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1 IEEE P3004.8™/D1.1235, June, 2010October, 2011June September 2 November2012February 2013

DCN 8-13-0010-00-CMTS Comments by Dan Ransom 02/28/2013

1IEEE P3004.8™/D1.12345 2Draft Recommended Practice for 3Motor Protection in Industrial and 4Commercial Power Systems

5Sponsor

6Technical Book Coordinating Committee 7of the 8IEEE Industry Applications Society

9Approved 10IEEE-SA Standards Board 11

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3 Copyright © 2010 201120122013IEEE. All rights reserved. 4 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8™/D1.1235, June, 2010October, 2011June September 2 November2012February 2013

1Abstract: This recommended practice covers the protection of motors used in industrial and 2commercial power systems. It is likely to be of greatest value to the power-oriented engineer with 3limited experience in the area of protection and control. It can also be an aid to all engineers 4responsible for the electrical design of industrial and commercial power systems. 5 6Keywords: 7

8

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17 Copyright © 2010 201120122013IEEE. All rights reserved. 18 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8™/D1.1235, June, 2010October, 2011June September 2 November2012February 2013

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3 Copyright © 2010 201120122013IEEE. All rights reserved. 4 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8™/D1.1235, June, 2010October, 2011June September 2 November2012February 2013

1Introduction

2 This introduction is not part of IEEE P3004.8/D1.125, Draft Recommended Practice for Motor Protection in 3 Industrial and Commercial Power Systems.

4

5Notice to users

6Laws and regulations

7Users of these documents should consult all applicable laws and regulations. Compliance with the 8provisions of this standard does not imply compliance to any applicable regulatory requirements. 9Implementers of the standard are responsible for observing or referring to the applicable regulatory 10requirements. IEEE does not, by the publication of its standards, intend to urge action that is not in 11compliance with applicable laws, and these documents may not be construed as doing so.

12Copyrights

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28Errata

29Errata, if any, for this and all other standards can be accessed at the following URL: 30http://standards.ieee.org/reading/ieee/updates/errata/index.html. Users are encouraged to check this URL 31for errata periodically.

3 iv 4 Copyright © 2010 20112013 IEEE. All rights reserved. 5 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8™/D1.1235, June, 2010October, 2011June September 2 November2012February 2013

1Interpretations

2Current interpretations can be accessed at the following URL: http://standards.ieee.org/reading/ieee/interp/ 3index.html.

4Patents

5[If the IEEE has not received letters of assurance prior to the time of publication, the following notice 6shall appear:]

7Attention is called to the possibility that implementation of this recommended practice may require use of 8subject matter covered by patent rights. By publication of this recommended practice, no position is taken 9with respect to the existence or validity of any patent rights in connection therewith. The IEEE is not 10responsible for identifying Essential Patent Claims for which a license may be required, for conducting 11inquiries into the legal validity or scope of Patents Claims or determining whether any licensing terms or 12conditions provided in connection with submission of a Letter of Assurance, if any, or in any licensing 13agreements are reasonable or non-discriminatory. Users of this recommended practice are expressly 14advised that determination of the validity of any patent rights, and the risk of infringement of such rights, is 15entirely their own responsibility. Further information may be obtained from the IEEE Standards 16Association.

17[The following notice shall appear when the IEEE receives assurance from a known patent holder or 18patent applicant prior to the time of publication that a license will be made available to all applicants 19either without compensation or under reasonable rates, terms, and conditions that are demonstrably free 20of any unfair discrimination.]

21Attention is called to the possibility that implementation of this recommended practice may require use of 22subject matter covered by patent rights. By publication of this recommended practice, no position is taken 23with respect to the existence or validity of any patent rights in connection therewith. A patent holder or 24patent applicant has filed a statement of assurance that it will grant licenses under these rights without 25compensation or under reasonable rates, with reasonable terms and conditions that are demonstrably free of 26any unfair discrimination to applicants desiring to obtain such licenses. Other Essential Patent Claims may 27exist for which a statement of assurance has not been received. The IEEE is not responsible for identifying 28Essential Patent Claims for which a license may be required, for conducting inquiries into the legal validity 29or scope of Patents Claims, or determining whether any licensing terms or conditions provided in 30connection with submission of a Letter of Assurance, if any, or in any licensing agreements are reasonable 31or non-discriminatory. Users of this recommended practice are expressly advised that determination of the 32validity of any patent rights, and the risk of infringement of such rights, is entirely their own responsibility. 33Further information may be obtained from the IEEE Standards Association.

3 v 4 Copyright © 2010 20112013 IEEE. All rights reserved. 5 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8™/D1.1235, June, 2010October, 2011June September 2 November2012February 2013

1Participants

2At the time this draft recommended practice was submitted to the IEEE-SA Standards Board for approval, 3the Protection and Coordination Working Group of the technical Books Coordinating Committee of the 4Industrial and Commercial Power Systems Department of the Industry Applications Society had the 5following membership:

6 , Chair 7 , Vice Chair 8 9Participant1 12Participant4 15Participant7 10Participant2 13Participant5 16Participant8 11Participant3 14Participant6 17Participant9 18 19 20The following members of the balloting committee voted on this. Balloters may have voted for approval, disapproval, or abstention. 22 23(to be supplied by IEEE) 24 25Balloter1 28Balloter4 31Balloter7 26Balloter2 29Balloter5 32Balloter8 27Balloter3 30Balloter6 33Balloter9 34 35 36When the IEEE-SA Standards Board approved this recommended practice on , it 37had the following membership:

38(to be supplied by IEEE) 39 , Chair 40 , Vice Chair 41 , Past President 42 , Secretary 43 44SBMember1 47SBMember4 50SBMember7 45SBMember2 48SBMember5 51SBMember8 46SBMember3 49SBMember6 52SBMember9

53 *Member Emeritus 54 55 56Also included are the following nonvoting IEEE-SA Standards Board liaisons:

57 , NRC Representative 58 , DOE Representative 59 , NIST Representative 60 61 62 IEEE Standards Program Manager, Document Development 63 64 65 IEEE Standards Program Manager, Technical Program Development 66

3 vi 4 Copyright © 2010 20112013 IEEE. All rights reserved. 5 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8™/D1.1235, June, 2010October, 2011June September 2 November2012February 2013

1Contents

21. Scope...... 1

32. Normative references...... 1

43. Definitions, abbreviations, and acronyms...... 2 5 1.1 Definitions...... 2 6 1.1 Acronyms and abbreviations...... 2

74. General discussion...... 2 8 4.1 Low-voltage systems...... 3 9 4.2 Medium-voltage systems...... 3

105. Factors to consider in protection of motors...... 3 11 5.1 Motor characteristics...... 3 12 5.2 Motor-starting conditions...... 5 13 5.3 Ambient conditions...... 5 14 5.4 Driven equipment...... 5 15 5.5 Power system quality...... 6 16 5.6 Motor importance...... 6 17 5.7 Load-side faults for motor controllers...... 6 18 5.8 Ground faults...... 7 19 5.9 Maintenance capability and schedule...... 7 20 5.10 Service factor...... 7

216. Types of protection...... 8 22 6.1 Purpose of motor protection...... 8 23 6.2 Abnormal power supply conditions (undervoltage protection)...... 8 24 6.2.1 Undervoltage (Device 27)...... 8 25 6.2.2 Instantaneous or time delaydelay...... 9 26 6.2.3 With latching contactor or circuit breaker...... 9 27 6.2.4 With ac magnetically held main contactor...... 10 28 6.2.5 With dc magnetically held main contactor...... 10 29 6.2.6 Voltage-sensing relays...... 10 30 6.3 Phase unbalance protection (Device 46, current) (Device 47, voltage) )(Device 60)...... 11 31 6.3.1 Purpose...... 11 32 6.3.2 Single phasing...... 11 33 6.3.3 Instantaneous or time delaydelay...... 12 34 6.3.4 Relays...... 12 35 6.4 Overcurrent protection (Device 51, inverse time) (Device 50, instantaneous)...... 12 36 6.5 Multifunction relay (Device 11)...... 13

377. Low-voltage motor protection...... 13 38 7.1 Low-voltage motor overcurrent protection...... 14 39 7.1.1 Thermal and electronic overload relays...... 14 40 7.1.2 Time-delay (or dual-element) fuses...... 15 41 7.1.3 Inverse-time circuit breakers...... 15 42 7.1.4 Instantaneous trip circuit breakers (or motor circuit protectors)...... 15 43 7.2 Low-voltage motor ground-fault protection...... 17

3 vii 4 Copyright © 2010 20112013 IEEE. All rights reserved. 5 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8™/D1.1235, June, 2010October, 2011June September 2 November2012February 2013

1 7.2.1 Solidly grounded systems...... 18 2 7.2.2 Low-resistance-grounded systems...... 18 3 7.2.3 High-resistance-grounded systems...... 18 4 7.3 Low-voltage motor stator winding over temperature...... 18 5 7.3.1 Thermostat winding over-temperature devices...... 19 6 7.3.2 Thermistor winding over-temperature devices...... 19 7 7.3.3 Resistance temperature detector (RTD) winding over-temperature devices....19 8 7.4 Low-voltage motor undervoltage protection...... 19 9 7.4.1 Undervoltage relays...... 20 10 7.4.2 Undervoltage sensors for circuit breakers...... 20

118. Medium-voltage motor protection...... 20 12 8.1 Medium-voltage motor overcurrent protection...... 20 13 8.2 Fault protection...... 25 14 8.2.1 Motor overcurrent differential relay (Device 87)...... 25 15 8.2.1.1 Conventional phase differential overcurrent relay...... 25 16 8.2.1.2 Self-balancing differential using window CTs...... 26 17 8.2.2 Split winding current unbalance (Device 87)...... 27 18 8.2.2.1 Purpose...... 27 19 8.2.2.2 Arrangement of CTs and relays...... 27 20 8.2.2.3 Evaluation of split windingsplit-winding current unbalance protection...... 27 21 8.2.2.4 Application of split windingsplit-winding protection...... 28 22 8.2.3 Ground-fault protection...... 28 23 8.2.3.1 Purpose...... 28 24 8.2.3.2 Instantaneous ground-fault protection...... 28 25 8.2.3.3 Time-overcurrent ground-fault protection...... 29 26 8.2.3.4 Installation of cable for ground-fault protection...... 29 27 8.2.3.5 Residually connected CTs and ground-fault relay...... 29 28 8.2.3.6 Selection of resistor for low-resistance system grounding...... 30 29 8.3 Monitors...... 30 30 8.3.1 Stator winding over temperature...... 30 31 8.3.2 RTDs...... 30 32 8.3.2.1 Thermocouples...... 31 33 8.3.2.2 Thermistors...... 31 34 8.3.2.3 Thermostats and temperature bulbs...... 31 35 8.3.2.4 Application of stator winding temperature protection...... 31 36 8.3.3 Rotor over temperature...... 32 37 8.3.3.1 Synchronous motors...... 32 38 8.3.3.2 Wound-rotor induction motor-starting resistors...... 32

3 viii 4 Copyright © 2010 20112013 IEEE. All rights reserved. 5 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8™/D1.1235, June, 2010October, 2011June September 2 November2012February 2013

1 8.3.4 Mechanical and other protection...... 32 2 8.3.4.1 Motor bearing and lubricating systems...... 32 3 8.3.4.2 Ventilation and cooling systems...... 33 4 8.3.4.3 Liquid detectors...... 33 5 8.3.4.4 Fire detection and protection...... 33 6 8.3.4.5 Partial discharge detectors...... 33 7 8.3.5 Vibration monitors and sensors...... 34 8 8.3.5.1 Purpose of vibration monitoring...... 34 9 8.3.5.2 Transducers...... 34 10 8.3.5.3 Proximity transducers...... 34 11 8.3.5.4 Monitors...... 37 12 8.3.5.5 Diagnostic systems...... 38 13 8.4 Synchronous motor protection...... 39 14 8.4.1 Damper winding protection...... 39 15 8.4.2 Field-current failure protection...... 39 16 8.4.3 Excitation voltage availability...... 40 17 8.4.4 Pullout protection (Device 55)...... 40 18 8.4.5 Incomplete starting sequence (Device 48)...... 40 19 8.4.5.1 Operation indicator for protection devices...... 41 20 8.4.5.2 Induction motor protection...... 41 21 8.5 Protection against excessive starting...... 41 22 8.6 Rotor winding protection...... 41 23 8.6.1 Synchronous motors...... 41 24 8.6.2 Wound-rotor induction motors...... 42 25 8.7 Lightning and surge protection...... 42 26 8.7.1 Types of protection...... 42 27 8.7.2 Locations of surge protection...... 44 28 8.7.3 Application of surge protection...... 44 29 8.8 Protection against overexcitation from shunt capacitance...... 44 30 8.8.1 Nature of problem...... 44 31 8.8.2 Protection...... 45 32 8.9 Protection against automatic reclosing or automatic transfer...... 46 33 8.9.1 Nature of problem...... 46 34 8.9.2 Protection...... 46 35 8.10 Protection against excessive shaft torques...... 47 36 8.11 Protection against excessive shaft torques developed during transfer of motors between out-of- 37 phase sources...... 47 38 8.12 Protection against failure to rotate...... 48 39 8.12.1 Failure to rotate...... 48 40 8.12.2 Reverse rotation...... 49

419. Application considerations...... 49 42 9.1 Motor protection for ASD applications...... 49

3 ix 4 Copyright © 2010 20112013 IEEE. All rights reserved. 5 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8™/D1.1235, June, 2010October, 2011June September 2 November2012February 2013

1 9.1.1 Terminology...... 49 2 9.1.2 Low Voltage AC Drive Motor Protection...... 49 3 9.1.2.1 Protection...... 50 4 9.1.2.2 Included in ASD...... 50 5 9.1.2.3 Bypass Circuits...... 51 6 9.1.2.4 Multiple Motor Applications...... 51 7 9.1.2.5 Overtemperature Protection...... 51 8 9.1.3 Medium Voltage AC Drive Motor Protection...... 52 9 9.1.4 DC Drive Motor Protection...... 52 10 9.1.5 Other Considerations...... 52 11 9.1.5.1 Shaft Voltage and Bearing Currents and Common Mode Voltages...... 52 12 9.1.5.2 Partial Discharge...... 52 13 9.1.5.3 ASD Output filters and reactors...... 52 14 9.1.5.4 NEMA MG-1 Part 30 and 31 Inverter Duty...... 53 15 9.1.6 Selecting Drives...... 53 16 9.1.6.1 Selection Considerations...... 53 17 9.1.6.2 Regeneration and Dynamic Braking...... 54 18 9.1.7 Drive Protection...... 54 19 9.2 Motor protection for hazardous (classified) locations...... 55 20 9.3 DC Motor protection...... 55

21Annex A Bibliography...... 56

22Annex B Protection setting considerations...... 57 23 B.1 Typical motor protection settings...... 57 24 B.2 Current unbalance and ground fault protection in HRG system...... 57 25 B.3 Overcurrent protection in fixed capacitor applications...... 57 26

3 x 4 Copyright © 2010 20112013 IEEE. All rights reserved. 5 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8/D1.12, June, 2010October 2011June 2012February 2013

1Draft Recommended Practice for 2Motor Protection in Industrial and 3Commercial Power Systems

4IMPORTANT NOTICE: This standard is not intended to ensure safety, security, health, or 5environmental protection in all circumstances. Implementers of the standard are responsible for 6determining appropriate safety, security, environmental, and health practices or regulatory 7requirements.

8This IEEE document is made available for use subject to important notices and legal disclaimers. 9These notices and disclaimers appear in all publications containing this document and may 10be found under the heading “Important Notice” or “Important Notices and Disclaimers 11Concerning IEEE Documents.” They can also be obtained on request from IEEE or viewed at 12http://standards.ieee.org/IPR/disclaimers.html.

131. Scope

14This recommended practice covers the protection of motors used in industrial and commercial power 15systems. It is likely to be of greatest value to the power-oriented engineer with limited experience in the 16area of protection and control. It can also be an aid to all engineers responsible for the electrical design of 17industrial and commercial power systems.

182. Normative references

19 The following referenced documents are indispensable for the application of this 21document (i.e., they must be understood and used, so each referenced document is cited in text and its 22relationship to this document is explained). For dated references, only the edition cited applies. For undated 23references, the latest edition of the referenced document (including any amendments or corrigenda) applies.

24API Std 541-1995, Form-Wound Squirrel Cage Induction Motors—250 Horsepower and Larger.

25API Std 546-1997, Brushless Synchronous Machines—500 kVA and Larger.

26IEC 60947-4-1-2000, Low-Voltage Switchgear and Controlgear, Part 4: Contactors and Motor Starters, 27Section One—Electromechanical Contactors and Motor-Starters.

2 1 3 Copyright © 2010 20112013 IEEE. All rights reserved. 4 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8/D1.12, June, 2010October 2011June 2012February 2013

1IEEE Std 141-1993 (Reaff 1999), IEEE Recommended Practice for Electric Power Distribution for 2Industrial Plants (IEEE Red Book).

3IEEE Std 241-1990 (Reaff 1997), IEEE Recommended Practice for Electric Power Systems in Commercial 4Buildings (IEEE Gray Book).

5IEEE Std 1015-1997, IEEE Recommended Practice for Applying Low-Voltage Circuit Breakers Used in 6Industrial and Commercial Power Systems (IEEE Blue Book).

7IEEE Std. 1349-2011, IEEE Guide for the Application of Electric Motors in Class I, Division 2 and Class I, 8Zone 2 Hazardous (Classified) Locations

9IEEE Std C37.2-1996, IEEE Standard Electrical Power System Device Function Numbers.

10IEEE Std C37.17-1997, Trip Devices for AC and General Purpose DC Low-Voltage Power Circuit 11Breakers.

12IEEE Std C37.96-2000, IEEE Guide for AC Motor Protection.

13NEMA ICS 2-2000, Industrial Control and Systems Controllers, Contactors and Overload Relays Rated 14600 Volts.

15NEMA MG 1-1998 (Revision 1, 2000), Motors and Generators.

16NFPA 20-1999, Standard for the Installation of Centrifugal Fire Pumps.

17NFPA 70-1999, National Electrical Code® (NEC®).

