3U TRIP 5221 1465 81-3U ALARM 5222 1466 81-3U SETPNT INT2 5223 1467 81-3U TL10 INT2 5224 1468 81-4U TRIP 5225 1469 81-4U ALARM GE Power Management DGP Digital Generator Protection System...
  • Page 228 IAS SAMP1 INT2 5633 1601 IBS SAMP1 INT2 5634 1602 ICS SAMP1 INT2 5635 1603 INS SAMP1 INT2 5636 1604 IAR AMP1 INT2 5637 1605 IBR SAMP1 INT2 5638 1606 ICR SAMP1 INT2 DGP Digital Generator Protection System GE Power Management...
  • Page 229 5665 1621 DI SAMP2 5666 1622 PUFLG0 SAMP2 5667 1623 PUFLG1 SAMP2 5668 1624 PUFLG2 SAMP2 5669 1625 PUFLG2 SAMP2 5670 1626 PRFLG0 SAMP2 5671 1627 PRFLG1 SAMP2 5672 1628 PRFLG2 SAMP2 GE Power Management DGP Digital Generator Protection System...
  • Page 230 ICR SAMP4 INT2 5702 1646 INR SAMP4 INT2 5703 1647 VA SAMP4 VOLT INT1 5704 1648 VB SAMP4 VOLT INT1 5705 1649 VC SAMP4 VOLT INT1 5706 164A VN SAMP4 VOLT INT1 DGP Digital Generator Protection System GE Power Management...
  • Page 231 5734 1666 PRFLG1 SAMP5 5735 1667 PRFLG2 SAMP5 5736 1668 SAMPPD SAMP5 5737 1669 IAS SAMP6 INT2 5738 166A IBS SAMP6 INT2 5739 166B ICS SAMP6 INT2 5740 166C INS SAMP6 INT2 GE Power Management DGP Digital Generator Protection System...
  • Page 232 5768 1688 VC SAMP7 VOLT INT1 5769 1689 VN SAMP7 VOLT INT1 5770 168A DI SAMP7 5771 168B DO SAMP7 5772 168C PUFLG0 SAMP7 5773 168D PUFLG1 SAMP7 5774 168E PUFLG2 SAMP7 DGP Digital Generator Protection System GE Power Management...
  • Page 233 INT2 5803 16AB INS SAMP9 INT2 5804 16AC IAR AMP9 INT2 5805 16AD IBR SAMP9 INT2 5806 16AE ICR SAMP9 INT2 5807 16AF INR SAMP9 INT2 5808 16B0 VA SAMP9 VOLT INT1 GE Power Management DGP Digital Generator Protection System...
  • Page 234 16CB PUFLG0 SAMP10 5836 16CC PUFLG1 SAMP11 5837 16CD PUFLG2 SAMP10 5838 16CE PRFLG0 SAMP10 5839 16CF PRFLG1 SAMP10 5840 16D0 PRFLG2 SAMP10 5841 16D1 SAMPPD SAMP10 5842 16D2 IAS SAMP11 INT2 DGP Digital Generator Protection System GE Power Management...
  • Page 235 5871 16EF VA SAMP12 VOLT INT1 5872 16F0 VB SAMP12 VOLT INT1 5873 16F1 VC SAMP12 VOLT INT1 5874 16F2 VN SAMP12 VOLT INT1 5875 16F3 DI SAMP12 5876 16F4 DO SAMP12 GE Power Management DGP Digital Generator Protection System...
  • Page 236 1C10 SETT PSW ASCII SETTINGS 16384 4000 Unit ID INTO 16385 4001 SYS FREQ INTO 16386 4002 SEL TVM 16387 4003 SEL TCM 16388 4004 SELPRIM BOOLEAN 16389 4005 CT RATIO INTO DGP Digital Generator Protection System GE Power Management...
  • Page 237 17668 4504 40-1 TL12 INT2 17920 4600 40-2 TRIP 17921 4601 40-2 ALARM 17922 4601 40-2 CENTER INT2 17923 4602 40-2 RADIUS INT2 17924 4603 40-2 TL13 INT2 18176 4700 32-1 TRIP GE Power Management DGP Digital Generator Protection System...
