SEL700G PART2.pdf - Section 5 Metering and Monitoring Instruction Manual Overview The SEL-700G Relay includes metering functions to display the present

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Unformatted text preview: Section 5 Metering and Monitoring Instruction Manual Overview The SEL-700G Relay includes metering functions to display the present values of current, voltage (if included), analog inputs (if included), field insulation resistance (with external SEL-2664 Field Ground Module), and RTD measurements (with the external SEL-2600 RTD Module or an internal RTD card). The relay provides the following methods to read the present meter values: ➤ Front-panel rotating display ➤ Front-panel menu ➤ EIA-232 serial ports (using SEL ASCII text commands or ACSELERATOR QuickSet® SEL-5030 Software) ➤ Telnet via Ethernet port ➤ Modbus® via EIA-485 port or EIA-232 port ➤ Modbus TCP via Ethernet port ➤ DNP3 Serial via EIA-232 port or EIA-485 port ➤ DNP3 LAN/WAN via Ethernet port ➤ DeviceNet port ➤ Analog outputs ➤ IEC 61850 via Ethernet port ➤ C37.118 Synchrophasor Protocol via serial port Load monitoring and trending are possible through use of the Load Profile function. The relay automatically configures itself to save as many as 17 quantities (selected from the Analog Quantities) every 5, 10, 15, 30, or 60 minutes. The data are stored in nonvolatile memory. As many as 9800 time samples are stored. The Breaker Monitor feature is available in all SEL-700G relays. Refer to Breaker Monitor on page 5.15 for description and application details. Date Code 20150521 Instruction Manual SEL-700G Relay 5.2 Metering and Monitoring Power Measurement Conventions Power Measurement Conventions The SEL-700G uses the IEEE convention for power measurement. The implications of this convention are depicted in Figure 5.1. Source Bus I lags V W=— VAR = + PF = LEAD Direction of Positive Real Power Q+ (VAR) I lags V W=+ VAR = + PF = LAG Generator P+ (W) SEL-700G Relay Figure 5.1 I leads V W=— VAR = — PF = LAG I leads V W=+ VAR = — PF = LEAD Complex Power Measurement Conventions Delta-Connected CTs The relay displays currents, voltages, and power in primary values as part of most metering and monitoring reports. If the winding phase CTs are wye connected, the relay can accurately derive the primary currents from the secondary values through multiplying them by the corresponding CT ratio. Delta-connected CTs, in general, remove zero-sequence current and introduce a phase shift. They also increase magnitude by 3 under balanced system conditions and as high as two times under unbalanced conditions. As a result, the relay cannot derive the primary currents/quantities accurately. The relay performs the following under all system conditions in the case of deltaconnected CTs. The primary currents displayed are derived from the secondary values through multiplying them by the corresponding CT ratio and dividing them by 3 . The phase angles are not compensated and reflect the same values as measured on the secondary. Metering The SEL-700G meter data fall into the following categories: SEL-700G Relay ➤ Fundamental metering ➤ Thermal metering: RTD metering (with the external SEL-2600 RTD Module or an internal RTD option) and generator thermal capacity ➤ Energy metering ➤ Maximum and minimum metering ➤ Math variable metering ➤ RMS metering ➤ Analog transducer input metering Instruction Manual Date Code 20150521 Metering and Monitoring Metering Fundamental Metering ➤ Demand and peak demand metering ➤ Synchrophasor metering ➤ Differential metering ➤ Harmonic metering (differential) Table 5.1 details each of the fundamental meter data types in the SEL-700G. Section 8: Front-Panel Operations and Section 7: Communications describe how to access the various types of meter data by using the relay front panel and communications ports. NOTE: Phase-to-phase voltages for wye- NOTE: If the winding phase CTs are delta connected PTs are available in