183. Definitions , abbreviations, and acronyms

19For the purposes of this document, the following terms and definitions apply. The IEEE Standards 20Dictionary: Glossary of Terms & Definitions should be referenced for terms not defined in this clause.1 21[BB46]

223.1 Definitions

23abnormal operating condition: As applied to motors, including, but not limited to, 24starting, locked rotor, voltage unbalance, overload, and short-circuit. As applied to 25equipment in classified locations, equipment failure is considered to be an abnormal 26operating condition. 27adjustable speed drive: an electric drive designed to provide easily operable means for 28speed adjustment of the motor, within a specified speed range. (See IEEE 100) 29ambient temperature: Ambient temperature is the temperature of the surrounding 30cooling medium, such as gas or liquid, which comes into contact with the heated parts of 31the apparatus (See NEMA MG-1)

21 The IEEE Standards Dictionary: Glossary of Terms & Definitions is available at http://shop.ieee.org/. 3 2 4 Copyright © 2010 20112013 IEEE. All rights reserved. 5 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8/D1.12, June, 2010October 2011June 2012February 2013

1approved: Acceptable to the authority having jurisdiction. 2 2autoignition temperature (AIT): The minimum temperature required to initiate or cause 3self-sustained combustion of a solid, liquid, or gas independently of the heating or heated 4element. 3 5Class B rise: Based on a maximum 40C ambient, a motor stator temperature rise at 1.0 6service factor of 80C (measured by resistance) or 80C, 85C, or 90C (measured by 7embedded detectors) in accordance with NEMA MG-1-2009 (Revision 1-2010), 4 8depending on the motor size, motor type, enclosure type, and voltage rating. The rise at 91.0 service factor corresponds to Class B type of insulation system in the NEMA MG-1- 102009 (Revision 1-2010) temperature rise tables. 11Common Mode Voltage: In the context of Adjustable Speed Drives, Common Mode 12Voltage (CMV) is the displacement of the neutral point (and each phase voltage) of the 13ASD output from ground due to the switching of the solid state devices in the drive. It is 14an alternating voltage whose magnitude and frequency components are dependent on the 15drive topology. All present drive topologies create CMV to some extent. CMV can also 16be created at the motor if phase circuit conductors, unsymmetrical with respect to the 17equipment grounding conductor(s) or grounded sheaths or raceways, are used between 18the ASD output and the motor. 19continuous duty: operation at a substantially constant load for an indefinitely long time. 20This is also known as continuous rating in NEMA MG-1. 21corona: A type of localized discharge resulting from transient gaseous ionization on an 22insulation system when the voltage stress exceeds a critical value. The ionization is 23usually localized over a portion of the distance between the electrodes of the system. 24(Corona activity can result in surface discharges and surface tracking on motor 25windings.) Corona is visible partial discharges in gases adjacent to a conductor. (See 26IEEE 1434 [B51]) 27explosionproof equipment: Equipment enclosed in a case that is capable of 28withstanding an explosion of a specified gas or vapor that may occur within it and of 29preventing the ignition of a specified gas or vapor surrounding the enclosure by sparks, 30flashes, or explosion of the gas or vapor within, and that operates at such an external 31temperature that a surrounding flammable atmosphere will not be ignited thereby. 5 32exposed surface: A surface that is internal to an enclosure or an external surface of an 33enclosure which could be exposed to the surrounding flammable atmosphere, without the 34benefit of an enclosure that would contain an explosion or exclude the hazardous gas. 35(An exposed internal surface may be the rotor, stator, or space heater surfaces of open

22See footnote 3.

33Reprinted with permission from NFPA 497, Recommended Practice for the Classification of Flammable Liquids, Gases or Vapors 4and of Hazardous (Classified) Locations for Electrical Installations in Chemical Process Areas Copyright © 2008, National Fire 5Protection Association, Quincy, MA. This reprinted material is not the complete and official position of the NFPA on the reference 6subject which is represented only by the standard in its entirety.

74Information on references can be found in Clause 2.

85See Footnote 3. 9 3 10 Copyright © 2010 20112013 IEEE. All rights reserved. 11 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8/D1.12, June, 2010October 2011June 2012February 2013

1and TEFC motors. An exposed external surface is the exterior surface, which could be 2exposed to the surrounding flammable atmosphere such as the exterior surface of 3explosionproof, pressurized, or force ventilated enclosures.) 4identified: (as applied to equipment). Recognizable as suitable for the specific purpose, 5function, use, environment, application, and so forth, where described in a particular 6Code requirement. 6 7IC Code: The IC Code designates the method of electrical machine cooling as described 8in NEMA MG-1, Part 6. 9IP Code: The IP Code designates the degree of protection provided by the enclosure of a 10rotating machine as described in NEMA MG-1, Part 5. 11listed: Equipment, materials, or services included in a list published by an organization 12that is acceptable to the authority having jurisdiction and concerned with evaluation of 13products or services, that maintains periodic inspection of production of listed equipment 14or materials or periodic evaluation of services, and whose listing states that either the 15equipment, material, or service meets appropriate designated standards or has been tested 16and found suitable for a specified purpose. 7 17multisection motor: A motor whose construction utilizes a component block approach in 18the assembly of the enclosure, that is, the enclosure has a number of bolted joints which 19could connect together the stator frame, the ventilation hood, the motor base, the bearing 20supports, and enclosure covers. 21NEMA frame: This refers to the NEMA MG-1 system of a standardized frame 22designation for AC machines including 449 frame size and smaller. NEMA MG-1-2009 23(Revision 1-2010), Part 4 provides critical mounting dimensions for each frame size. 24normal operating condition: As applied to motors, a normal operating condition is 25operating at rated full-load steady state conditions. 11 Locked-rotor, starting, single- 26phasing, and operating above base nameplate kilowatt or horsepower are not normal 27operating conditions. 28overload: Loading in excess of normal rating of equipment. For a motor, it is considered 29overloaded when operated above its base nameplate kilowatt or horsepower. 30partial discharge: A localized electric discharge resulting from ionization in an 31insulation system when the voltage stress exceeds the critical value. This discharge 32partially bridges the insulation in the voids internal to the motor winding insulation. 33per unit torque (as applied in Annex H): Per unit torque is the test value of load torque 34divided by the motor rated torque at nameplate rated conditions, such as rated voltage and 35rated frequency. 36service factor: A multiplier that, when applied to the rated power, indicates a permissible 37power loading that may be carried under the conditions specified for the service factor.

26See Footnote 3.

37See Footnote 3. 4 4 5 Copyright © 2010 20112013 IEEE. All rights reserved. 6 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8/D1.12, June, 2010October 2011June 2012February 2013

1spark: A sudden and irreversible transition from a stable corona discharge to a stable arc 2discharge. It is a luminous electrical discharge of short duration between two electrodes 3in an insulating medium. It is generally brighter and carries more current than corona, and 4its color is mainly determined by the type of insulating medium. It generates radio noise 5of wider frequency spectrum (extending into hundreds of megahertz) and wider 6magnitude range than corona. A spark is not classified as corona. Sparking can also 7include static discharge, sparking due to mechanical contact, and capacitive discharges 8(ie. across bearing oil film and separating switch contacts).

93.2 Acronyms and abbreviations

10 AFD adjustable frequency drive (ASD is the IEEE preferred term) 11 AHJ authority having jurisdiction 12 AIT autoignition temperature 13 API American Petroleum Institute 14 ASD adjustable speed drive 15 ASTM American Society for Testing and Materials 16 CEC Canadian Electrical Code 17 CENELEC European Committee for Electrotechnical Standardization 18 CMV Common Mode Voltage 19 CSA Canadian Standards Association International 20 DPFV Drip-Proof Forced Ventilated 21 FLC full-load current 22 FLT full-load torque 23 FPN Fine Print Note (formerly used in the National Electrical Code®) 24 HRG High Resistance Ground 25 IC IC Code 26 IEC International Electrotechnical Commission 27 IP IP Code 28 LCI Load Commutated Inverter 29 LFL lower flammable limit 30 LRC locked rotor current 31 LVPCB low-voltage power circuit breaker 32 MCCB molded-case circuit breaker 33 MESG maximum experimental safe gap 34 MIC minimum igniting current 35 MIE minimum ignition energy 36 MOV metal oxide varistor 37 NEC National Electrical Code 38 NEMA National Electrical Manufacturers Association 39 NFPA National Fire Protection Association 40 NRTL Nationally Recognized Testing Laboratory 41 ODE opposite drive end 42 ODP open dripproof 43 OEM original equipment manufacturer 44 PWM pulse-width modulation

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1 RP recommended practice 2 RPM revolutions per minute 3 RTD resistance temperature detector 4 SCR silicon controlled rectifier 5 SF service factor 6 T Code Temperature Code or Identification Number per 2011 NEC Table 7 500.8(C) 8 TEAAC totally enclosed air-to-air cooled 9 TEFC totally enclosed fan cooled 10 TEFV totally enclosed force-ventilated 11 TENV totally enclosed nonventilated 12 TEPV totally enclosed pipe-ventilated 13 TEWAC totally enclosed water-to-air cooled 14 TFE tetrafluoroethylene 15 UFL upper flammable limit 16 UL Underwriters Laboratories Inc. 17 VFD Variable Frequency Drive (ASD is the IEEE preferred term) 18 VSD Variable Speed Drive (ASD is the IEEE preferred term) 19 WPI weather protected Type I 20 WPII weather protected Type II 21

224. General discussion

23This recommended practice applies specifically to three-phase integral horsepower motors. Many factors 24should be considered in choosing motor protection: motor importance, motor rating (from one to several 25thousand horsepower), thermal limit of rotor or stator, environment, power system source and its neutral 26grounding method, type of motor controller, etc. Protection for each specific motor installation should meet 27the requirements of the application. Power quality of the plant distribution system should be given 28appropriate attention, especially with regard to voltage sags and surges, harmonics, service interruptions, 29and operation of distribution line reclosers. Items in 10.2Clause 5 and 10.3 Clause 6 should be considered 30as checklists when deciding upon protection for a given motor installation. After the types of protection 31have been selected, manufacturers’ bulletins should be studied to ensure proper application of the specific 32protection chosen.

334.1 Low-voltage systems

34Low-voltage systems are nominally 1000 V or less. Table 3-11 of the IEEE Std 141-1993 NEMA MG-1 35lists the standard motor nameplate ratings along with the preferred horsepower size limits for the several 36standard motor voltages. At present, a maximum of 575 V and 750 kW exists for motor nameplate ratings. 37

384.2 Medium-voltage systems

39Medium-voltage systems range from above 1000 V and up to 69 kV. Industrial and commercial power 40systems operate with distribution voltages of 2.4 kV, 4.16 kV, 6.9 kV, and 13.8 kV and above. The

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1selection of the motor voltages is described in Chapter 3 of IEEE Std 141-1993.

35. Factors to consider in protection of motors

4The factors in 10.25.1 through 10.25.10 should be considered when selecting motor protection.

55.1 Motor characteristics

6Motor characteristics include type, speed, voltage, horsepower rating, service factor, NEMA design (i.e., A, 7B, C, or D, or E, which are the torque and speed characteristics for low- and medium-voltage motors as 8described in NEMA MG 1-1998), application, power factor rating, type of motor enclosure, bearing 9lubrication types, arrangement of windings and their temperature limits, thermal capabilities of rotor and 10stator during starting, running, and stall conditions. See Table 1.

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1

2 Table 1—Typical characteristics and applications of 3 fixed frequency medium ac squirrel-cage motors

Locked- Locked- Pull-up Breakdown rotor rotor torque torque Polyphase torque current Typical Relative (percent (percent Slip characteristics (percent (percent applications efficiency rated load rated load rated load rated load torque) torque) torque) current) Fans, blowers, Design A centrifugal pumps Normal locked and compressors, rotor torque motor-generator Medium or 70–275a 65–190a 175–300 Not defined 0.5–5% and high sets, etc., where high locked rotor starting torque current requirements are relatively low Fans, blowers, Design B centrifugal pumps Normal and compressors, locked-rotor motor-generator Medium or 70–275a 65–190a 175–300a 600–800 0.5–5% torque and sets, etc., where high normal locked- starting torque rotor current requirements are relatively low Conveyors, crushers, Design C stirring machines, High locked- agitators, rotor torque reciprocating pumps 200–285a 140–195a 190–225a 600–800 1–5% Medium and normal and compressors, locked-rotor etc., where starting current under load is required High peak loads with or without flywheels such as Design D punch presses, High locked- 275 Not defined 275 600–800 Š5% shears, elevators, Medium rotor torque extractors, winches, and high slip hoists, oil-well pumping and wire- drawing machines IEC Design H 200–285a 140–195a 190–225a 800–1000 1–5% Conveyors, crushers, Medium High locked stirring machines, rotor torque agitators, and high reciprocating pumps locked rotor and compressors, current etc., where starting under load is required IEC Design N 70–190a 60–140a 160–200a 800–1000 0.5–3% Fans, blowers, Medium or Normal centrifugal pumps high locked-rotor and compressors, torque and motor-generator high locked sets, etc., where rotor current starting torque requirements are relatively low NOTE—These typical characteristics represent common usage of the motors—for further details consult the specific performance standards for the complete requirements. Reprinted from NEMA MG10-2001 by permission of the National Electrical Manufacturers Association.

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aHigher values are for motors having lower horsepower ratings. 1

25.2 Motor-starting conditions

3Motor-starting conditions include full voltage or reduced voltage, adjustable speed drive (ASD), voltage 4drop and degree of inrush current during starting, repetitive starts, and frequency and total number of starts. 5See Figure 1 and Padden and Pillai [B10].

6 7 Figure 1— Typical motor-starting and capability curves 8 (specific motor terminal voltage and for cold start)

95.3 Ambient conditions

10Ambient conditions include maximum and minimum temperatures, altitude, adjacent heat sources, and 11ventilation arrangement.

125.4 Driven equipment

13Load characteristics are important in the selection of the motor; otherwise, the driven equipment may lead 14to locked rotor, failure to reach normal speed, excessive heating during acceleration, overloading, and 15stalling. See Figure 2, which illustrates the relationship between the accelerating current of a motor versus 16the thermal damage limits of the motor during accelerating and running conditions. Present practice is to 17add an electronic reduced-voltage starter for motors that may have accelerating problems or to add an ASD 18for motors that could be operated at a reduced speed for some reasonable period of the duty cycle. The 19protection of ASDs is not discussed in this recommended practice. For a detailed study of reduced-voltage 20starting, read Chapter 7 of IEEE Std 241-1990.

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1 2 Figure 2— Typical time-current and thermal limit characteristic curves

35.5 Power system quality

4Power system quality issues include types of system grounding, exposure to lightning and switching surges, 5capacitors and their controls for power factor correction, fault capacity, exposure to automatic reclosing or 6transfer, possibilities of single-phase supply (e.g., broken conductor, open disconnect switch or circuit 7breaker pole, blown fuse), and other loads that can cause voltage unbalance. Another factor is harmonics, 8which may cause motor overheating and affect the performance of electronic protective devices.

105.6 Motor importance

11Factors that determine motor importance include motor cost, forced outage costs, amount of maintenance 12and operating supervision to be provided, and ease and cost of repair or replacement. A motor that is 13important to a plant’s operating continuity or process safety should include a pre-trip alarm for operator 14intervention as a first step. An example is to initiate an alarm when a ground fault is detected on high- 15resistance-grounded neutral low-voltage systems. This scheme can also be applied to medium-voltage 16systems below 13.8 kV; but at the 13.8 kV voltage level, use of a trip, rather than alarm, is preferred.

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15.7 Load-side faults for motor controllers

2Although most of this subclause concerns low-voltage applications, the principles apply to medium-voltage 3applications of motor controllers, as well. Calculation of available fault current in a circuit is described in 4Chapter 2. Fuse and circuit breaker protection for conductors in feeder and branch circuits are described in 5Chapter 5, Chapter 6, and Chapter 7.

6NOTE—Fuses and circuit breakers are rated for connection to available fault current sources on the basis 7of protecting the conductors on the load side of the circuit breaker or fuse.

8In a motor controller, the above philosophy does not necessarily extend to protect the motor controller or its 9compartment. For proper protection of the motor controller, the fuse or circuit breaker (or motor circuit 10protector) that the controller manufacturer has had tested by a nationally recognized testing laboratory 11(NRTL) for the rated fault current available at its line terminals should be used. A motor circuit protector 12has an instantaneous-only trip element, similar in construction to a molded-case circuit breaker (MCCB), 13and is defined in 10.47.1.4.

14Such motor controllers for best results should bear an NRTL listing for connection to available currents 15higher than the currents found in the power supply of the plant system under consideration or projected 16plant expansion fault duty. The NRTL-listed controller may still be substantially damaged by a load-side 17fault downstream of the controller. If protection is necessary to minimize damage to the controller itself, 18the controller manufacturer should be consulted, or Type 2 protection should be specified in accordance 19with IEC 60947-4-1-2000. Type 1 protection will prevent major damage but replacement of some motor 20control center components may be necessary after fault occurs.

21Controllers should be protected with fuses or circuit breakers rated for the available fault current.,. This 22subject is covered more thoroughly under protection of low-voltage motors in 7.1.

23Controllers connected to available currents above 10 000 A symmetrical should be provided with fuses or 24circuit breakers rated to interrupt a fault at least equal to the line terminal fault current, with provisions to 25prevent substitution of underrated fuses or circuit breakers. This subject is covered more thoroughly under 26protection of low-voltage motors in 10.47.1.

275.8 Ground faults

28Ground faults often start at a low current level and, if allowed to continue, lead to more extensive damage. 29Whether an arcing or bolted fault, the initial damage is to motor windings, but, if allowed to continue, 30could cause serious damage to the motor core. The cost to repair or replace would then be more expensive. 31This subject is treated in more depth in Chapter 8.

325.9 Maintenance capability and schedule

33Maintenance capability and schedule are important factors. Selection of complex protection that cannot or 34will not be appropriately maintained can lead to inadequate protection. Likewise, the selection and setting 35of overload protection do not prevent inadvertent setting changes due to normal vibration or ambient 36conditions. Backup protection should be coordinated to operate if primary protection fails to operate. 37Maintenance is covered in Chapter 16.