  • Page 238 4D06 24T INST PU PER UNIT INT2 19719 4D07 24T TL7 INT1 19720 4D08 24T RESET INTO 19968 4E00 59 TRIP 19969 4E01 59 ALARM 19970 4E02 59 INV PU VOLT INTO DGP Digital Generator Protection System GE Power Management...
  • Page 239 INT2 21763 5503 81-2O TL16 INT2 22016 5600 81-3O TRIP 22017 5601 81-3O ALARM 22018 5602 81-3O SETPNT INT2 22019 5603 81-3O TL17 INT2 22272 5700 81-4O TRIP 22273 5701 81-4O ALARM GE Power Management DGP Digital Generator Protection System...
  • Page 240 INT1 23811 5D03 27TN TL20 INT1 23812 5D04 27TN FORPWR_L WATT INTO 23813 5D05 27TN FORPWR_H WATT INTO GENERATOR AND STATION ID 32256 7E00 STATION ID ASCII 32288 7E20 GENERATOR ID ASCII DGP Digital Generator Protection System GE Power Management...
  • Page 241 RELAY TEST 81-1U TRIB BRKR 94G2 RELAY TEST 81-2U TRIB BRKR 94G3 RELAY TEST 81-3U RELAY TEST 81-4U * END COMMAND must be sent after new settings are sent to the DGP. GE Power Management DGP Digital Generator Protection System...
  • Page 242 9.7 FACTORY SETTINGS (GE FACTORY TESTS ONLY) 9 COMMUNICATIONS 9.7 FACTORY SETTINGS (GE FACTORY TESTS ONLY) 9.7.1 DESCRIPTION Normally the user can change the settings only if the settings that are in the relay are not corrupted. In a brand new relay the contents of the EEPROM are undefined.
  • Page 243 PKZip software for GE-Link file extraction. 10.1.3 INSTALLATION 1. Insert the GE Power Management Products CD into your local CD-ROM drive or point your web browser to the GE Power Management website at www.GEindustrial.com/pm. Under Windows 95/98, the Products CD will automatically launch the welcome screen. Since the Products CD is essentially a “snapshot” of the GE Power Management website, the installation procedures from the CD and the web are identical.
  • Page 244 Installing J1 disables remote closing of all of the output relays. Installing J2 disables all remote setting changes and the disable/enable of outputs (see Figure 3–4: DGP MMI MODULE on page 3–5). 10.2.2 GE-LINK USER INTERFACE All user actions are classified into these categories.
  • Page 245 10 GE-LINK SOFTWARE 10.2 GENERAL OPERATION 10.2.4 DELETING A SITE (LOCATION) To delete a site: 1. Delete all IEDs associated with that site. 2. Select the Site and click the Delete button or the Delete menu icon (shown in the diagram below).
  • Page 246 2. Enter the telephone number in the prompted dialog box and click OK. 3. GE-Link will try to make the telephone connection with the remote modem. If the modem connection is successful, click the Connect to Relay menu icon or select the Communication > Connect Relay menu item.
  • Page 247 10 GE-LINK SOFTWARE 10.3 IED CONNECTION 10.3.3 IED MODES A mode is the current state of the IED. The mode indicates whether the IED is connected or not, and if con- nected, the access level of the connection. Th e m od e of the sele cted IED w ill be displaye d o n the right bo ttom corne r of the sta tus bar pane.
  • Page 248 10.3.5 RETREIVING INFORMATION 1. When connected to an IED, GE-Link retreives Settings and non-settings information. 2. Click on a specific category in the Tree directly after the connection is established . GE-Link retrieves the data from the IED. 3. Subsequent access to a specific setting only shows the information last retreived. To view the most updated Settings information, click the Settings category then the Refresh icon (or select the Edit >...
  • Page 249 10 GE-LINK SOFTWARE 10.3 IED CONNECTION To retreive data for a category, first select the cate gory from the tre e, (sho w n at left) then click on the R e fre sh button (sho w n ab ove).
  • Page 250 2. The user can select an IED, edit the default settings, then save it to local file. To save the settings to a file select the File > Save Settings To File menu item or click the Save icon. 3. This action can be performed before connecting to an IED or while GE-Link is in the EDIT MODE (see SETTINGS MODE below).
  • Page 251 1. To select Manual Trip, click Manual Trip in the Operations branch. 2. GE-Link responds with a selection box showing the four output relays. Select the desired relay and click 3. The relay operates and GE-Link returns to the Manual Trip item menu.