Appendix K: Analog Quantities and can be displayed on the front panel. connected, the primary currents displayed are derived from the secondary values by multiplying them with CTR (CT ratio) and dividing them by the square root of 3. The phase angles shown are the same as the secondary values. If the CT connection type is known (DAB or DAC), the phase angles could be corrected by the user. Table 5.1 5.3 The MET response is meant to show steady-state primary values. During unbalanced conditions it is not possible to reproduce the primary line currents accurately because the delta-connected CTs filter out the zero-sequence component of the line current. Wye connected CTs do not have any such issue. Measured Fundamental Meter Values (Sheet 1 of 2) Relay Option X-Side Quantities (model dependent) Fundamental Meter Values ➤ Input currents IAX, IBX, and ICX magnitudes (A primary) and phase angles (degrees) ➤ Calculated currents IGX (IGX = 3I0 = IAX + IBX + ICX), positive-sequence current I1X, and negative-sequence current 3I2X magnitudes (A primary) and phase angles (degrees) ➤ Wye-connected input voltages (with respect to neutral): ➢ VAX, VBX, and VCX magnitudes (V primary) and phase angles (degrees) ➢ Calculated voltages VGX (VGX = 3V0 = VAX + VBX + VCX), positive-sequence voltage V1X and negative-sequence voltage 3V2X magnitudes (V primary) and phase angles (degrees) ➤ Delta-connected input voltages: ➢ VABX, VBCX, and VCAX magnitudes (V primary) and phase angles (degrees) ➢ Calculated positive-sequence voltage V1X and negative-sequence voltage 3V2X magnitudes (V primary) and phase angles (degrees) ➤ Power and Power Factor (single phase quantities for wye-connected PTs only): ➢ Single-phase (PAX, PBX, PCX) and three-phase (P3X) real power (kW) ➢ Single-phase (QAX, QBX, QCX) and three-phase (Q3X) reactive power (kVAR) ➢ Single-phase (SAX, SBX, SCX) and three-phase (S3X) apparent power (kVA) ➢ Single-phase (PFAX, PFBX, PFCX) and three-phase (PF3X) power factor (lead/lag) ➤ Frequency (FREQX) in Hz. ➤ Volts/Hertz in %. Y-Side Quantities (model dependent) Input currents IAY, IBY, and ICY magnitudes (A primary) and phase angles (degrees) Calculated currents IGY (IGY = 3I0 = IAY + IBY + ICY), positive-sequence current I1Y, and negativesequence current 3I2Y magnitudes (A primary) and phase angles (degrees) Wye-connected input voltages (with respect to neutral): ➢ VAY, VBY, and VCY magnitudes (V primary) and phase angles (degrees) ➢ Calculated voltages VGY (VGY = 3V0 = VAY + VBY + VCY), positive-sequence voltage V1Y and negative-sequence voltage 3V2Y magnitudes (V primary) and phase angles (degrees) ➤ Delta-connected input voltages: ➢ VABY, VBCY, and VCAY magnitudes (V primary) and phase angles (degrees) ➢ Calculated positive-sequence voltage V1Y and negative-sequence voltage 3V2Y magnitudes (V primary) and phase angles (degrees) Date Code 20150521 Instruction Manual SEL-700G Relay 5.4 Metering and Monitoring Metering Table 5.1 Measured Fundamental Meter Values (Sheet 2 of 2) Relay Option Fundamental Meter Values ➤ Power and Power Factor (single phase quantities for WYE connected PTs only): ➢ Single-phase (PAY, PBY, PCY) and three-phase (P3Y) real power (kW) ➢ Single-phase (QAY, QBY, QCY) and three-phase (Q3Y) reactive power (kVAR) ➢ Single-phase (SAY, SBY, SCY) and three-phase (S3Y) apparent power (kVA) ➢ Single-phase (PFAY, PFBY, PFCY) and three-phase (PF3Y) power factor (lead/lag) ➤ Frequency (FREQY) in Hz. Other Quantities (model dependent) ➤ Synchronism-check voltage input (VS) magnitude (V primary) and phase angle (degrees) and frequency (FREQS) in Hz ➤ Neutral voltage input (VN) magnitude (V primary) and phase angle (degrees) ➤ Third harmonic voltages for stator ground element 64G (Wye-connected X-side PTS only): Third harmonic voltages VPX3 (VPX3 = VAX3 + VBX3 + VCX3) and VN3 (V primary); Field ground insulation resistance Rf in kilohmsa (requires SEL-2664 Field Ground Module) a Field ground insulation resistance, Rf, will