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15.10 Service factor

2The service factor of an ac motor is a multiplier which, when applied to the rated horsepower, indicates a 3permissible horsepower loading that may be carried under the conditions specified for the service factor 4(see NEMA MG 1-1998). <-2011 Section 1, 1.42; 14.37 for standard conditions.>

56. Types of protection

66.1 Purpose of motor protection

7In a power system, the basic premise is that the delivered power is of acceptable quality to satisfy the needs 8of the facility. However, an abnormal condition can exist due to plant conditions or the external power 9supply. Depending upon the plant size and location, conditions such as voltage transients, surges or sags, 10over-frequency or under-frequency, harmonics, or discontinuity may develop that require corrective action. 11For large facilities, the incoming power is likely monitored, and means have probably been taken to protect 12the facility from abnormal conditions. This practice is important, because this recommended practice 13focuses upon only motor protection. For smaller installations or unusual locations, plant protection may be 14more integrated with motor protection.

15The motor protective devices permit the motor to start and run, but initiate tripping and removal of the 16motor circuit from the power system when the motor stalls, does not accelerate, draws excessive current, 17overheats, vibrates excessively, or shows other symptoms of improper motor conditions. Detection is 18through measurement of voltage, current, temperature, frequency, harmonics, vibration, and speed, where 19appropriate. However, for the majority of small motors (i.e., less than 220 kW), overcurrent is the most 20prevalent means.

21In the discussion of protective devices in this recommended practice, reference is made to device numbers, 22which are described in IEEE Std C37.2-1996. In general, medium-voltage protection resorts to device 23numbers because of their convenience in lieu of using repetitive descriptions. The subject of device 24numbers is adequately described in Chapter 4.

25The motor protection selection is typically based on its horsepower/kW rating and voltage level (low and 26medium voltage). They are:

27  Motor ≤ 1000 HP (746 kW) – 48, 49, 49R, 27, 50BF, 51M & 86

28  1000 HP (746 kW) ≤ Motor ≤ 2500 HP (1.9 MW) – 48. 49, 49R, 27, 50BF, 51M & 86

29  Motor ≥ 2500 HP (1.9 MW) – 48.49, 49R, 32, 27/59, 51V, 60, 67 & 81U/O

30  Synchronous motor ≤ 2000 HP (1.49 MW) – 48, 49, 49R, 32, 27/59, 51V, 60, 67 &81U/O, 25

31  Synchronous motor ≥ 2000 HP (1.49 MW) – 48, 49, 49R, 24, 27/59, 32, 40, 50BF, 51V, 67, 81R, 32 81U/O & 87, 25

33

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16.2 Abnormal power supply conditions (undervoltage protection)

26.2.1 Undervoltage (Device 27)

3Although overvoltage conditions should have some consideration, that phenomenon draws less attention 4because of protection by surge arresters for momentary conditions and relays for the less common sustained 5overvoltage. This subclause concentrates on undervoltage conditions. Further discussions concerning large 6motors can be found in 10.5.108.9. Undervoltage protection is used as follows:

7 a) To prevent a motor from automatically restarting when voltage returns following an interruption, as 8 may happen with single-service arrangements or automatic transfer operations. This protection can be 9 accomplished either by controls or by an undervoltage relay (Device 27). Consideration should also be given 10 as to the importance of the motor and whether conditions warrant that the motor ride through voltage sags or 11 drop out at some specific voltage, not to be energized until other conditions may have been met. 12 b) To avoid excessive inrush to the total motor load on the power system with a corresponding voltage 13 sag, following a voltage dip, or when voltage returns following an interruption. 14 c) To avoid reaccelerating motors before their fields collapse. Fast asynchronous reclosing has been 15 damaging and can occur if cooperation is lacking between the industrial plant and its power supplier. The 16 power supplier should be consulted to learn whether it follows the practice of adding time delaydelay before 17 reclosing circuit breakers following an automatic trip. This delay is not a panacea, and some other form of 18 protection may be required, such as under-frequency relaying (Device 81). 19

206.2.2 Instantaneous or time delaydelay

21Undervoltage protection is either instantaneous (i.e., no intentional delay) or time-delay. Time-delay 22undervoltage protection should be used with motors important to continuity of service, providing it is 23satisfactory in all respects, to avoid unnecessary tripping on voltage sags that accompany external short 24circuits. Examples follow of non-latching starters where time-delay undervoltage protection is not 25satisfactory and instantaneous undervoltage should be used:

26NOTE—The limitations in Item a) and Item b) could be overcome by using either a separate ac power 27source for control or battery control on the contactor to prevent its instantaneous dropout. In other words, 28the time-delay undervoltage feature can be applied directly to the main contactor.

29 a) Fusible switch or circuit breaker combination motor starters having ac magnetically held 30 contactors used on systems of low three-phase fault capacity. With the usual time-delay 31 undervoltage scheme, the contactor could drop out due to the low voltage accompanying a fault on 32 the load side of the contactor before the supply fuse or circuit breaker opens to remove the fault. 33 Unless provided with blocking for automatic restart, the contactor could then reclose into the fault. 34 This problem does not exist if the available fault capacity is high enough to open the external fuse 35 or circuit breaker before the contactor interrupts the fault current. 36 b) Synchronous motors used with starters having ac magnetically held contactors. With the 37 usual time-delay undervoltage scheme, the contactor could drop out on an externally caused 38 system voltage dip, then reclose, and reapply the system voltage to an out-of-phase internal 39 voltage in the motor. The high initial inrush could damage the motor winding, shaft, or foundation. 40 This problem could also occur for large, two-pole squirrel-cage induction motors. If asynchronous 41 reclosing represents a risk to the motor, undervoltage protection alone may not suffice; and an 42 under-frequency relay may be required. Asynchronous reclosing usually is not a problem with the 43 150 kW and smaller induction motors with which magnetically held contactor starters are used 44 because the internal voltages of these motors decay quite rapidly.

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1 c) Motors used on systems having fast automatic transfer or reclosing where the motor must 2 be tripped to protect it before the transfer or reclosure takes place. See Item b) regarding 3 asynchronous reclosing needing an under-frequency relay. 4 d) When the total motor load having time-delay undervoltage protection results in excessive 5 inrush current and voltage drop after an interruption. A problem could arise of having insufficient 6 system capacity to restart the motors. Options include designing for a larger power capacity than 7 needed for normal operations or removing some of the motor loads from automatic restarting. 8 Least important motors should use instantaneous undervoltage protection. Time-delay 9 undervoltage protection of selectively chosen delays could be used on the motors whose inrush the 10 system can handle. Sequencers are available for selecting the order of motor restarts, thus reducing 11 the need for oversized transformers or lower transformer impedances. Caution should be observed 12 when placing numerous controls within one device where common mode failure could negate the 13 benefits.

146.2.3 With latching contactor or circuit breaker

15Motor switching devices, such as latching contactors or circuit breakers, inherently remain closed during 16periods of low or zero ac voltage. The following methods are used to trip open the devices:

17 a) Energize shunt trip coil from a battery. 18 b) Energize shunt trip coil from a separate reliable source of ac. This ac source should be 19 electrically isolated from the motor ac source in order to enhance reliability. 20 c) Energize shunt trip coil from a capacitor charged through a rectifier from the ac system. 21 This method is commonly referred to as capacitor trip. 22 d) De-energize a solenoid and allow a spring release to trip the contactor or circuit breaker. 23Item a) through Item c) are usually used in conjunction with voltage-sensing relays (see 10.36.2.6). Item d) 24could have the solenoid operating directly either on the ac system voltage or from a battery, where a relay 25would sense loss of ac voltage and de-energize the solenoid. The solenoid could be either instantaneous or 26time-delay.

276.2.4 With ac magnetically held main contactor

28Because the ac magnetically held main contactor (which supplies the motor) drops out on loss of ac, it 29provides an instantaneous undervoltage function. If automatic restart is required because of the process, 30two common approaches achieve time-delay undervoltage protection:

31 a) Permit the main contactor to drop out instantaneously, but provide a timing scheme 32 (which starts timing when ac voltage is low or zero) to reclose the main contactor when normal ac 33 voltage returns within some preset timing interval. Some of the timing schemes in use are as 34 follows: 35 1) Capacitor charged through a rectifier from the ac system. The charge keeps an instantaneous 36 dropout auxiliary relay energized for an adjustable interval, which is commonly 2 s or 4 s. 37 2) Standard timer that times when de-energized (e.g., pneumatic or inverse time-undervoltage 38 relay). 39 b) Use a two-wire control. This control utilizes a maintained closed start button or operates 40 from an external contact responsive to some condition such as process pressure, temperature, or 41 level. The main contactor drops out with loss of ac, but recloses when ac voltage returns. 42Neither arrangement provides perfect undervoltage protection and should not be used if automatic 43restarting could endanger personnel or equipment.

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16.2.5 With dc magnetically held main contactor

2With a dc magnetically held main contactor, the contactor remains closed during low or zero ac voltage. 3Time-delay undervoltage protection is achieved using voltage-sensing relays (see 10.36.2.6). For this 4scheme, the dc voltage should be monitored as well.

56.2.6 Voltage-sensing relays

6A commonly used type of voltage-sensing relay is the single-phase inverse time-undervoltage relay. 7Because a blown control fuse could cause tripping, two or three such time-undervoltage relays are 8sometimes used, connected to different phases, and wired so that all must operate before tripping occurs or 9re-energization can be permitted.

10Three-phase undervoltage relays are available. Many operate in response to the area of the voltage triangle 11formed by the phasors of the three-phase voltages. Alternatively, a voltage balance relay (Device 60) could 12be used for blown fuse protection.

13When applying undervoltage protection with time delaydelay, the time-delay setting should be chosen so 14that time-delay undervoltage tripping does not occur before all external fault-detecting relays have had an 15opportunity to clear faults from the system. This practice recognizes that the most frequent causes of low 16voltage are system faults; and when these faults are cleared, most induction motors can continue normal 17operation. For inverse time-undervoltage relays, their trip time versus system short-circuit current should be 18plotted to ensure that they trip only after the system overcurrent protective relays. This procedure should be 19done for the most critical coordination condition, which exists when the system short-circuit capacity is 20minimum. This study should be included with normal systems studies concerning voltage drop, short 21circuits, etc. Typical time delaydelay at zero voltage is 2 s to 5 s.

22For motors extremely important to continuity of service, such as some auxiliaries in electric generating 23plants, the undervoltage relays are used only to alarm. The motors providing fire pump service should be 24protected in accordance with NFPA 20-1999.

256.3 Phase unbalance protection (Device 46, current) (Device 47, voltage) )(Device 2660)

276.3.1 Purpose

28The purpose of phase unbalance protection is to prevent motor overheating damage. Motor overheating 29occurs when the phase voltages are unbalanced. A small voltage unbalance produces a large negative- 30sequence current flow in both synchronous and induction motors. The per-unit negative-sequence 31impedance of either motor is approximately equal to the reciprocal of the rated voltage per-unit locked- 32rotor current. When, for example, a motor has a locked-rotor current equal to six times rated current, the 33motor has a negative-sequence impedance of approximately 0.167 per unit (16.7%) on the motor rated 34input kilovoltampere base. When voltages having a 0.05 per-unit negative-sequence component are applied 35to the motor, negative-sequence currents of 0.30 per unit flow in the windings. Thus, a 5% percent voltage 36unbalance produces a stator negative-sequence current equal to 30% percent of full-load current. This 37situation can lead to a 40% percent to 50% percent increase in temperature rise.

386.3.2 Single phasing

39

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1The extreme form of unbalance is the complete loss of voltage in one phase. Under these conditions, a 2three-phase motor is unable to start. If the single phasing occurs during full-load running conditions, the 3current in the two energized phases increases above full-load current for a wye-connected motor (see 4Figure 1). If the motor is delta connected, the current in the motor phase coils that are connected to the 5energized phases will see greater than full load amps and the two phase coils that are bisected by the lost 6phase will see less than full load current (see Figure 2). In each case, adequate phase over current 7protection is required.

8

9 Figure 1 Wye-connected Figure 2 Delta connected

10

14Many motors, especially in the higher horsepower ratings, can be seriously damaged by negative-sequence 15current heating, even though the stator currents are low enough to go undetected by overload (over current) 16protection. (The standard service factor for large motors is 1.00.) Therefore, phase unbalance protection is 17desirable for all motors where its cost can be justified relative to the cost and criticality of the motor. Phase 18unbalance protection should be provided in all applications where single phasing is a strong possibility due 19to factors such as the presence of fuses, overhead distribution lines subject to conductor breakage, or 20disconnect switches (which may not close properly on all three phases). For large facilities, a bus phase- 21balance (negative-sequence) overvoltage relay (Device 47) could be installed to alarm in a sensitive 22manner. This alarm would be set in conjunction with individual large motor (phase-balance) negative- 23sequence over current relays (Device 46). For small installations, a single phase-balance (negative- 24sequence) over current relay may suffice for a large, critical motor; or alternatively one phase-balance 25(negative-sequence) bus overvoltage relay could be set to protect several motors, by alarming and/or 26tripping.

27A general recommendation is to apply phase unbalance protection to all motors 750 kW and above. For 28motors below 750 kW, the specific requirements should be investigated. Phase unbalance protection should 29also be considered for certain critical motors such as hermetic refrigeration chiller motors and similar 30motors.

31A special form of unbalance is the complete loss of one phase at the same voltage level as the motor. Under 32starting conditions, a three-phase motor is unable to start. If the single phasing occurs during full-load 33running conditions, the current in the other two phases increases to approximately 173% of normal full- 34load current for a wye-connected motor. In each case, adequate protection is required. For large facilities, a 35bus phase-balance (negative-sequence) overvoltage relay (Device 47) could be installed to alarm in a 36sensitive manner. This alarm would be set in conjunction with individual large motor (phase-balance)

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1negative-sequence overcurrent relays (Device 46). For small installations, a single phase-balance (negative- 2sequence) overcurrent relay may suffice for a large, important motor; or alternatively one phase-balance 3(negative-sequence) bus overvoltage relay could be set to protect several motors, by alarming and/or 4tripping.

5When a motor is supplied from a delta-wye or wye-delta transformer, single phasing on the supply voltage 6(primary) side of the transformer results in currents to the motor in the ratio of 115%, 115%, and 230% of 7normal. In two phases, the current is only slightly greater than prior to single phasing, while it is 8approximately doubled in the third phase. This situation requires a properly sized overload relay or time- 9delay fuse in each phase if the motor does not have suitable phase unbalance protection.

10Many motors, especially in the higher horsepower ratings, can be seriously damaged by negative-sequence 11current heating, even though the stator currents are low enough to go undetected by overload (overcurrent) 12protection. (The standard service factor for large motors is 1.00.)

13Therefore, phase unbalance protection is desirable for all motors where its cost can be justified relative to 14the cost and importance of the motor. Phase unbalance protection should be provided in all applications 15where single phasing is a strong possibility due to factors such as the presence of fuses, overhead 16distribution lines subject to conductor breakage, or disconnect switches (which may not close properly on 17all three phases).

18A general recommendation is to apply phase unbalance protection to all motors 750 kW and above. For 19motors below 750 kW, the specific requirements should be investigated. Phase unbalance protection should 20also be considered for certain important motors such as hermetic refrigeration chiller motors and similar 21motors having a service factor less than 1.25.

226.3.3 Instantaneous or time delaydelay

23Unbalanced voltages accompany unbalanced system faults. Therefore, phase unbalance protection should 24include sufficient delay to permit the system overcurrent protection to clear external faults without 25unnecessary tripping of the motor or motors.

26Delay is also necessary to avoid the possibility of tripping on motor starting inrush. Therefore, unbalance 27protection having an inherent delay should be chosen. Another (high-risk) scheme is to use an auxiliary 28timer (Device 62). Its selection is important because the timer probably has a higher failure rate than the 29protective relay. If a time delaydelay of more than 2 s or 3 s is used, the motor designer should be 30consulted.

316.3.4 Relays

32Several types of relays are available to provide phase unbalance protection, including single phasing. Most 33of these relays are described in Chapter 4 and in IEEE Std C37.96-2000. Further information about 34specific relays should be obtained from the various manufacturers. Most of the commonly used relays can 35be classified as follows:

36 c) Phase current balance (Device 46). Phase current balance relays are induction disk 37 devices that detect unbalance in the currents in the three phases. As such they have an inherent 38 time delaydelay. Occasionally, a timer may be required to obtain additional delay. Because this 39 relay cannot protect for unbalances less than 25% percent, its selection is questionable except for 40 complete loss of one phase. Unfortunately, this device shares the same device number as the 41 negative-sequence overcurrent relay (Device 46) in Item c).

2 17 3 Copyright © 2010 20112013 IEEE. All rights reserved. 4 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8/D1.12, June, 2010October 2011June 2012February 2013

1 d) Negative-sequence voltage (Device 47). Because negative-sequence voltage relays may 2 operate instantaneously on negative-sequence overvoltage, some external time delaydelay may be 3 necessary. 4 e) Negative-sequence overcurrent (Device 46). A negative-sequence overcurrent relay is a 5 time-overcurrent relay with extremely inverse characteristics that operates at very low levels of 6 negative-sequence current. Settings are available to alarm before trip and to trip upon a limit of 2 7 I2 t.

86.4 Overcurrent protection (Device 51, inverse time) (Device 50, instantaneous)

9Overcurrent sensing is the most frequently used method to monitor and protect the many power circuits in a 10facility. If a short circuit occurs, the action must be initiated without delay, whereas an overload within the 11service factor rating may not require any action. Under Chapter 15 guidelines, no delay should occur in the 12operation of the protection for circuit components (e.g., motors) upon sensing a fault, with backup 13protection coordinated by being delayed in time or overcurrent magnitude, or both.

14Motor branch circuit protection is to operate whenever a motor fails to accelerate, when the motor-running 15current exceeds normal limits, and when a short circuit is detected. Time-overcurrent devices are normally 16used to protect against overloads and failure to accelerate, whereas instantaneous devices operate without 17any intentional delay for short-circuit protection.

18Depending upon the motor rating and voltage, the devices for performing these functions are of different 19construction. For medium-voltage or large motors, the protection may be in the form of three phase- 20overcurrent protective relays or one multifunction relay (Device 11), which would include such other 21protective functions as accelerating characteristics, current unbalance, differential overcurrent, ground-fault 22current, and loss of load. Such complex protection would normally not be provided for unimportant low- 23voltage motors, although capable multifunction devices are available for low-voltage motor protection. In 24addition, some motors may be supplied directly from low-voltage switchgear and use the protective 25characteristics described in IEEE Std C37.17-1997 and shown in Chapter 7. The decision on whether to 26use low-voltage switchgear is usually influenced by the frequency of motor starts because motor controllers 27are rated for a considerably greater number of operations.