  • Page 252 This menu item displays the station and generator ID for the relay. The IDs can be up to 32 characters long and must be all printable characters. 1. Select the Change Station/Generator ID item from the Operations branch. 2. GE-Link responds with an edit box. Enter the new station and generator ID. 3. Click OK to accept changes. 10.5.8 RELAY TEST This item allows the user to test the relay functions.
  • Page 253 10 GE-LINK SOFTWARE 10.6 GETTING INFORMATION 10.6 GETTING INFORMATION 10.6.1 DESCRIPTION All Information data values are read only once upon entry to the respected Information Item. If the user exits from any item and then re-enters, the refresh button must be activated to update the most recent data values.
  • Page 254 10.6.6 OSCILLOGRAPHY DATA For applicable models, this item allows oscillography data for a particular fault to be saved on disk. Select the Oscillography Data item from the Information branch and follow the GE-Link prompts. 10.6.7 DGP STATUS This item allows the user to display, print, or copy the DGP status.
  • Page 255 1–11: ELEMENTARY DIAGRAM WITHOUT TEST BLOCKS, WYE VT ............. 1-25 IGURE 1–12: ELEMENTARY DIAGRAM WITHOUT TEST BLOCKS, DELTA VT ..........1-26 IGURE 1–13: DIGITAL RELAY SYMBOL LEGEND....................1-27 IGURE 2–1: SAMPLE GENERATOR SYSTEM ......................2-2 IGURE GE Power Management DGP Digital Generator Protection System...
  • Page 256 3–3: DGP POWER SUPPLY MODULE......................3-4 IGURE 3–4: DGP MMI MODULE ..........................3-5 IGURE 4–1: ADDING A NEW IED..........................4-6 IGURE 4–2: GE-LINK SETTINGS MENU........................4-7 IGURE 4–3: DIGITAL OUTPUT TEST CONNECTIONS ................... 4-12 IGURE 4–4: DIGITAL INPUT TEST CONNECTIONS ....................4-14 IGURE 4–5: AC SYSTEM INPUT TEST CONNECTIONS ..................
  • Page 257 Delta connected VTs” 2-41 Added separate DGP Settings Tables for DGP***AAA, DGP***ABA, and DGP***ACA 4-23 Added the following step in the T10 procedure of Section 4.7.7: “5. Reduce Ia to 0 A” GE Power Management DGP Digital Generator Protection System...
  • Page 258 Section 9-2: MODBUS COMMUNICATIONS Chapter 10: GE-LINK SOFTWARE Appendix A: TABLES AND FIGURES Appendix B: CHANGE NOTES Appendix C: DGP WARRANTY Added an Index Reference to GE Power Management Website on back page DGP Digital Generator Protection System GE Power Management...
  • Page 259 In Section 4.7.24, “(2601) VTFF = DISABLE (0) – set for “(2601) VTFF = ENABLE (1)” TEST mode only” Modified “RMS measurements: ±3%” RMS measurements: ±3% of reading” Corrected In Section 9.1.3, “ATEL0L3Q0S7=60V0X4Y0” “ATEL0L0Q0S7=60V0X4Y0” GE Power Management DGP Digital Generator Protection System...
  • Page 260 B.1 CHANGE NOTES APPENDIX B DGP Digital Generator Protection System GE Power Management...
  • Page 261 Figure 3-2, 3-3, and 3-4 Replaced all with Figure 3-2 Updated Using DGP-Link section Using GE-Link Section Updated all instances of “GE Multilin” “GE Power Management” Updated all references to “DGP-Link” “GE-Link” GE Power Management DGP Digital Generator Protection System...
  • Page 262 B.1 CHANGE NOTES APPENDIX B DGP Digital Generator Protection System GE Power Management...
  • Page 263 DIT 103 DIT 101 DIT 102 4. I have an older version of DGPxxxAAA firmware. What upgrade kit do I order to upgrade my DGPxxxAAA to the latest firmware revision? Use kit 0355A3489G0001. GE Power Management DGP Digital Generator Protection System...
  • Page 264 11. Why can't I change settings with the GE-Link software? In order to download settings using GE-Link, the remote settings change jumper must be enabled. This is accomplished by moving the shorting pin on J2 on the right of the MMI301 module to one side as shown in the...