read FAIL when E64F = Y and the data are invalid. All angles are displayed between –180 and +180 degrees. The angles are referenced to VABn, VANn (for delta- or wye-connected PT, respectively), or IAn (n = X or Y). If the voltage channels are not supported, if VABn < 13 V (for delta-connected PT), or if VANn < 13 V (for wye-connected PT), the angles are referenced to IAn current. If the relay includes both X and Y-side quantities, the angles are referenced to the X-side quantity. Figure 5.2 shows an example of the METER command report. =>MET <Enter> SEL-700G GENERATOR RELAY Date: 02/24/2010 Time: 11:43:44.875 Time Source: Internal Mag (A pri.) Angle (deg) IAX 505.1 -30.0 IBX 501.2 -149.9 ICX 499.4 89.9 IGX 6.9 -44.8 I1X 501.9 -30.0 3I2X 3.2 -4.0 Mag (A pri.) Angle (deg) IAY 500.7 150.0 IBY 502.5 30.6 ICY 500.1 -89.1 IGY 9.2 40.7 I1Y 501.1 150.5 3I2Y 4.9 83.8 Mag (A pri.) Angle (deg) IN 0.0 143.8 Mag (V pri.) Angle (deg) VAX 9978.0 0.0 VBX 9982.1 -120.3 VCX 9986.7 120.0 VGX 53.6 151.5 V1X 9982.2 -0.1 3V2X 38.6 27.1 Mag (V pri.) Angle (deg) VS 0.0 -102.7 VN 0.00 16.9 Mag (V pri.) VN3 0.66 VPX3 3.94 AX 4362 2523 5040 0.87 LAG Real Pwr (kW) Reactive Pwr (kVAR) Apparent Pwr (kVA) Pwr Factor Frequency (Hz) FREQX 60.00 BX 4348 2474 5003 0.87 LAG CX 4312 2505 4987 0.87 LAG 3PX 13023 7503 15029 0.87 LAG FREQS 60.00 V/Hz (%) Field Resistance (kOhm) 100.5 19276.6 => Figure 5.2 METER Command Report for SEL-700G1 With Synchronism Check and Neutral Voltage Inputs SEL-700G Relay Instruction Manual Date Code 20150521 Metering and Monitoring Metering Thermal Metering 5.5 The thermal metering function reports the RTD meter values (see Table 5.2 for details) and also reports the state of connected RTDs, if any have failed (see Table 5.3 for details). The report also displays % generator thermal capacity used and % RTD-based thermal capacity used quantities for selected models with thermal model element. Table 5.2 Thermal Meter Values Relay Option Thermal Values With External SEL-2600 RTD Module or Internal RTD Option All RTD Temperatures Models With Thermal Model Element Enabled % Generator Thermal Capacity Used % RTD-based Thermal Capacity Used Table 5.3 RTD Input Status Messages Message Status Open RTD leads open Short RTD leads shorted Comm Fail Fiber-optic communications to SEL-2600 RTD Module have failed Stat Fail SEL-2600 RTD Module self-test status failure Figure 5.3 provides an example of the METER T command report. =>MET T <Enter> SEL-700G GENERATOR RELAY Max Winding RTD Max Bearing RTD Ambient RTD Max Other RTD RTD1 WDG 91 RTD2 WDG 94 RTD3 WDG 96 RTD4 BRG 24 RTD5 BRG 48 RTD6 BRG 72 RTD7 AMB 35 RTD8 OTH 1 120 RTD9 OTH 2 144 RTD10 OTH 3 168 Generator TCU (%) RTD TCU (%) =>> Figure 5.3 Date Code 20150521 Date: 02/24/2010 Time: 15:09:23.117 Time Source: Internal 96 C 72 C 35 C 168 C C C C C C C C C C C 76.2 72 MET T Report for SEL-700G0 Model Instruction Manual SEL-700G Relay 5.6 Metering and Monitoring Metering Energy Metering The SEL-700G with the voltage option includes energy metering. Table 5.4 lists the energy quantities that are available in the Energy Meter report generated by the MET E command. Figure 5.4 shows the device response to the METER E command. NOTE: Energy values rollover after 999,999 MVAh and reset to 0. =>>MET E <Enter> SEL-700G GENERATOR RELAY X Side Energy Positive MWHX (MWh) Negative MWHX (MWh) Positive MVARHX (MVArh) Negative MVARHX (MVArh) Date: 03/05/2010 Time: 10:56:59.234 Time Source: Internal 999998.500 67543.037 123454.765 4523.386 LAST RESET = 03/04/2010 13:07:54 =>> Figure 5.4 Device Response to the METER E Command To reset energy meter values, issue the METER RE command as shown in Figure 5.5. =>>MET RE <Enter> Reset Metering Quantities (Y,N)? Y <Enter> Reset Complete =>> Figure 5.5 Device Response to the METER RE Command The MET WE command from Access Level 2 allows you to preload data for the Energy Meter Report. See Figure 5.6 for the device response to the MET WE command. =>>MET WE <Enter> X Side 3-Phase Energy Data Preload Positive Negative Positive Negative real energy (0 - 999999.000) real energy (0 - 999999.000) reactive energy (0 - 999999.000) reactive energy (0 - 999999.000) MWHPX MWHNX MVARHPX MVARHNX = 123456.789 ? 