286.5 Multifunction relay (Device 11)

29An important development has been the multifunction motor protection relay. Recognized as a powerful 30tool, the multifunction relay incorporates many protective functions that would normally be applied 31through the use of individual protective relays, but are all incorporated into one enclosure. For example, the 32relay incorporates short-circuit and overcurrent protection in each phase- and ground-fault protection. 33Depending upon the options selected, the relay could include protection against stalls, locked rotor, over- 34temperature alarm or trip, current unbalance, metering, and communications. No detailed discussion of the 35relay is included in this subclause because the possible functions are described under other protective 36relays, such as Device 50 and Device 51.

376.5.1 Medium-voltage multifunction relay applications

39Medium-voltage motor starters consist of a vacuum contactor protected by an intelligent relay. While a 40bimetallic thermal overload relay could be used, as is done for low-voltage motors, a greater measure of 41protection is usually desired for medium-voltage motors due to their cost and critical role in many 42applications.

2 18 3 Copyright © 2010 20112013 IEEE. All rights reserved. 4 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8/D1.12, June, 2010October 2011June 2012February 2013

1For some users, a medium-voltage circuit breaker is the preferred device for starting and stopping motors. 2As with a medium-voltage starter, a medium-voltage circuit breaker consist of a contactor (vacuum, SF6, or 3oil-filled) protected by an intelligent relay.

4

7Formerly, individual devices may have been used for various protective functions. Several of them are 8noted earlier in this document: Instantaneous Device 50, Overload Device 51, Time Delay Device 62. 9While offering adequate protection, those devices occupied significant space, required significant labor to 10mount and wire, and required individual calibration and maintenance. Whether medium-voltage starters or 11medium-voltage breakers are used for motor starting, the same multifunction relay may often be used with 12either device to effect motor protection.

13Modern multifunction relays offer protective and monitoring features impossible in older electro- 14mechanical devices. Waveform capture, starts-per-hour protection, fault data logs, broken rotor-bar 15detection, trending, motor load profiling are some of the diagnostic and monitoring functions available. 16

17Multifunction relays usually provide operator interface panels, consisting of touch-screens or soft function 18keys with LCD screens, used for setup and for scrolling among the parameters. Many multifunction relays 19offer programming software. By using software a user can program the setup from a computer, upload new 20setups, download and save files, and monitor the relay locally. Some also have logic capability (AND, OR, 21NAND, NOR gates) programmable via the software.

22Additional input/output capacity may be standard or optional for starter auxiliaries. Motor and bearing RTD 23inputs, formerly requiring a separate relay, may be available.

24

25

26< IAS magazine 27has motor protection, page 10 History, Nov 2012>

28Many users wish to have communications capability incorporated into protective relays. Communications- 29capabilities allow interfacing with the software package for setup, troubleshooting, and monitoring. 30Communications also allow remote monitoring of motors for operating status, operating current, fault 31history, and others. Older separate relays did not generally include communications. Communications may 32be accomplished via RS-232 or USB or fiber ports or RS-485. Protocols may be Modbus RTU, Modbus 33TCP, IEC-61850, and others. .

35

36[this new section needs to include current application technology for protection and communications]

376.5.2 Low-voltage multifunction relay applications

39

40

2 19 3 Copyright © 2010 20112013 IEEE. All rights reserved. 4 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8/D1.12, June, 2010October 2011June 2012February 2013

1While protection for low-voltage motors was traditionally provided through use of heaters in bimetallic 2overload relays or from later solid-state overload relays, many users now desire greater protection. 3Multifunction relays are now offered for that purpose.

4In addition to overload protection, multifunction relays are available for low-current (or low-power) 5protection for pumps to prevent cavitation, jam and stall protection, frequency-of-start, ground fault 6protection, and others. Arc flash sensing is now being incorporated into some multifunction relays.

7Multifunction relays typically provide an human-machine interface (HMI) panel through which setup and 8monitoring may be accomplished. Fault-type, cause of fault, run/stop status, running Amperes, and other 9parameters may be read from the display. Remote HMI ports may be offered for mounting in motor control 10centers and enclosed starter enclosures.

11Multifunction relays may also include as standard or optionally RTD inputs and additional input/output 12points. Input/output points may be used to interface with external control, reversing, multi-speed, and 13reduced-voltage starting systems.

14Communications is now desired by some users. Where traditional overload relays have not included 15communications, many multifunction relays either include communications in the standard feature-set or 16offer it optionally. Communications available include RS-232, RS-485, Modbus RTU, Modbus TCP, IEC- 1761850, a Ethernet, and others.

18 [this new section needs to include current application technology for protection and communications]

196.6 Ground Fault Relay (Device 64)

20This is a classic relay for ground fault detection. It is typically used for medium voltage motors, large 21motors > 750 kW or motors with a neutral. Various methods of ground protection are available such as 22ground sensing, zero sequence sensing and residual sensing.

236.7 Underexcitation (loss of field) Protection (Device 40) 24 25This type of protection is only applicable to synchronous motors. It is applied to the rotor field winding. 26 276.8 Over Excitation (volts/hertz) Protection (Device 24) 28 29This type of protection is only applicable to synchronous motors. It is applied to the rotor field winding. 30 316.9 Bearing Protection Relay (Device 38) 32 33This relay monitors the bearing temperature and trips the motor when the operating temperature reaches the 34trip setpoint. 35 366.10 Mechanical Condition Protection Relay (Device 39) 37 38This protection relates to occurrence of abnormal mechanical condition such as vibration, eccentricity, 39expansion, shock, tilting or seal failure. It uses various sensor to send signals to protection relays. 40

41

2 20 3 Copyright © 2010 20112013 IEEE. All rights reserved. 4 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8/D1.12, June, 2010October 2011June 2012February 2013

17. Low-voltage motor protection

2

3 4

5Conventionally, low-voltage motors drive small process equipment and auxiliary equipment. These motors, 6usually 220 kW and below, may operate continuously or may be in cyclical services. These applications 7use motor contactors in motor control centers (MCCs) or combination starters.

9One-line diagrams of typical low-voltage starters for industrial applications using MCCs or combination 10starters are shown in View (a), View (b), View (c), and View (d) and View (e) of Figure 3.

M

11 (e)

12 a) Typical starter with fuses b) Typical starter with a circuit breaker 13 c) Typical location for power factor correction capacitors d) Typical location for control power transformer 14 e) Typical starter with molded-case switch and fuses 15

16 Figure 3— Typical low-voltage starter one-line diagrams for industrial 17 applications using MCCs or combination starters

187.1 Low-voltage motor overcurrent protection

19Overload protection for low-voltage motors is usually provided by thermal overcurrent relays or electronic 20overcurrent devices. In some cases, dual-element fuses or a thermal-magnetic circuit breaker may serve as 21the primary overload devices, but are normally backup protection for overload relays. Short-circuit 22protection for low-voltage motors is usually provided by fuses, a thermal-magnetic circuit breaker, or an

2 21 3 Copyright © 2010 20112013 IEEE. All rights reserved. 4 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8/D1.12, June, 2010October 2011June 2012February 2013

1instantaneous trip device (or motor circuit protection) in combination with an overload relay. Ground-fault 2protection for low-voltage motors is usually provided by the short-circuit protection device, but ground- 3fault relays may be installed. (See Bradfield and Heath [B1]; Nailen [B8]; Gregory and Padden [B4] and 4[B3]; Smith [B12].)

57.1.1 Thermal and electronic overload relays

6Thermal overload relays are constructed as either melting alloy or bimetallic. Although single-phase 7elements are the most common, they are also furnished in a three-phase construction block design. The 8relays are designed to operate within a current range, as follows:

9 a) Selection of the heater element should be based upon the relay manufacturer’s tables 10 relating motor characteristics and ambient temperature conditions and based on the location of the 11 motor relative to the relay. This method is employed because only minor adjustments need be 12 made in the relay itself to set a trip value to match the motor current. 13 b) After the selection of the heater, the melting alloy unit is considered nontamperable. 14 c) Older bimetallic types may have limited adjustment of trip setting intended to 15 compensate for ambient temperature. Newer relays have a wider range of adjustment. 16 d) The thermal memory of bimetallic overload relays provides satisfactory protection for 17 cyclic overloading and closely repeated motor starts. 18 e) A manual reset feature is available and is normally trip free (i.e., manual override is not 19 possible). 20 f) Some relays are available as ambient-temperature-compensated or as noncompensated. 21 Noncompensated is an advantage when the relay and motor are in the same ambient because the 22 relay opening time changes with temperature in a similar manner as the motor overload capability 23 changes with temperature. 24 g) NEMA ICS 2-2000 has standardized motor overload relays into three classes denoting 25 time delaydelay to trip on locked-rotor current: Class 10 for fast trip, 10 s at six times the overload 26 rating; Class 20, for intermediate trip, for 20 s at six times the overload rating; and Class 30 for 27 long-time trip, 30 s at six times the overload rating. In most applications, the Class 10 relay is 28 applied for hermetic and other motors with a service factor of 1.00 or 1.05. The Class 20 relay is 29 commonly used for higher service factor motors, such as NEMA Design T frame motors. A Class 30 30 relay is used in applications where high-inertia loads cause the motor to have a long starting 31 time, such as conveyor belt motors. Electronic devices, sometimes integral with the contactor, 32 sense the current in all three phases. They can be adjusted for Class 10, Class 20, or Class 30. 33 34Overload relays are sized in accordance with the National Electrical Code® (NEC®) (NFPA 70- 3519992011). Article 430-32, Article 430-33, and Article 430-34 reference the motor nameplate rating. Power 36factor correction capacitors installed for individual motors may be connected as shown in View (c) of 37Figure 3, and no current adjustment need be made to the overload devices. However, this connection is not 38the only method of providing individual power factor correction and has been known to cause contactor 39failures due to resonance with other motor capacitors (see Nailen [B8]). When capacitors are installed 40between the overload device and the motor, the overload relay provides circuit impedance, which generally 41dampens the resonance problem. However, the overload relay current rating should be adjusted to account 42for the reduced current flowing to the motor-capacitor combination. Part 14.43.3 of NEMA MG 1-1998 43recommends a bus connection when several motors are connected to the bus in order to minimize the 44potential harmonic resonance.

2 22 3 Copyright © 2010 20112013 IEEE. All rights reserved. 4 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8/D1.12, June, 2010October 2011June 2012February 2013

1Overload relays and other devices for motor overload protection that are not capable of opening short 2circuits shall be protected by fuses or circuit breakers with ratings or settings in accordance with NEC 3Article 430-52 or by a motor short-circuit protector in accordance with NEC Article 430-52.

47.1.2 Time-delay (or dual-element) fuses

5Time-delay fuses are available from 0.1 A through 600 A. Fuses for short-circuit and ground-fault 6protection shall be sized in accordance with NEC Article 430-52 and Table 430-152. The full-load current 7values used for that table are in Table 430-148, Table 430-149, and Table 430-150. The rating of a time- 8delay fuse shall be permitted to be increased, but in no case exceed 225% percent (400% percent for Class 9CC fuses) of full-load current. A one-line diagram of a typical starter with fuses is shown in View (a) of 10Figure 3. Also available are fuses without time delaydelay, which can provide short-circuit and ground- 11fault protection, but may not provide any backup protection.

127.1.3 Inverse-time circuit breakers

13These circuit breakers (i.e., molded case) are available from 10 A through 3000 A when constructed with 14thermal-magnetic trip elements, and up to 5000 A when constructed with solid state trip elements. Both 15types of trip devices are referred to in the NEC as inverse-time circuit breakers and shall be sized in 16accordance with NEC Article 430-52 and Table 430-152. The full-load current values used for that table 17are in Table 430-148, Table 430-149, and Table 430-150. The rating of an inverse-time circuit breaker shall 18be permitted to be increased, but in no case exceed,

19  400% percent for full-load currents of 100 A or less, 20  300% percent for full-load currents greater than 100 A. 21 22A one-line diagram of a typical starter with a circuit breaker is shown in View (b) of Figure 3.

237.1.4 Instantaneous trip circuit breakers (or motor circuit protectors)

24

25Instantaneous trip circuit breakers (i.e., molded-case), commonly called motor circuit protectors, are 26available from 3 A through 1200 A. The instantaneous setting can typically be adjusted in fixed steps to 27between 3 to 13 or 3 to 10 times the continuous-current rating. Instantaneous trip circuit breakers are tested 28under UL 489 [B13]. The trip range of the breaker should be within +30% percent or –20% percent of the 29set point. On the coordination plot, these devices have a broad bandwidth corresponding to these 30tolerances.

31These breakers are referenced as instantaneous trip breakers and shall be sized in accordance with NEC 32Article 430-52 and Table 430-152. The full-load current values used for that table are in Table 430-148, 33Table 430-149, and Table 430-150. Trip settings above 800% percent for other than Design E motors and 34above 1100% percent for Design E motors shall be permitted where the need has been demonstrated by 35engineering evaluation. In such cases, it shall not be necessary to first apply an instantaneous trip circuit 36breaker at 800% percent or 1100% percent. Either an adjustable instantaneous trip circuit breaker or a 37motor short-circuit protector shall be used when it is part of a listed combination controller having 38coordinated motor overload, short-circuit, and ground-fault protection in each conductor and if it operates 39at not more than 1300% percent of full-load motor current for other than NEMA Design E motors and no 40more than 1700% percent of motor full-load current for Design E motors. A one-line diagram of a typical

2 23 3 Copyright © 2010 20112013 IEEE. All rights reserved. 4 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8/D1.12, June, 2010October 2011June 2012February 2013

1starter with a circuit breaker is shown in View (b) of Figure 3.

3Two points should be reviewed by the engineer. First, the overload device is normally the only line of 4protection from overloads and high-impedance faults when using instantaneous trip circuit breakers. A 5failure of the overload device, the overload wiring, or the contactor can prevent the circuit from being 6isolated due to overload or high-impedance fault conditions. Where backup protection is desired for these 7abnormal conditions, an inverse-time circuit breaker or dual-element fuses should be selected.

8Second, the selection of the contactor and conductor sizes depends on the setting of the instantaneous trip 9function. NEMA-rated magnetic contactors are tested to break up to 10 times the full-load current values 10given in NEC Table 430-148, Table 430-149, and Table 430-150 for the corresponding horsepower rating 11of the contactor. When an overload device trips, the contactor is called upon to open the circuit. Therefore, 12the contactor should be rated to break the circuit. Under high-impedance fault conditions, the current may 13be in the range of 10 to 17 times the motor full-load current. The instantaneous trip breaker may be set 14above the 10 times full-load current break test value of the contactor. Refer to Figure 4 for the time-current 15curves of a 480 V, 75 kW motor application with a 175 A instantaneous trip breaker, a Class 20 overload, 16and a NEMA size 4 magnetic contactor (i.e., 1350 A break rating). This figure illustrates a case where the 17instantaneous trip is set about 12 times the full-load current of 124 A (see NEC Table 430-150). The #2/0 18AWG XHHW conductor is rated for 175 A at 75 C. The contactor is not protected using the setting of 19about 1500 A. A lower instantaneous setting would protect the contactor, but some motors may trip the 20breaker on starting. Contactors for NEMA Design E motors shall have a horsepower rating not less than 1.4 21times the rating of a motor rated 3 kW through 75 kW, have a rating not less than 1.3 times the rating of the 22motor rated over 75 kW, or be marked for use with a Design E motor (see NEC Article 430-83, Exception 23No. 1).

2 24 3 Copyright © 2010 20112013 IEEE. All rights reserved. 4 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8/D1.12, June, 2010October 2011June 2012February 2013

1 2 Figure 4— Time-current curve for a 480 V, 75 kW motor with size 4 3 contactor, Class 20 overloads, and an instantaneous trip circuit breaker with 4 a setting of 12 times full-load current 5

6In a recently published book, the authors reveal that some high-efficiency motors draw up to 2.83 times 7locked-rotor current during starting, and they recommended a 19.2 times full-load current on the 8instantaneous breaker setting, approximately 3 times locked-rotor current in one case (see Prabhakara, et al. 9[B11]). A typical value used in the industrial applications is 1.76 times locked-rotor current for estimating 10asymmetrical inrush current. To prevent false tripping of the instantaneous trip breaker on starting, several 11options are available:

12 a) Use an autotransformer or other means for reduced voltage starting to limit the inrush 13 current. 14 b) Specify a contactor with a higher break rating and set the instantaneous breaker at a 15 higher setting within the NEC limits. 16 c) Use an inverse-time circuit breaker in place of the instantaneous trip breaker so that the 17 instantaneous setting, if available, can be set above the motor inrush current. 18

197.2 Low-voltage motor ground-fault protection

20Many low-voltage motor applications utilize fuses or MCCBs for ground-fault protection. However, the 21type of protection selected is dependent upon the type of system grounding.

2 25 3 Copyright © 2010 20112013 IEEE. All rights reserved. 4 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8/D1.12, June, 2010October 2011June 2012February 2013

17.2.1 Solidly grounded systems

2Fuses and circuit breakers normally provide adequate ground-fault protection for motors on solidly 3grounded systems. However, for larger motors applications, such as the 75 kW motor shown in Figure 4, 4miscoordination occurs. For example, this motor is protected by an instantaneous only circuit breaker set at 51500 A trip. The main breaker ground trip is set at 1200 A, the maximum allowed by NEC Article 230-95, 6where a shutdown does not introduce additional hazards. Miscoordination can occur in the region between 7the ground trip device on the main low-voltage power circuit breaker (LVPCB) and the instantaneous trip 8circuit breaker protecting the motor. LVPCBs, specified with long-time and short-time functions only (i.e., 9no instantaneous element), can usually be coordinated selectively.