  • Page 265 The DGP requires a special null-modem cable to communicate directly with a laptop PC (see connection dia- gram below). The cables are available from GE Power Management as part number 0246A9866. Please spec- ify the cable type and connector gender when ordering.
  • Page 266 19. Where is the figure showing Curve 4 of the 24T function in the DGP manual? Curve 4 is a definite time delay equal to the corresponding TIME FACTOR setting. Therefore, no figure is nec- essary. The same applies to Curve 2 of functions 59 and 27. DGP Digital Generator Protection System GE Power Management...
  • Page 267 Warranty shall not apply to any relay which has been subject to mis- use, negligence, accident, incorrect installation or use not in accor- dance with instructions nor any unit that has been altered outside a GE Power Management authorized factory outlet.
  • Page 268 D.1 DGP WARRANTY APPENDIX D DGP Digital Generator Protection System GE Power Management...
  • Page 269 ............. 4-37 initial test setup ............4-8 algorithm ..............2-38 preparation ............... 4-2 description ..............1-9 protection tests ..........4-1, 4-17 logic diagram ............1-14 setting up a new test unit ........... 4-5 GE Power Management DGP Digital Generator Protection System...
  • Page 270 DEC1000 CONTACT EXPANSION UNIT ...... 1-18 COMMISSIONING ............2-41 DEFECTIVE MODULES COMMPORT ..............2-11 locating ..............6-5 COMMUNICATION DEVICE NUMBER modem connection for GE-Link .........10-4 see ANSI device numbers listed numerically at beginning COMMUNICATIONS of index baud rate ..............2-11 DI1 to DI6 data frame format ............9-5 see entry for DIGITAL INPUTS data packet format ............
  • Page 271 INDEX acceptance tests ............. 4-11 FREQUENCY-SENSITIVITY CHARACTERISTICS ..1-20 periodic tests ............. 5-3 FREQUENTLY ASKED QUESTIONS ......C-1 test with GE-Link ............ 10-10 FRONT VIEW .............. 3-3 testing ..............8-10 DIGITAL RESET ............10-10 DISPLAY ..............8-1 periodic testing ............5-2 DISPLAY TEST ............
  • Page 272 ............5-8 NOMINAL VOLTAGE ..........2-12 settings ..............2-20 NON-CRITICAL FAILURES ...........6-5 LOSS OF FIELD PROTECTION NULL-MODEM ............. 1-22, 9-2 acceptance tests ..........4-22, 4-23 NUM FLTS ............1-21, 2-11 see entry for MMI DGP Digital Generator Protection System GE Power Management...
  • Page 273 ................2-13 memory map ............9-13 OUTPUTS primary/secondary units setting .........2-10 disabling ............8-7, 10-9 requesting ..............8-13 enabling ............8-7, 10-9 viewing with GE-Link ..........10-11 OVERCURRENT PRINT KEY ..............8-4 acceptance tests ............. 4-24 PRINTER ..............1-21 algorithm ..............2-22 PROTECTION FEATURES ........... 1-6 logic diagram ............
  • Page 274 TRIP CIRCUIT MONITOR ........... 1-19 SINGLE LINE DIAGRAM ..........1-6 TRIP CURRENT MONITOR ......... 2-10 SOFTWARE TRIP RELAY .............. 2-13 see GE-LINK and Chapter 10 TRIP VOLTAGE MONITOR ......... 1-19 SPARES ..............6-1 TRIP VOLTAGE MONITORING ........2-10 SPECIFICATIONS ............7-1 TROUBLESHOOTING ...........6-4...
  • Page 275 INDEX settings ..............2-37 WARN ................. 6-5 WARRANTY ..............D-1 WIRING DIAGRAM ............1-5 XTM TEST PLUGS circuit connection ............3-6 description ..............3-6 insertion ..............3-6 GE Power Management DGP Digital Generator Protection System...
  • Page 276 INDEX DGP Digital Generator Protection System GE Power Management viii...
  • Page 277 NOTES GE Power Management DGP Digital Generator Protection System...
  • Page 278 GE POWER MANAGEMENT WEBSITE The latest product information for the DGP relay is available on the Internet via the GE Power Management home page: http://www.GEindustrial.com/pm This site provides access to the following customer services: • Digital Products Directory • Instruction Manuals A brief description of products can be viewed online.

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