123456.789 = 123456.789 ? 123456.789 = 123456.789 ? 123456.789 = 0.000 ? 123456.789 MWHPY MWHNY MVARHPY MVARHNY = = = = Date Time = 03/10/2010 ? 3/11/2010 = 08:10:10 ? 16:01:02 Y Side 3-Phase Energy Data Preload Positive Negative Positive Negative real energy (0 - 999999.000) real energy (0 - 999999.000) reactive energy (0 - 999999.000) reactive energy (0 - 999999.000) Last Reset 12345.123 123.123 0.345 123.000 ? ? ? ? 123456.789 123456.789 123456.789 123456.789 Save changes (Y,N)? Y <Enter> New Energy Data Saved =>> Figure 5.6 Device Response to the METER WE Command Energy metering values are stored to nonvolatile memory four times a day and within one minute of the energy metering values being reset. SEL-700G Relay Instruction Manual Date Code 20150521 Metering and Monitoring Metering Maximum and Minimum Metering 5.7 Maximum and minimum metering allows you to determine maximum and minimum operating quantities such as currents, voltages, power, analog input quantities, RTD quantities, and frequency. Table 5.4 lists the max/min metering quantities. Table 5.4 Maximum/Minimum Meter Values Relay Option Maximum/Minimum Meter Values X-Side Maximum/ Minimum Quantities (model dependent) ➤ Input currents IAX, IBX, and ICX magnitudes (A primary) ➤ Calculated currents IGX (IGX = 3I0 = IAX + IBX + ICX) (A primary) ➤ Wye-connected input voltages (with respect to neutral): VAX, ➤ ➤ ➤ ➤ ➤ Y-Side Maximum/ Minimum Quantities (model dependent) VBX, and VCX magnitudes (V primary); Calculated voltages VGX (VGX = 3V0 = VAX + VBX + VCX) (V primary) Delta-connected input voltages: VABX, VBCX, and VCAX magnitudes (V primary) Three-phase (P3X) real power (kW) Three-phase (Q3X) reactive power (kVAR) Three-phase (S3X) apparent power (kVA) Frequency (FREQX) in Hz. ➤ Input currents IAY, IBY, and ICY magnitudes (A primary) ➤ Calculated currents IGY (IGY = 3I0 = IAY + IBY + ICY) (A primary) ➤ Wye-connected input voltages (with respect to neutral): VAY, ➤ ➤ ➤ ➤ ➤ Other Maximum/ Minimum Quantities (model dependent) VBY, and VCY magnitudes (V primary); Calculated voltages VGY (VGY = 3V0 = VAY + VBY + VCY) (V primary) Delta-connected input voltages: VABY, VBCY, and VCAY magnitudes (V primary) Three-phase (P3Y) real power (kW) Three-phase (Q3Y) reactive power (kVAR) Three-phase (S3Y) apparent power (kVA) Frequency (FREQY) in Hz. ➤ Synchronism-check voltage input (VS) magnitude (V primary) ➤ Neutral voltage input (VN) magnitude (V primary) ➤ Third harmonic voltages for stator ground element 64G (Wye-connected X-side PTS only): ➤ Third harmonic voltages VPX3 (VPX3 = VAX3 + VBX3 + VCX3) and VN3 (V primary). ➤ RTD1-RTD12 temperatures (°C) ➤ Analog input values (±20mA, ±10V) in engineering units All maximum and minimum metering values include the date and time that these values occurred. The analog quantities from Table 5.4 are checked approximately every 0.5 seconds and, if a new maximum or minimum value occurs, this value is saved along with the date and time that the maximum or minimum value occurred. Maximum and minimum values are only checked if relay element FAULT is deasserted (no fault condition exists) for at least one second. Additionally, the following minimum thresholds must also be met (n = X or Y for X or Y-side quantities): Date Code 20150521 ➤ Current values IAn, IBn, ICn, and IN: 3% of the nominal CT rating. ➤ Current values IGn: IAn, IBn, and ICn all must be above their thresholds. Instruction Manual SEL-700G Relay 5.8 Metering and Monitoring Metering ➤ Voltage values (phase, phase-to-phase, synchronism check, neutral): 7.5 V • PTRn, 13 V • PTRn, 7.5 V • PTRS, and 7.5 V • PTRN, respectively. ➤ Power values (real, reactive, and apparent): All three currents (IAn, IBn, ICn) and