11If selectivity between the individual motor protective device and the main breaker is desired for ground 12faults, additional protective devices should be installed for the larger motors or interlocking ground-fault 13devices should be installed. For solidly grounded systems, the protective devices should be wired to open 14the breaker, not the contactor, unless the contactors are rated high enough to interrupt the available fault 15current. Some breakers have integral solid-state devices that sense ground faults and open the breaker. 16Contactors may also have integral solid-state devices that sense ground faults, but these may open the 17contactor. Also, zero-sequence current transformers (CTs) and trip units can be installed to shunt-trip the 18circuit breakers or switch, provided that the circuit breaker or switch has a shunt trip, which is not 19necessarily included on the circuit breaker or switch unless ordered that way.

20

217.2.2 Low-resistance-grounded systems

22Low-resistance-grounded systems are not normally used on low-voltage applications. For low-resistance- 23grounded systems (e.g., between 200 A to 400 A), ground-fault currents may not be high enough to trip the 24MCCBs or to open fuses in a timely fashion, particularly for larger motors.

267.2.3 High-resistance-grounded systems

27For high-resistance-grounded systems, where the fault current is usually 5 A to 10 A range, no individual 28motor ground-fault protection is generally provided. Instead, an alarm at the grounding resistor signals that 29a ground fault has occurred. A ground pulsed signal is used to locate the fault. The faulted circuit is then 30manually cleared. Caution should be used when selecting conductor insulation materials and ratings for use 31on high-resistance-grounded systems, particularly on smaller conductors (e.g., size 10 AWG and below). 32Zone selective interlock (ZSI) tripping is another type of ground-fault protection that permits the first 33ground fault to be alarmed only, with rapid tripping following a ground fault on a different phase. This trip 34rating illustrates the advantage of high-resistance grounding when operation may continue during the 35presence of the first ground fault. Removal of the first ground fault is important, however, in order to 36prevent escalated damage from a second ground fault on a different phase. The MCCBs used in high- 37resistance-grounded systems should be rated for line-to-line voltage (e.g., 480 V not 480/277 V for a 480 38nominal system voltage). (Also the single-pole interrupting rating should be checked to clear the second 39fault on a different phase: ground as well as line-to-ground faults on two separate phases, one on each side 40of the breaker. See Gregory [B2].)

2 26 3 Copyright © 2010 20112013 IEEE. All rights reserved. 4 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8/D1.12, June, 2010October 2011June 2012February 2013

17.3 Low-voltage motor stator winding over temperature

2The purpose of stator winding over-temperature protection is to detect excessive stator winding temperature 3prior to the occurrence of motor damage. In low-voltage motors in non-critical services, the temperature 4sensors are normally wired to trip the motor control circuit and open the contactor. .

67.3.1 Thermostat winding over-temperature devices

7Thermostats are the most common type of stator temperature sensors installed in three-phase industrial 8service 460 V motors from 11 kW through 150 kW. Many manufacturers wind the stators with the devices 9installed and cut off the leads if a customer does not specify the protection. Thermostat devices are 10bimetallic, normally closed devices (or normally open devices) that operate at one fixed temperature. They 11are normally wired in series with the control circuit at 120 V. These devices are normally sealed from the 12atmosphere, but are not rated as hermetically sealed for hazardous NEC Class 1 Division 2 areas.

137.3.2 Thermistor winding over-temperature devices

14Thermistors are used to operate relays for either alarm or trip functions, or both. They have resistance 15characteristics that are nonlinear with respect to temperature and thus are not used to indicate temperature. 16Two types of thermistors exist:

17 d) Positive temperature coefficient. The resistance of a positive temperature coefficient 18 thermistor increases with temperature. An open circuit in this thermistor appears as a high- 19 temperature condition and operates the relay. This arrangement is fail-safe. 20 e) Negative temperature coefficient. The resistance of a negative temperature coefficient 21 thermistor decreases as temperature increases. An open circuit in this thermistor appears as a low- 22 temperature condition and does not cause relay operation. 23

247.3.3 Resistance temperature detector (RTD) winding over-temperature devices

25RTDs may be considered in larger or critical service low-voltage motors. In those cases, the RTDs are 26usually connected into a device that provides an alarm and/or trip functions. The most common practice is 27to install six RTDs, two per phase, of the 100 Ω platinum elements class B to IEC 60751 for small motors 28and 100Ω platinum element class A to IEC 60751 for large or important motor. More information on RTDs 29is contained in 10.5.3.1.1.

30RTDs are not normally installed in low-voltage motors unless the service is critical. In those cases, the 31RTDs are usually connected into a device that provides an alarm-only function. The most common practice 32is to install six RTDs, two per phase, of the 120 100 Ω platinum elements. More information on RTDs is 33contained in 10.5.3.1.1.

347.4 Low-voltage motor undervoltage protection

35Undervoltage protection is used to protect motors from several damaging conditions: low voltage due to a 36voltage sag, automatic reclosing or automatic transfer, and power restoration. In a voltage sag, the motor 37draws more current than normal and has unusually high heating. Excessive heating can be a serious 38problem in hazardous areas where the motor must stay within its T marking.

2 27 3 Copyright © 2010 20112013 IEEE. All rights reserved. 4 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8/D1.12, June, 2010October 2011June 2012February 2013

1When the supply voltage is switched off during automatic reclosing and transfers, the motors initially 2continue to rotate and retain an internal voltage. This voltage decays with motor speed and internal flux. If 3the system voltage is restored out of phase with a significant motor internal voltage, high inrush can occur. 4Such current can damage the motor windings or produce torques damaging to the shaft, foundation, drive 5coupling, or gears. IEEE Std C37.96-2000 discusses considerations for the probability of damage occurring 6for various motor and system parameters.

7When power is restored after an outage, the starting sequence should be programmed so that all motors on 8the system are not starting simultaneously. This step is important for the generating equipment, as well as 9for transformers and conductors. Undervoltage devices are not normally installed on essential loads such as 10motors for fire pumps.

117.4.1 Undervoltage relays

12Low-voltage undervoltage relays are typically electronic devices that monitor all three phases. These 13devices can be furnished with a time delaydelay to trip, a time delaydelay to restart, or instantaneous for 14trip and restart. Usually, the designer sets the device at 85% percent of line voltage with a time delaydelay 15off and a time delaydelay for restart. Normally, the undervoltage relays are wired into the motor control 16circuit to open the contactor.

177.4.2 Undervoltage sensors for circuit breakers

18Some MCCBs have an undervoltage sensor adapter that trips the circuit breaker on a low-voltage condition. 19The circuit breakers are reset manually. Where automatic restart is necessary, this method should not be 20used. These sensors may not be as reliable as separate undervoltage relays, and this factor should be 21considered when designing the circuit.

228. Medium-voltage motor protection

23< Dan Ransom lead, Jeff Hensley, David Bredhold, Ted Kloba>

24

25< lead, >

26Conventionally, large motors drive the main process equipment and would operate continuously for the 27length of the batch process. However, to accomodateBecause of this infrequentstopping and starting, 28medium-voltage circuit breakers are often used to apply the power to the motors. Medium-voltage motor 29voltage ratings are 2300 V, 4000 V, 4600 V, 6600 V, and 13 200 V per Part 20.12 of NEMA MG 1-1998. 30When a motor must be started frequently, it may might be necessary (even economical) to use motor 31contactors in a combination controller with a current-limiting fuse or circuit breaker because of the greater 32life of the contactors. Use cCare should be exercised when applying fused contactors on solidly grounded 33neutral systems because the contactor is incapable of interrupting high fault currents, especially ground 34faults. As a result, ground-fault relays and differential relays maymight not be applied safely applied. The 35risks could be minimized by having the manufacturer perform short-circuit tests on the combination 36controller to confirm its safe performance to in interrupting the fault on the system to which it is applied. In 37tThis subclause, the text refers to the usinge of circuit breakers for the main device to both close and open 38the motor circuit. The Ttext describing combination controllers for medium-voltage motors is generally 39similar to low-voltage combination controllers discussed previously.

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1In principle, the protection of medium-voltage motors is similar to low-voltage motors, but the 2requirements are more demanding. Being closer to the utility source, medium-voltage motors are more 3susceptible to voltage sags and surges, reclosing, and higher available fault levels. Because of the higher 4bus voltage and load currents, instrument transformers are used to reduce these currents to lower values, 5which can be used with protective relays, described in Chapter 4. The most common instrument 6transformer secondary ratings are 120 V (line-to-line) for voltage transformers (VTs), and 5 A for CTs, 7described in Chapter 3. The circuit breakers [i.e., air, sulfur hexafluoride (SF6), vacuum], instrument 8transformers, and protective relays are mounted in switchgear.

98.1 Medium-voltage motor thermal overload protection

10Motors and synchronous machines develop heat while running. Monitoring heating, air and water flow, 11ambient air conditions, temporary overloads, intake air plenum damper positions is important. Also using 12an accurate model of the motor heating (using equivalent motor current) yields benefits in using the motor 13to maximum effect without damage.

14Thermal protection of a motor is vital to motor longevity. Older motor protection methods used overcurrent 1550 and 51 elements instead of the 49 thermal model (Device 49TC) and had no backup resistance 16temperature detector (RTD) temperature devices (49). Comparing these two methods of motor protection 17(Device 50/51 and Device 49TC), demonstrates the benefits of the Device 49TC thermal model for motor 18protection versus using an overcurrent method. Note that compromises must be made when employing 19overcurrent protection because typical 50/51 element curves do not match motor damage curves and do not 20take negative-sequence current effects into account.

21A motor thermal model uses an “equivalent current,” Ieq, calculation that best represents the actual motor 22flux dynamics. This equivalent motor current accounts for the heating effects of negative-sequence and 23other currents present in induction motor applications.

24The result of using thermal overload protection is extended motor life, and more efficient usage of motor 25capabilities. Figure 5 shows a set of typical motor operational curves for starting (accelerating) and for 26running (see IEEE Guide for the Presentation of Thermal Limit Curves for Squirrel Cage Induction 27Machines, IEEE Standard 620-1996, for an explanation of the construction of this chart). With Device 2849TC protection, an engineer can place the motor-protection curve directly underneath the starting and 29running damage curves; replicating the exact shape of the damage curve without compromise and overlaps. 30Thermal overload protection using the Device 49TC element is a better method for protecting medium- 31voltage motors than is simple overcurrent protection.

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1

2 Figure 5 – Typical Motor Curves 3High-inertia motors take a much longer time to accelerate, and without proper protection, this long 4acceleration time could lead to nuisance tripping. In addition, a low-voltage condition can also lead to a 5longer accelerating time, thus requiring careful selection of the type of protection relays and settings. A 6good practice for these motors is to request motor acceleration curves that are plotted for the cases of 100 7percent and 80 percent of actual motor-starting voltage. At section 8.2.1, other techniques are shown on 8methods for high-inertia protection. In some cases, protective relaying might not adequately solve the 9problem, and a turning gear motor has been applied to start the large inertia motor in at least one case. This 10latter concept is expensive and is not a recommendation.

11High-inertia motors (pumps and large fans) require modifications of the thermal overload protection curve. 12Newer motor protection relays offer this capability. An engineer can configure the overload protection 13curve to include extended starting times and currents, thus preventing false trips upon starting these 14devices.

158.2 Medium-voltage motor overcurrent protection

16

18In Figure 6 , Figure 7, and Figure 8, illustrate some additional techniques for illustrate differentother 19approaches applied forto large- motors protection. The accelerating curve has isbeen shown slightly 20differently in each case to demonstrate that no one single curve is accepted as a standard. T, and the motor 21accelerating curve should be provided by the motor or equipment supplier before setting the relays. High- 22inertia motors often take a much longer time to accelerate and, without proper protection, could lead to

2 30 3 Copyright © 2010 20112013 IEEE. All rights reserved. 4 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8/D1.12, June, 2010October 2011June 2012February 2013

1nuisance tripping. In addition, a low-voltage condition can also lead to a longer accelerating time, thus 2necessitating careful selection of the type of overcurrent relays and their settings. A good practice for these 3motors is to request motor acceleration curves that are plotted for the cases of 100% and 80% actual motor 4starting voltages. Under 10.58.2.1, some techniques are shown on how to resolve this protection. In some 5cases, relaying may not adequately solve the problem, and a turning gear motor has been applied to start the 6large inertia motor in at least one case. This latter concept is expensive and is not a recommendation.

7In Figure 65, a NEMA Design- A or Design- B motor curve is shown with protection for starting and 8running easily made using a Device 51, a time-overcurrent relay element with inverse or very inverse 9characteristics. Within the overcurrent relay is a second element, a Device 50, which operates without delay 10to protect against a short circuit. Normally three overcurrent relays elements are used, each phase 11relayelement supplied from its owna separate CT. Some designers use only two of the three relays for 12overcurrent protection, and set Device 51 of the third relay relatively low (i.e., 110% percent to 120% 13percent of the full-load current) to alarm on an overload overcurent condition. Codes may not permit this 14practice in some cases, and redundancy is lost during relay testing. In this latter scheme, the two protective 15phase relays could be set for extreme overcurrent conditions at 125% percent to 140% percent of the full- 16load current.

17 18 Figure 6— Conventional overcurrent motor protection of motor 19

20In Figure 67, protection for a high-inertiahigh-inertia motor allows for the longer accelerating time. 21Whereas Aa conventional motor reaches rated speed within 10 s to 15 s; , a high-inertiahigh-inertia motor 22maymight take 30 s to 40 sor longer (Ffor example, centrifuges maycan take about 40 minutes to reach 23rated speed; when starting wye/delta). As a result, little time difference exists between the accelerating 24current curve and the motor thermal limits. Several approaches are available, as shown in Figure 6 7 and 25Figure 78, and an impedance (Device 21) method is shown in Figure 8 9. In Figure 6 , Device 51 has long- 26time inverse or very- inverse characteristics, set above the accelerating current. (Definite- time delaydelay 27is another term to describe this element.) Device 50 (HDO) is a high- dropout (HDO) element that rapidly 28resets rapidly when the starting current drops to a magnitude of 85% percent to 90% percent of the set 29current without delay. For starting, a time delay of less than 1 s occurs is neededin order to permit the 30Device 50 (HDO) to be set atsetting at 1.15 p.u. of locked-rotor current (LRC or LRA). This delay prevents

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1false trips due tocaused by the asymmetrical starting currents, yet provides short-circuit protection after the 2time delay. A second Device 50 element is set at approximately two times the locked-rotor current to 3protect against short circuits during starting.

4 5 Figure 7— Protection of high-inertia motor 6

7Figure 7 illustrates a second method for protecting a high-inertia motor. This approach also uses two 8Device 50 elements per phase. The conventional Device 50 is set in the normal way to protect against short 9circuits. The second Device 50 is used in conjunction with the a Device 51 overcurrent element to block 10tripping by the Device 51 for overcurrent conditionss below the Device 50 setting. This scheme offers an 11overload overcurrent alarm, while allowing the motor to continue operating unless the actual overcurrent 12exceeds a high setting. The use of this scheme is dependent upon the operating philosophy of the facility. 13Large motors should be specified with thermistors or RTDs buried in their windings for high-temperature 14backup detection. Note that, although temperature changes are generally slower to develop than 15overcurrent and thermal overload increases. Actual faults within the windings would be detected faster by 16thermal overload (Device 49TC), overcurrent differential relay protection (Device 87), andor a sensitive 17ground-fault current (Device 51N) relay protection schemes.

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1

2 3

4 A — ALLOWABLE HEATING CURVE 5 B — STARTING CURRENT 6 C — 51 — LONG TIME OC 7 D — DEFINITE TIME SET 120% percent FL 8 E — INVERSE INST 50

9 Figure 8— Alternate method of protecting a high-inertia motor 10

11Figure 8 9 represents shows a scheme that relies upon the characteristics of an Device 21 (i.e., impedance 12distance (Device 21) relay) to permit tripping if the high-inertia motor does not accelerate to a certain speed 13within a fixed period. Upon energization of the motor circuit energization, the locked-rotor current is 14primarily inductive, as because a blocked motor could easily be considered a transformer with shorted 15secondary windings. As the motor accelerates,, the current decreases from a subtransient to a transient 16value, and the power factor and measured impedance increase. Used in conjunctionAlso used with the 17Device 21 is are either an overcurrent relay (Device 51), or an overvoltage relay (Device 59) that, which 18operates as a timing device in this case. This scheme guards against a stalled motor. O although other 19schemes exist, such as zero-speed devices used with timers (Device 48). Figure 9 10 illustrates how the 20locked-rotor protection functions below the safe stall time.

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Device 21

1 2 Figure 9— Protection of high-inertia motor using an impedance relay 3

4 5 Figure 10 — Schematic of locked-rotor protection of Figure 8 6

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18.3 Fault protection

28.3.1 Motor overcurrent differential relay (Device 87)

3Motor overcurrent differential protection measures the current flow into a load and compares it to the 4current measured on the neutral side of the motor; for normal operation the current going in and the current 5going out match and cancel. A current difference is detected as a fault. These schemes can be technically 6applied to any motor load, but often are applied only to large or critical motors only where damage could 7be costly or replacement difficult. By detecting faults at a low level, damage maycan be confined solely to 8the windings solely. Three general recommendations forGenerally, applyying differential overcurrent 9protection are as follows:

10 a) With all motors 750 kW (1000 hp) and above larger used on ungrounded systems. 11 b) With all motors 750 kW (1000 hp) and above larger used on grounded systems where the 12 ground-fault protection applied is not considered sufficient without differential protection to 13 protect against phase-to-phase faults. 14 c) With smaller motors, especially at voltages above larger than 2400 V 15 d) , although justifying differential protection for large motors (i.e., 1900 kW (2500 hp) and 16 abovelarger); justification is easier. 17

188.3.1.1 Conventional phase differential overcurrent relay

19A conventional phase- differential overcurrent relay is used to senses low-level phase faults and to quickly 20removes the motorelectric circuit power quickly before extensive motor damage develops. This scheme 21uses six identical CTs (i.e., one pair for each phase) and three relays (i.e., one per phase). The CTs should 22be sized to carry full-load current continuously and to not saturate during an external or internal fault (see 23Figure 10). The currents from each pair of CTs circulate through the relay-restraining windings under 24normal (i.e., no-fault) conditions. For a fault in the motor windings or in the cable, the CT secondary 25currents have different magnitudes and/or polarities, and the differential current from each CT adds to the 26other and operates the Device 87 to trip the motor circuit breaker. While sometimes applied toThis scheme 27is employed for both delta-connected motors, this scheme is usually used with and for wye-connected 28motors. (W. ye-connected motors are much more common than delta-connected ones in the larger 29horsepower ratings.) With the wye-connected motor, three of the CTs are normally located at the starter (or 30motor switchgear) and the other three in the three phases at the motor winding neutral.

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1 2 Figure 11 — Conventional phase differential protection using three (3) 3 percentage differential relays

48.3.1.2 Self-balancing differential using window CTs

5Three window (or toroidal) CTs are normally installed at the motor. One CT per phase is used, with the 6motor line, and neutral leads of one phase are passed through the CTit so that the flux from the two currents 7normally cancels each other in the CT. A winding phase-to-phase or phase-to-ground fault results in an 8output from the CTs of the associated phases. That current operates the associated relays elements (see 9Figure 1112).

10 11 Figure 12 — Self-balancing differential protection (one relay element shown) 12

13Normally in one relay package, The the Device 87 CTs and relayelements would normally be the same as 14the CTs and relays used for zero-sequence instantaneous ground overcurrent protection (see 10.5.2.3.2) 15with the relay set between 0.25 A and 1.0 A pickup. Therefore, this differential scheme usually has a lower 16primary pickup in amperes than the conventional differential scheme because the CT ratio is usually greater 17with the conventional scheme. This differential scheme has a slight advantage over the scheme in Figure 10 18in detecting ground faults. For motors installed on grounded systems this difference is significant because 19most faults begin as ground faults. The usual objective of motor-fault protection is to remove the fault 20before the stator iron is significantly damaged significantly.

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1Application problems have occurred with this scheme when the available fault current is very high and 2when high-speed, balanced-core differential protection signals to tripping the motor starter before the 3current-limiting fuses clear the fault (and thus protecting the starter). Because the starter has such a low 4fault rating, some engineers have slowed down the operation of the relay, by delay or a different relay type, 5in order to distinguish between a developing low-level fault and a direct short.

6With the CTs located at the motor, this scheme does not detect a fault in the cables supplying power to the 7motor. Normally, a fault in these cables would normally be detected by the overcurrent protection. For 8large motors, coordinating the supply phase-overcurrent protection with the motor thermal overcurrent 9overload and overcurrent protection is often a problem. The presence of motor differential protection is 10sometimes considered to make this coordination less essential. In this regard, the conventional current 11differential is better than the self-balancingself-balancing flux flux differential because the motor cables are 12also included in the differential protection zone. Hence coordination between the motor differential and 13supply phase-overcurrent relays is complete.

14As with zero-sequence ground-fault overcurrent protection, testing the overall CT and relay combinations 15is important during commissioning. Current in a test conductor should be passed through the window of 16each CT. Because normally the relays do not carry current, an open circuit in a CT secondary or wiring to a 17relay can be discovered by this overall testing.

188.3.2 Split winding current unbalance (Device 87)

198.3.2.1 Purpose

20The purpose of the split- winding current unbalance device is to quickly detect quickly a low-magnitude 21fault conditions. This protection also serves as backup to instantaneous phase-overcurrent and ground-fault 22overcurrent protection. Normally, tThis protection is normally only applied only to motors having two (or 23three) winding paths in parallel per phase (see Figure 12). <(Ddo not useconfuse this arrangement with 24partial- on part-winding starting, discussed elsewhere.) applications>

25 26 Figure 13 — Split-phase winding motor overcurrent protection used with 27 two paths windings per phase (one relay shown)

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18.3.2.2 Arrangement of CTs and relays

2

3The usual application is with a motor having two or more winding paths in parallel per phase. The six line 4leads (i.e., two per phase) of the motor are brought out, and one CT is connected in each of the six leads. 5Choose tThe primary current rating of the CTs should be chosen to carry full-load current (FLC or FLA).

6The CTs may can be installed at the motor. It maymight be convenient, however, to use six cables to 7connect the motor to its the starter (or switchgear), and in this case the CTs can be located in the starter.

8The currents from each pair of CTs, associated with the same phase, are subtracted, and their difference is 9fed to a short-time inverse-e time -overcurrent relay. Three of these relays are required (i.e., one per phase), 10and each is set at 1.0 time dial and between 0.5 A and 2.5 A. The relay should be set above the maximum 11current unbalance that can occur between the two parallel windings for any motor-loading condition.

128.3.2.3 Evaluation of split windingsplit-winding current unbalance protection

13The following factors should be considered when evaluating split- winding current unbalance protection:

14 a) Total cost would be somewhat less than conventional phase current differential and more 15 than self-balancingself-balancing flux differential. 16 b) The primary pickup current for this protection would be about half of the primary pickup 17 current of conventional phase differential because both schemes require the CT primaries to be 18 rated to carry normal load currents. Self-balancing differential would usually have a lower primary 19 pickup (in amperes). 20 c) This protection has a slight time delaydelay compared to the phase current differential 21 schemes. 22 d) When the CTs are located in the motor starter, split- winding protection has the same 23 advantage over self-balancingself-balancing flux differential as does conventional phasecurrent 24 differential, namely, it detects a fault in the motor cables and may facilitates coordination with the 25 supply feeder overcurrent relays (see 10.5.2.1.2). 26 e) The salientA feature that of this protection provides, and no other motor protection has, 27 is the ability to sense short-circuited winding turns. The number of turns that must be short- 28 circuited before detection occurs depends upon the motor winding arrangement, the relay pickup, 29 and CT ratio. An analysis of the specific motor winding would be required to determine the 30 worthiness of this feature. Short-circuited turns could cause a ground fault, which could be 31 detected by the self-balancingself-balancing flux differential scheme before this split- winding 32 protection would sense the short-circuited turns condition. 33 f) This protection could be applied to a motor with four winding paths in parallel per phase 34 by grouping them these as two pairs as if only two paths in parallel existed (i.e., six CTs and three 35 relays are used). 36 g) Often, aA split differential scheme is can be often effective ly used where one CT is in 37 one of the parallel paths and the other CT sees the total phase current. 38

398.3.2.4 Application of split- winding protection

40Split winding protection is rarely used rarely, but is feasible to apply tofor important motors rated above 41greater than 3700 kW that have two or four winding paths in parallel per phase.

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18.3.3 Ground-fault protection

28.3.3.1 Purpose

3The purpose of ground-fault protection is to protect motors by detecting ground-fault conditions with no 4intentional delay and to be certain that the unbalance current represents a true ground fault (i.e., not current 5fromdue to asymmetry in the primary current, or and currents fromto CT saturation). Following this 6detectionUpon detecting a ground fault, the protection maymight trip the motor circuit or only alarm, 7depending upon the voltage and facility operating practice.

88.3.3.2 Instantaneous ground-fault protection

9Using a zero-sequence (or window) flux CT that has been designed for instantaneous ground-fault 10protection and tested with a specific ground-fault relay is recommended (see Figure 1314). For medium- 11voltage applications, the power system should be resistance-groundedhigh-impedance grounded, or hybrid 12grounded. , and tThe Device 50G element should be set to operate for a primary ground-fault current in the 13range of 10 A to 30 A. A suitable time delaydelay should be added when the installation has surge 14protection on the motors.

15 16 Figure 14 — Ground fault overcurrent protection using a window (flux) CT

178.3.3.3 Time-overcurrent ground-fault protection

18Many installations have surge protection at the motor terminals, and a surge discharge through an arrester 19could cause an instantaneous relay element to have a false trip. To avoid this event, a Device 51G should be 20applied, in place of the Device 50G in Figure 13, and set to trip within a few cycles to seconds of the fault- 21sensing pickup.

228.3.3.4 Installation of cable for ground-fault protection

23The following precautions should be observed in applying the relay and zero-sequence CT and in installing 24the cables through the CT:

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1 h) If the cable passes through the CT window and terminates in a pothead on the source side 2 of the CT, the pothead should be mounted on a bracket insulated from ground. Then the pothead 3 should be grounded by passing a ground conductor through the CT window and connecting it to 4 the pothead. 5 i) If metal-covered cable passes through the CT window, the metal covering should be kept 6 on the source side of the CT, insulated from ground. The terminator for the metal covering 7 maymight be grounded by passing a ground conductor through the CT window and then 8 connecting it to the terminator. 9 j) Cable shields should be grounded by passing a ground conductor through the CT window 10 and then connecting it to the shields. 11 k) The overall CT and ground relay scheme should be tested by passing current in a test 12 conductor through the CT window. Because normally no current exists in the relay, an open circuit 13 in the CT secondary or wiring to the relay can be discovered by this overall test. 14

158.3.3.5 Residually connected CTs and ground-fault relay

16Applications have been made using the residual connection from three CTs (i.e., one per phase) to supply 17the relay. This arrangement is not ideal because high large phase currents (e.g., due tofrom motor starting 18inrush or phase faults) maymight cause unequal saturation of the CTs and produce a false residual current. 19As a result, undesired tripping of the ground relay maycan occur, and the production or process may could 20be jeopardized. For this reason, a Device 50N is not recommended in the residual connection. A Device 2151N installed in the residual connection would be more appropriate for these installations.

22

238.3.3.6 Selection of resistor for low-resistance system grounding

24The purpose of resistance grounding is to provide current sufficient for protective relays to operate upon 25detection of a ground fault, but low sufficiently smallenough to limit the magnitude and resulting damage 26to the motor. (In mine distribution systems, the objective is to limit equipment-frame-to-earth voltages for 27safety reasons.) However, the ground-fault current should not be so limited small that the windings near the 28neutral end are unprotected. In the past, protection within 5% percent to 10% percent of the neutral has 29often been considered adequate. Selection of the ground resistor should also consider the number of steps in 30ground-fault overcurrent protection coordination (see Love [B5] and [B6]). On this basis, the ground 31resistor chosen for the system neutral grounding normally limits the ground-fault current within the range 32of 400 A to 2000 A. However, some companies prefer neutral ground-fault current limited to 200 A to 800 33A; this difference emphasizes the need to coordinate the protection of a system. A 10- s time rating is 34usually chosen for the resistor.

35To avoid excessive transient overvoltages, the resistor should be chosen so that the following zero- 36sequence impedance ratio is achieved:

37R0 / X0 should be equal to or greater than 2.

38A more detailed discussion of the selection of the resistor can be found in Chapter 8.

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18.4 Monitors

2In addition to protection against failures due tocaused by electrical causesabnormalities, advances in 3instrumentation and techniques have enabled protective methods that monitor machinery characteristics 4and, as a result, can detect trends of equipment failures during the incipient stage. This development has 5manifested into monitors, sensors, and detectors that use inputs not related directly to measured electrical 6quantities of voltage and current.

78.4.1 Stator winding over temperature

8The purpose of stator winding over-temperature protection is to detect excessive stator winding 9temperatures prior to the occurrence of motor damage. Often, tThis protection is often arranged just to 10alarm on motors operated with competent supervision. Sometimes two temperature settings are used, the 11lower setting for alarm, the higher setting to trip. The trip setting will depends on the type of winding 12insulation used for its winding and on the user operating requirements of the user.

13

148.4.2 RTDs

15Six RTDs (two per phase) should be specified in motors rated 370 kW (500 hp) and above. These devicesy 16are installed in the winding slots when the motor is being wound. The six RTDs are spaced around the 17circumference of the motor core to monitor all phases. The most commonly used type is three-lead, 120 18100- Ω platinum for Class B to IEC 60751 for small motors, and 10-0Ω platinum element Class A to IEC 1960751 for large orand critical motors with three leads. A four- lead RTD is used shouldfor applications that 20require higher accuracy. The RTD element device resistance increases with temperature, and a Wheatstone 21bridge devices or similar circuitry isare used to provide temperature indication or and contact output 22operation, or both. . The value of the temperature trip will depends on the type of winding insulation used 23(see Table 1) and the operating requirements of the user..

24

25For safety, RTDs should be grounded, and that ground in turn places a ground on the Wheatstone bridge 26control module. Therefore, the Wheatstone bridge control module should not be operated directly from a 27switchgear dc battery because these dc control schemes should normally operate ungrounded in order to 28achieve maximum reliability. However, loss of ac control voltage due tocaused by a blown fuse could 29remove protection, unless the null point is near the trip setting at which time it could cause tripping.

30An open RTD or its an open RTD circuit appears as an infinite resistance and causes a false trip because 31this corresponds to a very high temperature. Newer motor protection relays use RTD voting to prevent the 32threat of a false temperature reading (and subsequent false alarms and false tripping). To indicate an 33excess-temperature condition, the relay must receive sufficient high-temperature indications from multiple 34RTDs (the number of RTD votes is configurable). In this way damaged and open-circuit RTD inputs are 35ignored.

36The following arrangements of RTDs are frequently used frequently:

37 a) Monitor all six leads continuously with alarm points and time-delayed, higher elevated 38 trip points using one monitor or a programmable logic controller. 39 b) Monitor six leads with alarm points and have a manual trip.

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1 c) Configure alarm points and trip points for selected sectors of the motor section. 2 Determine which detector normally runs hottest and permanently connect a trip relay to it. Use one 3 temperature indicator and a selector switch to manually monitor the other five detectors. 4 d) Use a selector switch and combination indicator and alarm relayelements. (Precaution: 5 An open circuit in the switch contact will cause a false trip. Bridging contacts are required.) 6 e) Use a selector switch and an indicator only. 7 f) Use one, two, or three (i.e., one per phase) alarm relays; and use one, two, or three (i.e., 8 one per phase) trip relays set at a higher temperature. 9 10

118.4.2.1 Thermocouples

12Thermocouples are used to indicate temperatures for alarm and trip functions, in a similar manner to RTDs. 13However, an open circuit in the thermocouple leads does not cause a trip because the output appears as a 14low-temperature condition. It is advisable to use thermocouple of Tolerance Class 1 for high accuracy in a 15large motor. ShouldIf the transmitter/transducer for the temperature is not head mounted or located < 0.5m 16from the thermocouple terminal lead, then it should be connected with a suitable thermocouple extension 17cable to the transmitter/transducer. For safety, similar to the As per RTDs, for safety the thermocouple must 18be ofhave a grounded junction. In usual caseUsually, the grounding of the thermocouple grounding is done 19on the sheath at the terminal box. Thermocouple outputs from thermocouples isare compatible with 20conventional temperature-monitoring and data-logging schemes, and newer relays have (4–20 mA and 0– 2110 V) analog inputs for inputting thermocouple data via the proper interface..

22 23 Limit or Errors ASTM E230- ANSI MC 96.1

24 Table 1 –Temperature classifications for wire insulation

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18.4.2.2 Thermistors

2Thermistors are used to operate relays for alarm or trip functions, or both. They These devices are not used 3to provide temperature indication. However, they thermistors are often combined with thermocouples, 4which provide indication, while the thermistor operates a relatively inexpensive relay. See 10.4.3.2 for 5further details.

68.4.2.3 Thermostats and temperature bulbs

7Thermostats and temperature bulbs are used on some motors. For instance, thermostats are bimetallic 8elements and are used on random- wound motors (460- V class, not medium-voltage motors) to detect 9failure to start. They These are embedded in the end windings and provide a contact opening to trip the 10motor. Bulb temperature devices are used to provide measurement and trip contacts for bearing oil 11temperature in oil-lubricated bearings. See 10.4.3.1 for further details.

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1

28.4.2.4 Application of stator winding temperature protection

3Stator winding temperature protection is commonly specified on for all motors rated 190 kW (250 hp) and 4abovegreater. RTDs are commonly specified in for all motors rated 370 kW (500 hp) and abovegreater. In 5the following situations, the application ofapplying stator winding temperature protection should be 6considered:

7 a) Motors in high ambient temperatures or at high altitudes 8 b) Motors whose with ventilation systems that tend to become dirty and lose cooling 9 effectiveness 10 c) Motors subject to periodic overloading due tocaused by load characteristics of the drive 11 or the process 12 d) Motors likely to be subjected to continuous overloading (within their service- factor 13 range) in order to increase production 14 e) Motors for whichused in critical continuity of service applications is critical 15 f) Motors supplied from ASDs (adjustable speed drives) 16 g) Motors in hazardous (classified) locations 17

188.4.3 Rotor over temperature

198.4.3.1 Synchronous motors

20

21Rotor winding over-temperature protection is available for brush synchronous motors, but although, 22normally, this protection is not normally used. One well-known approach is to use a Kelvin bridge chart 23recorder with contacts adjustable to the temperature settings desired. The Kelvin bridge uses field voltage 24and field current (from a shunt) as inputs and measures the field resistance in order to determine the field 25winding temperature.

268.4.3.2 Wound-rotor induction motor-starting resistors

27

28Some form of temperature protection should be applied for wound-rotor induction motor-starting resistors 29on motors having severe starting requirements, such as long acceleration intervals or frequent starting. 30RTDs and other types of temperature sensors have can been used, placed in proximity to the resistors.

2 44 3 Copyright © 2010 20112013 IEEE. All rights reserved. 4 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8/D1.12, June, 2010October 2011June 2012February 2013

18.4.4 Mechanical and other protection

28.4.4.1 Motor bearing and lubricating systems

3Various types of temperature sensors are used on sleeve bearings to detect overheating: , such as RTDs, 4thermocouples, thermistors, thermostats, and temperature bulbs. Excessive bearing temperature maymight 5not be detected soon enoughin time to prevent bearing damage. More serious mechanical damage to the 6rotor and stator may can be prevented by tripping the motor before complete bearing failure. Thus, for 7maximum effectiveness, the following steps are recommended:

8 a) Use a fast-responding temperature sensor (not an RTD). 9 b) Locate the temperature sensor in contact with the bearing metal where it is close to the 10 source of overheating. 11 c) Use the temperature sensor for tripping instead of alarm; for some installations, use both 12 alarm and trip sensors, the former having a lower temperature setting. 13 d) Provide alarm and trip devices on bearing lubricating systems to monitor the following: 14 1) Lubricating oil temperature, preferably from each bearing 15 2) Bearing cooling water temperature, both temperature in and out 16 3) Bearing lubricating oil flow and cooling water flow 17 18In lieu of the flow-monitoring recommended in Item d) 3), often a suitable arrangement of pressure 19switches is often used. However, flow monitoring is strongly recommended for important or high-speed 20machines.

21Temperature sensors generally cannot detect impending failure of ball bearings andor roller bearings soon 22in timeenough to be effective. Vibration monitors and detectors should be considered (see 10.5.3.4).