all three voltages (VAn, VBn, VCn, or VABn, VBCn, VCAn) must be above their thresholds. Figure 5.7 shows an example device response to the METER M command. =>>MET M <Enter> SEL-700G GENERATOR RELAY IAX (A) IBX (A) ICX (A) IGX (A) IAY (A) IBY (A) ICY (A) IGY (A) IN (A) VAX (V) VBX (V) VCX (V) VS (V) VN (V) VN3 (V) VP3X (V) kW3X (kW) kVAR3X (kVAR) kVA3X (kVA) FREQX (Hz) RTD1 (C) RTD2 (C) RTD3 (C) RTD4 (C) RTD5 (C) RTD6 (C) RTD7 (C) RTD8 (C) RTD9 (C) RTD10 (C) Date: 02/24/2010 Time: 15:13:20.377 Time Source: Internal MAX 505.2 502.7 500.0 11.7 501.2 503.5 500.1 10.1 11.1 9980.8 9983.4 9987.4 9985.8 15.8 5.8 17.9 13026 8031.6 15033 60.00 91 94 96 24 48 72 96 120 144 168 DATE 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 TIME 15:03:38 11:29:28 15:01:15 11:30:07 15:03:38 11:29:28 15:01:15 15:03:14 15:05:12 15:07:16 11:29:07 11:29:45 15:05:13 15:03:12 14:05:23 15:05:13 14:54:52 11:29:01 15:06:53 11:22:50 15:06:19 15:06:23 15:06:27 14:50:22 14:50:22 14:50:22 14:50:22 14:50:22 14:50:22 14:50:22 MIN 504.2 501.1 498.1 4.0 500.6 502.3 499.6 9.0 9.6 9974.7 9979.7 9983.5 9975.7 5.7 2.7 9.7 12702 7494.6 15023 59.98 -48 -24 0 24 48 72 23 120 144 168 DATE 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 02/24/2010 TIME 11:29:14 14:58:14 11:28:33 15:12:28 11:29:14 14:58:14 11:28:33 14:59:16 14:54:15 15:11:21 14:51:00 15:07:59 14:11:24 14:12:25 14:15:44 12:11:54 11:27:49 14:50:34 11:29:57 15:02:24 14:50:23 14:50:23 14:50:23 14:50:23 14:50:23 14:50:23 15:02:59 14:50:23 14:50:23 14:50:23 LAST RESET = 02/24/2010 11:22:49 =>> Figure 5.7 Device Response to the METER M Command To reset maximum/minimum meter values, issue the METER RM command as shown in Figure 5.8. The max/min meter values can be reset from the serial port, Modbus, the front panel, or assertion of the RSTMXMN relay element. The date and time of the reset are preserved and shown in the max/min meter report. =>>MET RM <Enter> Reset Metering Quantities (Y,N)? Y <Enter> Reset Complete =>> Figure 5.8 Device Response to the METER RM Command All maximum and minimum metering values are stored to nonvolatile memory four times per day and within one minute of the maximum and minimum metering values being reset. SEL-700G Relay Instruction Manual Date Code 20150521 Metering and Monitoring Metering Math Variable Metering 5.9 The SEL-700G includes 32 math variables. When you receive your SEL-700G, no math variables are enabled. To use math variables, enable the number of math variables (between 1 and 32) you require, using the EMV setting in the Logic setting category. Figure 5.9 shows the device response to the METER MV M(ath) V(ariable) command with 8 of the 32 math variables enabled. =>>MET MV <Enter> SEL-700G GENERATOR RELAY MV01 MV02 MV03 MV04 MV05 MV06 MV07 MV08 Date: 02/24/2010 Time: 15:26:40.866 Time Source: Internal 1.00 -32767.00 -1.00 0.00 1000.59 -1000.61 2411.01 2410.99 =>> Figure 5.9 RMS Metering Device Response to the METER MV Command The SEL-700G includes root-mean-squared (rms) metering. Use rms metering to measure the entire signal (including harmonics). You can measure the rms quantities shown in Table 5.5. Table 5.5 RMS Meter Values Relay Option RMS Meter Values X-Side RMS Quantities (model dependent) ➤ Input currents IAX, IBX, and ICX magnitudes (A primary) ➤ Wye-connected input voltages (with respect to neutral): VAX, VBX, and VCX magnitudes (V primary) ➤ Delta-connected input voltages: VABX, VBCX, and VCAX magnitudes (V primary) Y-Side RMS Quantities (model dependent) ➤ Input currents IAY, IBY, and ICY magnitudes (A primary) ➤ Wye-connected input voltages (with respect to neutral): VAY, VBY, and VCY magnitudes (V primary) ➤ Delta-connected input voltages: VABY, VBCY, and VCAY magnitudes (V primary) Other RMS Quantities (model dependent)...
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  • Winter '18
  • JAVIER LOZANO URBINA
  • Electricity distribution, Measuring instrument, Multimeter

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