23Protection to that detects currents that maymight cause bearing damage should be considered for motors 24having insulated bearings. Recent research in vibration rotor-bar heating has discovered that these 25conditions exhibit discernible signatures (usually in the frequency domain). Specialized equipment detects 26this effect, and is used on large and critical-application motors.

288.4.4.2 Ventilation and cooling systems

29Alarm and trip devices should be considered, as follows:

30 a) In motor ventilation systems 31 1) To detect high differential pressure drop across air filters 32 2) To detect loss of air flow from external blowers (In lieu of air flow monitoring, a suitable 33 arrangement of pressure switches is often used; however, flow monitoring is preferable.) 34 b) With water-cooled motors, to monitor water temperature, flow, or and pressure 35 c) With inert-gas-cooled motors, to sense pressure and temperature 36 d) For motors in hazardous areas, to detect flammable gasses and vapors gas 37

2 45 3 Copyright © 2010 20112013 IEEE. All rights reserved. 4 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8/D1.12, June, 2010October 2011June 2012February 2013

18.4.4.3 Liquid detectors

2On large machines, liquid detectors are sometimes provided to detect liquid (usually water) inside the stator 3frame, e.g., because of a leak in the air cooler of a totally enclosed water- and air-cooled motor.

48.4.4.4 Fire detection and protection

5For fire detection and protection, the following items should be considered:

6 a) Installation of suitable smoke and flame detectors to alert operators to use suitable 7 portable fire extinguishers. 8 b) Installation of suitable smoke and flame detectors and an automatic system to apply 9 carbon dioxide or other suppressant into the motor. Some old, large motors have internal piping to 10 apply water for fire extinguishing. Possible false release of the water is a serious disadvantage. 11 c) Use of synthetic lubricating oil that does not burn, particularly for drives having large 12 lubricating systems and reservoirs and for systems in hazardous atmospheres. Lubricating systems 13 of gas compressors or hydrocarbon pumps should be kept separate from the motor to preclude 14 combustibles and flammables from entering the motor through the oil system. 15

168.4.4.5 Partial discharge detectors

17Partial discharge detectors are embedded in the windings. They These detectors show a pattern of 18frequencies that are normal for a motor. Abnormal patterns of corona indicate insulation damage. These 19detectors are normallyshould be considered for installed on large motors (>7500 kW) 4000 V and above, 20particularly used for motors in critical service.

21[

228.4.5 Vibration monitors and sensors

238.4.5.1 Purpose of vibration monitoring

24[update this section, get copyright releases; add NEMA tables]

25Vibration monitoring has advanced from an important startup function to an effective tool during operation 26of the process. It increases safety and reliability and maymight reduce costs over the life of the plant. The 27three components of a vibration monitoring system are transducers, monitors, and machine diagnostic 28equipment, although many installations maymight not have permanent monitors and diagnostic systems 29(see Figure 1415).

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1 2 Figure 15 — Vibration monitoring system

38.4.5.2 Transducers

4Transducers are a critical part of a vibration monitoring system. Accurate machinery diagnostics depend 5upon reliable transducer signals. Two orthogonal, or XY, transducers should be installed at or near each 6bearing; and a phase reference probe, such as a once-per-turn event probe, should be installed on each 7shaft. This configuration provides diagnostic equipment with the information necessary to accurately 8indicate accurately the vibratory motion. Transducers should be of rugged construction to better withstand 9the motor’s environment. In general, if rotor-related malfunctions are anticipated (e.g., unbalance, 10misalignment, rubbings), vibration transducers that observe the rotor should are be preferred. If housing- 11related malfunctions are anticipated (e.g., piping strains, structural resonances), transducers mounted on the 12machine housing should are be preferred.

138.4.5.3 Proximity transducers

14On motors with fluid-film bearings, such as sleeve bearings, non-contacting proximity transducers (see 15Figure 1516) provide the best information data and should be preferredare preferred. Often on these motors, 16much of the rotor motion is not transmitted to the housing. Non-contacting proximity transducers 17accurately indicate accurately the displacement of the rotor displacement relative to the housing. They 18These transducers have a broad frequency response, down to dc (i.e., 0 Hz) at the low end. The upper- end 19frequency response is also high great (up to 10 kHz), but useful application at high frequencies is limited 20because little measurable displacement occurs at these high frequencies. This Proximity transducers can 21measure slow-roll and the shaft’s average position within the bearing. For motors with rolling-element 22bearings, a special transducer can be applied to provide an earlier warning of bearing malfunctions than 23provided by velocity transducers or accelerometers provide. Such motors have a high-gain, low-noise eddy- 24current proximity transducer that is installed in the bearing housing to observe the bearing outer race. Such 25These transducers maymight be difficult to install in motors with tight clearances. See Figure 16 17 for a 26vibration- limit curve.

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1 2 Figure 16 — Typical proximity transducers 3

4 5 Reprinted with permission API. . . 6 NOTES: 7 1) [INSERT] 8 2) [INSERT] 9 3) [INSERT]

10 Figure 17 — Shaft vibration limits (relative to bearing housing using 11 non-contact vibration probes): for all hydrodynamic sleeve-bearing motors; 12 with the motor securely fastened to a massive foundation

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18.4.5.3.1 Velocity transducers

2Velocity transducers may can be used on motors with rolling-element bearings where virtually all of the 3shaft motion is faithfully transmitted to the bearing housing. Velocity transducers are seismic devices that 4measure motion relative to free space; these transducers, are useful for overall vibration measurement, and 5provide good frequency response in the mid-frequency range (i.e., 4.5 Hz to 1 kHz). This transducer is self- 6generating; no power source is required. Traditional velocity transducers are mechanical devices that suffer 7from a limited life span. Some modern velocity transducers use a piezoelectric sensing element; these 8tranducers, do not suffer fromhave a limited life span this limitation, and are thus preferred. See Figure 17 9for a vibration- limit curve.

10 11 Reprinted with permission . . . 12 NOTES: 13 1) [INSERT] 14 2) [INSERT] 15 3) [INSERT]

16 Figure 18 — Bearing housing vibration limits: for sleeve and antifriction 17 bearing motors; with the motor securely fastened to a massive foundation 18

198.4.5.3.2 Accelerometers

20Accelerometers are generally used on motors with rolling-element bearings where virtually all of the shaft 21motion is transmitted to the bearing housing. Accelerometers are useful for overall vibration measurements 22and have a broad frequency response. They These devices are particularly useful particularly for high-

2 49 3 Copyright © 2010 20112013 IEEE. All rights reserved. 4 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8/D1.12, June, 2010October 2011June 2012February 2013

1frequency measurements. An accelerometer is almost the only viable transducer at high frequencies 2(usually above greater than 5 kHz). Motor vibration acceleration increases with frequency. Therefore, the 3acceleration unit of measurement is favoredpreferred. However, at low frequencies, its the accelerometer 4usefulness is limited. Accelerometers are sensitive to the method of attachment and the quality of the 5mounting surface.

68.4.5.3.3 Vibration limits

7API Std 541-1995 recommends limits for shaft and bearing vibrations, using non-contact vibration probes 8on hydrodynamic bearing motors operating at speeds equal to or greater than 1200 r/min. Examples of 9these limits are shown in Figure 16 17 and Figure 17 18 from API Std 541-1995.

118.4.5.4 Monitors

128.4.5.4.1 Monitors process and display transducer signals

13Monitors should detect malfunctions in the transducer system and the transducer power supply. These 14devicesy should provide two levels of alarms, and protect against false alarms. They Monitors should be 15constructed so that both the unprocessed and processed information is available to online and portable 16diagnostic equipment. Monitors designed to work with accelerometers or velocity transducers should be 17able to integrate the signal. Modern motor relays have incorporated many of the monitoring functions. See 18Figure 198 for sample monitoring system panels.

19 20Reprinted with permission . . .

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1 Figure 19 — Monitoring system panels 2

38.4.5.4.2 Continuous monitors

4Motors that are critical to a process should be instrumented with continuous monitors, in which each 5monitor channel is dedicated to a single transducer. These monitors have the fastest response time and 6provide the highest level of motor protection.

78.4.5.4.3 Periodic monitors

8General- purpose motors can be instrumented with periodic monitors, in which each monitor channel is 9time-shared among many transducers. Consequently, the response time is slower than the continuous 10monitor.

118.4.5.4.4 Portable monitors

12These Portable monitors are widely used widely, primarily when a permanent monitoring system has not 13been justified. Often, tThese devicesy are often used with infrared scanners, which to determine whether 14bearings are overheating. The results are suitable for trending in condition-based maintenance programs. 15Other types of portable monitors include ultrasonic probes as a part of their a maintenance programs.

168.4.5.5 Diagnostic systems

178.4.5.5.1 Purpose of diagnostic systems

18A diagnostic system is essential to effective machinery management. Being computerizedUsing computing 19technology, the system processes the data provided by the transducers and monitors into information that 20can be used to make decisions regarding motor operation. A diagnostic system should be capable of 21simultaneously processing the data from two orthogonal transducers simultaneously, along withand a once- 22per-turn reference probe. It should display data in several plot formats, including orbit, time base, Bode, 23polar, shaft centerline, trend, spectrum, and full spectrum. It should minimize operator involvement in 24motor configuration and data acquisition. It should display alarms for each monitored channel, trend its 25data over time, and archive its data to a storage medium (e.g., computer disk). It should integrate with 26computer networks and control systems.

278.4.5.5.2 Continuous online diagnostic systems

28Motors that are critical to a process should be managed by a continuous online diagnostic system. Each 29channel in a continuous online diagnostic system is dedicated to the data from a single transducer and 30monitor channel. The diagnostic system processes machinery information online, and the data are 31continuously sampled continuously, and are available to the host computer. A diagnostic system that 32processes steady-state information, during normal operation, is a minimum requirement; and the diagnostic 33system should be capable of processing data both during startups and shutdowns. It should be capable of 34displaying information in real time. The continuous online diagnostic system is expensive and should be 35evaluated as with any protection to determine its economic feasibility.

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18.4.5.5.3 Periodic online diagnostic systems

2General -purpose motors can be managed by an online periodic diagnostic system. Each channel in a 3periodic system can be shared among many transducers. The data are periodically sampled periodically and 4are continuously available continuously to the host computer.

58.4.5.5.4 Vibration limits

6The vibration limits for motor shafts and bearing housings depend mainly on the operating speed. Typical 7limits are described in API Std 541-1995 and API Std 546-1997. The limits for filtered and unfiltered 8measurements are also described.

98.5 Synchronous motor protection

108.5.1 Damper winding protection

11

12When a synchronous motor is starting, high currents are induced in its rotor damper winding. If the motor- 13accelerating time exceeds specifications, the damper winding maymight overheat and be damaged.

14Several different electromechanical and electronic protective protection schemes are available. None of 15these schemes directly senses directly damper winding temperature. Instead, they these schemes try to 16simulate the temperature by evaluating two or more of the following quantities:

17 a) Magnitude of induced field current that flows through the a field- discharge resistor. This 18 value is a measure of the relative magnitude of induced damper-winding current. 19 b) Frequency of induced field current that flows through the discharge resistor. This value is 20 a measure of rotor speed and provides an indicator, therefore, of the increase in damper-winding 21 thermal capability resulting from the ventilation effect and the decrease of induced current. 22 c) Time interval after starting. 23

248.5.2 Field-current failure protection

25Field current maymight drop to zero or to a low value when a synchronous motor is operating for several 26reasons:

27  Tripping of the remote exciter, either motor-generator set or electronic. (Controls for these should 28 be arranged so that the remote exciter will not drop out on an ac voltage dip.) 29  Burnout of the field contactor coil. (The control should be arranged so that the field contactor does 30 not drop out on an ac voltage dip.) 31  Accidental tripping of the field. (Field-circuit overcurrent protection is usually omitted from field 32 breakers and contactors in order to avoid unnecessary tripping.) The field circuit is usually 33 ungrounded and should have ground detection lights or a relay element applied to it to detect the 34 first ground fault before a short circuit occurs (see 10.5.7.1).

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1  High-resistance contact or an open circuit between slip ring and brushes due tofrom excessive wear 2 or and misalignment. 3  Failure of diode bridge on rotating diodes on a brushless exciter (detected by pullout relays or a 4 power-factor Device 55 element). 5 6Reduced field-current conditions should be detected for the following reasons:

7  Overloaded motors pull out of step and stall. 8  Lightly loaded motors are not capable of accepting load when required. 9  Normally loaded motors, which do not pull out of step, are likely to do so on an ac voltage sag 10 through which they might otherwise rideride through would be usual. 11  The excitation drawn from the power system by large motors maymight cause a serious system 12 voltage drop and endanger servic continuity of service to other motors. 13 14A common approach to field-current failure protection is to use an instantaneous dc undercurrent relay to 15monitor field current. This application should be investigated to ensure that no transient conditions would 16reduce the field current and cause unnecessary tripping of this instantaneous relay. A timer could be used to 17obtain a delay of one or more seconds. Connect, or the relay could be connected to alarm only where 18competent supervising personnel are available. Another approach is to use a constant-current source to 19monitor field resistance; a sudden lower reading indicates a ground fault. Some protection schemes inject a 20square wave into the field circuit, and monitor the returned signal for rounded edges that indicate a change 21in field coil conditions.

22Field-current failure protection is also obtained by the generator loss-of-excitation relay that operates from 23the VTs and CTs that monitor motor stator voltages and current (VAR-import Device 40 and power-factor 24Device 55 protection). This approach has been done on some large motors (i.e., 3000 kW and above). This 25relay maymight also provide pullout protection (see 10.5.4.4)

268.5.3 Excitation voltage availability

27Device 56 is a relay that automatically has automatic control ofs the application of the field excitation to an 28ac motor at some point in the trip cycle, probably more related to permissive control function. This device 29is a frequency relay, but others apply a simple voltage relay as a permissive start to ensure that voltage is 30available from the remote exciter. This approach avoids starting and then having to trip because excitation 31was not available. Loss of excitation voltage is not normally used as a trip; the field-current failure 32protection is used for this function.

338.5.4 Pullout protection (Device 55)

34Pulling out of step is usually detected usually by one of the following relay schemes:

35 a) A power- factor relay (Device 55) responding to motor stator voltage and current VTs 36 and CTs. See 10.5.4.5 about the need to delay actuation of the pullout relay until the machine has 37 a chance to pull into synchronism during a calculated period. 38 b) An instantaneous relay connected in the secondary of a transformer whose with the 39 primary carries carrying the dc field current. The normal dc field current is not transformed. When 40 the motor pulls out of step, alternating currents are induced in the field circuit and transformed to 41 operate the pullout relay. This relay, while inexpensive, is sometimes subject to false tripping on

2 53 3 Copyright © 2010 20112013 IEEE. All rights reserved. 4 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8/D1.12, June, 2010October 2011June 2012February 2013

1 ac transients accompanying external system fault conditions, and also ac transients caused by 2 pulsations in reciprocating compressor drive applications. Device 95 has sometimes been used to 3 designate this relay. 4 c) The generator loss-of-excitation relay (Device 40). 5

68.5.5 Incomplete starting sequence (Device 48)

7Incomplete starting sequence protection is normally a timer that blocks tripping of the field-current failure 8protection and the pullout protection during the normal starting interval. The timer is started by an auxiliary 9contact on the motor starter, and it times for a preset interval that has been determined during test starting 10to be slightly greater than the normal interval from start to reaching full field current. The timer puts the 11field-current failure and pullout protection in service at the end of its timing interval. This timer is often a 12de-energize-to-time device so that it is fail-safe with regard to applying the field-current failure and pullout 13protection.

148.5.5.1 Operation indicator for protection devices

15Many types of the protective devices discussed in 10.5.4.1 through 10.5.4.5 do not have operation 16indicators. Separate operation indicators should be used with these protective devices.

178.5.5.2 Induction motor protection

18

19For induction motor incomplete starting sequence protection (Device 48), wound-rotor induction motors 20and reduced-voltage starting motors should have a timer applied to protect against failure to reach normal 21running conditions within the normal starting time. Such a de-energized-to-time device is started by an 22auxiliary contact on the motor starter and times for a preset interval, which has been determined during test 23starting to be slightly greater than the normal starting interval. The timer trip contact is blocked by an 24auxiliary contact of the final device that operates to complete the starting sequence. This device would be 25the final secondary contactor in the case of a wound-rotor motor, or it would be the device that applies full 26voltage to the motor stator. Incomplete sequence protection should also be applied to partsplit-winding and 27wye-delta motor-starting control, and to pony motor and other reduced-voltage sequential start schemes.

288.6 Protection against excessive starting

29The following protections against excessive starting are available:

30 a) A timer element, started by an auxiliary contact on the motor starter, with contact 31 arranged to block a second start until the preset timing interval has elapsed. 32 b) Stator thermal overcurrent overload elementsrelays (Device 49TC). , which provide 33 some protection, with the degree ofThis protection dependsing upon the following: 34 1) The Normal duration and magnitude of motor inrush 35 2) Running thermal capacity previously developed 36 3) The relay-operating time at motor inrush and the cool-down time of the relay 37 4) The Thermal damper-winding protection on synchronous motors

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1 5) Rotor over-temperature protection 2 c) Multifunction motor protection relays that have the capability to be programmed to limit 3 the number of starts during a specific period (jogging protection). Large motors are often provided 4 with nameplates giving their permissible start frequency of starting. 5

68.7 Rotor winding protection

78.7.1 Synchronous motors

8The field and field supply should not be intentionally grounded intentionally. While the first ground 9connection does not cause damage, a second ground connection probably will cause damage. Therefore, 10detecting the first ground is important. The following methods are used:

11 a) Connect two lamps in series between field positive and negative with the midpoint 12 between the lamps connected to ground. A ground condition shows by unequal brilliancy 13 brilliance of the two lamps. 14 b) Connect two resistors in series between field positive and negative with the midpoint 15 between the resistors connected through a suitable instantaneous relay to ground. The maximum 16 resistance to ground that can be detected depends upon the relay sensitivity and the resistance in 17 the two resistors. This scheme does not detect a ground fault at midpoint in the field winding. If a 18 varistor is used instead of one of the resistors, then the point in the field winding at which a ground 19 fault cannot be detected changes with the magnitude of the excitation voltage. This approach is 20 used to overcome the limitation of not being able to detect a field midpoint ground fault. 21 c) Apply a small low ac voltage signal between the field circuit and ground, and monitor the 22 ac flow to determine when a field-circuit ground fault occurs. (Note: bBefore using one of these 23 schemes, a determination should be made that a damaging ac current will not flow through the 24 field capacitance to the rotor iron and then through the bearings to ground and thus cause damage 25 to the bearings). 26 27If a portion of the field becomes faulted, damaging vibrations may can result. Vibration monitors and 28sensors should be considered.

298.7.2 Wound-rotor induction motors

30The protection for wound-rotor induction motors is similar to the protection described for synchronous 31motors, except the field is three-phase ac instead of a dc field (see Figure 19). Yuen, et al. [B14], describe 32some operating experience which confirms the effectiveness of this protection. Wound-rotor motor damage 33can result due tofrom high-resonant torques from during operation with unbalanced impedances in the 34external rotor circuit on speed-controlled motors. Protection to detect this fault is available, although it has 35is seldom been used.

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1 2 Figure 20 — Rotor ground protection of wound-rotor motor

38.8 Lightning and surge protection

48.8.1 Types of protection

5Surge arresters are often used often, one per phase connected between phase and ground, to limit the 6voltage to ground impressed upon the motor stator winding due tofrom lightning and switching surges. The 7need for this type of protection depends upon the exposure of the motor and its the related power supply to 8surges. Medium-voltage cables have capacitance in their shields that can attenuate a surge. Like many 9protective applications, the engineer should evaluate importance and replacement costs, as well. A study is 10recommended.

11The insulation of the stator winding of ac rotating machines has a relatively smalllow impulse strength. 12Stator winding insulation systems of ac machines are exposed to stresses due tofrom the steady-state 13operating voltages and to from steep-wave-front voltage surges at large of high amplitudes. Both types of 14voltages stress the ground insulation. The steep-wave-front surges also stress the turn insulation. If the rise 15time of the surge is sufficiently steep enough (i.e., 0.1 µs to 0.2 µs), then most of the surge can appear 16across the first coil, the line-end coil; and its distribution in the coil can be nonlinear. This phenomenon can 17damage the turn insulation even though the magnitude of the surge is limited to a value that can be safely 18withstood by the ground wall insulation.

19The surge arrester should be selected to limit the magnitude of the surge voltage to a value less than the 20motor insulation surge withstand [(or basic impulse insulation level ([BIL)].]). See Table 2.

21The steepness of the surge wave front at the motor terminals is influenced by two time constants:

22  At the supply end, by the effect of system inductance, grounding resistance, and motor cable 23 impedance 24  At the motor end, by cable impedance and motor capacitance 25Surge capacitors are used, also connected between each phase and ground, to decrease the slope of the 26wavefront of lightning and switching surge voltages. As the surge voltage wavefront travels through the 27motor winding, the surge voltage between adjacent turns and adjacent coils of the same phase are lower for

2 56 3 Copyright © 2010 20112013 IEEE. All rights reserved. 4 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8/D1.12, June, 2010October 2011June 2012February 2013

1a wavefront having a decreased slope. (A less steep wavefront is another way of designating a wavefront 2having a decreased slope.) The recommended practice is to install a surge surge-protection package 3consisting of a three-phase capacitor and three surge arrestors.

4 Table 2— The equivalent BILs by present standard test for commercially 5 used motor voltages

Rated voltage NEMA BIL IEC BIL (V) (kV) (kV)

2400 9 15

4160 15 22

13 800 51 60 6

7The steep-wave-fronted surges appearing across the motor terminals are caused by lightning strikes, normal 8circuit breaker operation, motor starting, aborted starts, bus transfers, switching windings (or speeds) in 9two-speed motors, or switching of power- factor correcting capacitors. Turn insulation testing also imposes 10a high stress on the insulation system.

11The crest value and rise time of the surge at the motor depend on the transient event taking place, on the 12electrical system design, and on the number and characteristics of all other devices in the system. These 13factors include, but are not limited to, the motor, the cables connecting the motor to the switching device, 14the conduit and conduit grounding, the type of switching device, the length of the switchgear bus, and the 15number of other circuits connected to the bus.

16See IEEE Std C37.96-2000 for additional information on recommendations of the IEEE Surge Protection 17Committee.

188.8.2 Locations of surge protection

19The surge protection should be located as close to the motor terminals (in circuit length) as feasible, 20preferably with leads of 1 m or less. The supply circuit should connect directly to the surge equipment first 21and then go to the motor.

22Specifying that the surge protection be supplied in an oversized terminal box on the motor or in a terminal 23box adjacent to the motor is becoming more common. When surge protection is supplied in a motor 24terminal box, it must be disconnected before high-voltage dielectric testing of the motor is begunbegins. 25This step is a recognized inconvenience of this arrangement. A separate surge disconnecting device 26maymight be required.

27If the motors are within 30 m of their starters or the supply bus, locating the surge arresters, but not 28capacitors, in the starters or supply bus switchgear is economical (but not as effective). In the latter case, 29one set of surge protection can be used for all the motors within that 30 m of the bus. Alternatively, this 30approach may can be used for the smaller motors, and individual separate surge protection installed at each 31larger motor. Neither of these remote methods is recommended, and neither nor is locating the surge 32protection at the line side of the motor disconnect recommended, because as the disconnect can also be 33located too distant to be effective.

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18.8.3 Application of surge protection

2The following factors should be considered when applying surge protection:

3 a) When a medium-voltage motor is rated above greater than 370 kW (500 hp), surge 4 arresters and capacitors should be considered. 5 b) When a 150 kW (200 hp) or larger motor or when a critical motor is connected to open 6 overhead lines at the same voltage level as the motor, surge arrestors and capacitors should be 7 considered. 8 c) Even when a transformer is connecting the motors to open overhead lines, surge 9 protection is still required at times to protect against lightning or switching surges. Techniques are 10 available to analyze this situation. If doubt exists, surge protection should be provided. Refer to 11 10.5.8.2 for surge protection on the supply bus for motors located remote from the bus. In 12 addition, refer to Chapter 13 and Chapter 14, which recommend protection for switchgear and 13 incoming lines. 14 d) Where certain vacuum or SF6 circuit breakers or vacuum contactors are used, surge 15 protection maymight be necessary due tobecause of the possibility of restrikes, which can result in 16 voltage spikes. 17 e) For application in Class I, Division 2 or Class I, Zone 2, nonsparking surge arresters, 18 such as metal oxide varistor (MOV), sealed type, and specific- duty surge protective capacitors 19 can be installed in general-purpose type enclosures. Surge protection types other than those 20 described above require enclosures approved for Class I, Division 1 locations or Zone 1 locations. 21 (See 2011 NEC Article 501.35(B) and 505.20(C)). Refer to IEEE 1349-2011 22 NOTE – For a motor application, using three single-phase, specific- duty surge capacitors avoids 23 phase-phase short-circuit faults within the capacitor. 24

258.9 Protection against overexcitation from shunt capacitance

268.9.1 Nature of problem

27When the supply voltage is switched offremoved, an induction motor initially continues to rotate and 28retains its the internal voltage. If a capacitor bank is left connected to the motor or if a long distribution line 29having significant shunt capacitance is left connected to the motor, the possibility of overexcitation exists. 30Overexcitation results when the voltage versus current curves of the shunt capacitance and the motor no- 31load excitation characteristic intersect at a voltage above the rated motor voltage.

32The maximum voltage that can occur is the maximum voltage on the motor no-load excitation 33characteristic (sometimes called magnetization or saturation characteristic). This voltage, which decays 34with motor speed, can be damaging to a motor (see Figure 20 21 as an example).

2 58 3 Copyright © 2010 20112013 IEEE. All rights reserved. 4 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8/D1.12, June, 2010October 2011June 2012February 2013

1 2 Figure 21 — Excess shunt capacitance from utility line, which is likely to 3 overexcite a large, high-speed motpor 4

5Damaging inrush can occur if automatic reclosing or transfer takes place on a motor that has a significant 6internal voltage due tofrom overexcitation.

78.9.2 Protection

8When overexcitation is expected, protection can be applied in several ways. B, beginning with the simplest 9protection, which is of a separate contactor to drop out the capacitors when the motor power source is lost. 10The contactor could also be dropped outoperated by instantaneous overvoltage relay elements. An 11alternative is to use a high-speed underfrequency relay, which, however, maymight not be sufficiently fast 12enough on high-inertia or lightly loaded motors.

13The underfrequency relay is not suitable for motors whose when frequency maymight not decrease 14following loss of the supply overcurrent protective disconnecting device. With these applications, a loss-of- 15power relay could be used. Examples of these applications are the following:

16

17 a) Mine hoist with overhauling load characteristic at time of loss of supply overcurrent device 18 f) Motor operating as induction generator on shaft with process gas expander 19 g) Induction motor with forced commutation from an ASD

2 59 3 Copyright © 2010 20112013 IEEE. All rights reserved. 4 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8/D1.12, June, 2010October 2011June 2012February 2013

18.10 Protection against automatic reclosing or automatic transfer

28.10.1 Nature of problem

3

8Fast reclosing on a motor bus is possible if the motor volts-per-hertz excitation level remains below 1.33. 9Any system that restores power must do so in less than 100 ms to prevent major damage. These systems 10must be studied to determine efficacy even when using fast, permissive synchronizing and fast-closing 11circuit breakers. The benefit of fast reclosing is continued process operation without long, costly 12downtime, which balances the risk and effort involved. IEEE Std C37.96-2000 discusses considerations for 13the probability of damage occurring for various motor and system parameters.

14If fast reclosing cannot be obtained then closing must occur when motors on a bus have completed spinning 15and are nearly stopped. This is the residual closing range (time greater than 3 s or facility safe 16practice).One of the best methods to prevent fast reclosing is to consult with the power supplier to 17determine whether they can delay reclosing (e.g., 2 s or more or whatever becomes a standard practice).

188.10.2 Protection

19The following protection alternatives should be considered:

20 a) Delay restoration of system voltage, using a timer (Device 62) for a preset interval sufficient for 21 adequate decay of the motor internal voltage. This method maymight not be as necessary if the 22 power supplier cooperates on the reclosing, but could be a backup device 23 b) , provided that the timer’s reliability is acceptable. 24 c) Delay restoration ofing system voltage until the internal voltage fed back from the motor(s) has 25 dropped to a low enough value. Commonly, tThis residual closing value is commonly considered 26 to be 25% percent of rated voltage. The frequency also decreases as the voltage decays due 27 tobecause of motor deceleration. The undervoltage relay element (Device 27) and its setting 28 should be chosen accordingly to include a full-wave rectifier and a dc coil and to make the relay 29 element dropout independent of frequency. If an ac frequency-sensitive relay is used, it should be 30 set (based on motor and system tests) to actually drop out at 25% of rated voltage and at the 31 frequency that will exist when 25% of rated voltage is reached. 32 h) Use a high-speed under-frequency relay element (Device 81) to detect the supply outage 33 and trip the motors before supply voltage is restored. A limitation exists if the motor operates at 34 the same voltage level as the supply lines on which faults may occur followed by an automatic 35 reclosing or transfer operation. The problem is that the under-frequency relay requires some 36 voltage in order to have operating torque. If no impedance (e.g., a transformer) exists between the 37 motor and the system fault location, then the voltage may not be sufficient to permit the under- 38 frequency relay to operate. Digital frequency relays are not as voltage limited as electromechanical 39 relays. 40 i) 41 j) Use single-phase (Device 27) or three-phase undervoltage relays elements as follows:

2 60 3 Copyright © 2010 20112013 IEEE. All rights reserved. 4 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8/D1.12, June, 2010October 2011June 2012February 2013

1 1) One relay element with a sufficiently fast time setting can be connected to the same VT as 2 the under-frequency relay [see Item c)] and sense the fault condition that results in 3 insufficient voltage to operate the under-frequency relayelement. 4 2) One, two, or three relay elements (i.e., each connected to a different phase) can be used to 5 detect the supply outage and trip the motors when sufficient time delaydelay exists before the 6 supply is restored. 7 k) Use a loss-of-power (undercurrent) relay element (Device 37). This under-power 8 relayelement should be sufficiently fast and sensitive. A high-speed three-phase relay has been 9 used frequently, butThis element should be active only in the motor running state (blocked at 10 startup) until when sufficient load is obtained on the circuit or motor with which it is applied. 11 l) Use a reverse-power relay element (Device 32). This relay element detects a separation 12 between motors and their source. While this approach is suitable in some circumstances, generally 13 the loss-of-power relay element application is generally more suitable than the reverse-power relay 14 element application due tobecause of the following limitations: 15 1) During the fault, when the source is still connected to the motors, net power flow continues 16 into the motors for low-level faults. Although not true for three-phase bolted faults, low-level 17 faults have a very low impedance, into which reverse power flows. 18 2) 19 3) Usually, tTripping by reverse power can usually be reliedis effective upon only if a definite 20 load remains to absorb power from high-inertia motor drives after the source -fault-detecting 21 relays elements isolate the source from the motors. 22 4) Reverse-power relays responsive to reactive power (i.e., vars) instead of real power (i.e., 23 watts) usually do not provide a suitable means of isolating motors prior to automatic 24 reclosing or automatic transfer operations. 25

268.11 Protection against excessive shaft torques

27< Dan Ransom; lead >A phase-to-phase or three-phase short circuit at or near the synchronous motor 28terminals produces high shaft torques that may can be damageing to the motor or driven machine. 29Computer programs have been developed for calculationng of these torques. Refer to IEEE Std C37.96- 302000 for information on this potential problem.

31To minimize exposure to damaging torques, a three-phase, high-speed undervoltage relay element (Device 3227) can be applied to detect severe phase-to-phase or three-phase short-circuit conditions for which the 33motors should be tripped. This relay is often the type whose torque is proportional to the area of the triangle 34formed by the three voltage phasors. A severe reduction in phase-to-phase or three-phase voltage causes 35tripping. Addn additional tripping delay of 1 cycle to 8 cycles (15 ms to 500 ms) may be satisfactory from a 36protection point of view and desirable to avoid unnecessary shutdowns. This protection can be achieved 37using a suitable timer. Selection of protection and settings for this application should be done in 38cConsultation with the suppliers of the motors, driven machines, and protection devices when creating 39protection settings.

408.12 Protection against excessive shaft torques developed during transfer of 41motors between out-of-phase sources

42< Dan Ransom; lead >A rapid transfer of large motors from one energized power system to another 43energized power system could cause very high motor inrush currents and severe mechanical shock to the 44motor. The abnormal inrush currents maymust be sufficient be high enough to trip circuit breakers or blow 2 61 3 Copyright © 2010 20112013 IEEE. All rights reserved. 4 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8/D1.12, June, 2010October 2011June 2012February 2013

1fuses, and these currents could damage motor system components. The mechanical jolt could physically 2damage the motor, shaft, and couplings.

3These effects can occur in emergency or standby power systems when a motor is de-energized and then 4rapidly reconnected to another source of power that is out-of-phase with the motor’s regenerated voltage. 5Motors above 37 kW driving high-inertia loads (e.g., centrifugal pumps, fans) may require special 6consideration.

7The problem can be eliminated if the motor circuits can be de-energized long enoughfor sufficient time to 8permit the residual voltage to decay before power is again applied to the motor. This step can be done in 9two ways. In one available method, auxiliary contacts or a relay on the automatic transfer switch can open 10the motor holding coil circuits, while the transfer is delayed about 3 s. This method is sometimes effective, 11but requires interwiring between the transfer switch and the motor starters and depends upon the reliability 12of a timing device. Another method utilizes a transfer switch with a timed center-off position. The switch 13opens, goes to the neutral or off position, is timed to stay there about 3 s to 10 s, and then completes the 14transfer. This approach eliminates any interwiring to the motors. The required time delaydelay should be 15set carefully set and may can vary as the system conditions change. A third position (neutral) creates the 16danger that the transfer switch maymight remain indefinitely in a neutral position in the event of a control 17circuit or contactor malfunction.

18Another solution is to momentarily parallel momentarily the two power sources on transfer, connecting 19both sources together and then dropping one out. This approach is completely effective because power to 20the motors is never interrupted. However, it can require new equipment and can be costly. If one source is 21utility power, a problem may can exist occur in becausethat some utilities do not permit paralleling another 22source with their systems. In obtaining permission for the paralleling from the utility, a design review may 23can lead to additional protective relaying. An additional factor is that the combined available fault current 24maymight exceed the ratings of the connected electrical switching equipment.

25In-phase transfer is another solution to the problem. An accessory on the transfer switch, known as a fast n 26in-phase monitor or synch-check element (Device 25), measures the phase-angle difference between the 27two power sources. An on-site generator set would be controlled by an automatic synchronizer, which 28recognizes that the two sources continually go in and out of phase. At the proper window or acceptable 29phase-angle difference between the sources, the synchronizer synch-check element initiates transfer. The 30design allows for the operating time of the transfer switch so that the oncoming source is connected to the 31motors in phase or at a phase difference small enough to eliminate excessive inrush currents and 32mechanical shock. No special field adjustments or interwiring to the motors are required. For typical 33transfer switches with transfer times of 10 cycles (166 ms) or less and for frequency differences between 34the sources of up toas much as 2 Hz, the fast synchro-check relay element provides a safe transfer of 35motors.

368.13 Protection against failure to rotate

378.13.1 Failure to rotate

38A failure to rotate occurs when the supply is single phased or if the motor or driven machine is jammed. 39The following protection is available:

40 a) Relays may can be used to detect single phasing (see 10.3.3.2). 41 m) The direct means to detect failure to rotate is to use a shaft-speed sensor and timer to 42 check whether a preset speed has been reached by the end of a short preset interval after 43 energizing the motor. This protection is necessary for induction and brushless synchronous motors 44 that have a permissible locked-rotor time less than normal acceleration time.

2 62 3 Copyright © 2010 20112013 IEEE. All rights reserved. 4 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8/D1.12, June, 2010October 2011June 2012February 2013

1 n) For induction and brushless synchronous motors having a permissible locked-rotor time 2 greater than normal acceleration time, relying upon the element 49TC thermal overload element is 3 preferred. Using an inverse-time phase-overcurrent relays (Device 51) as a backup is normal (see 4 10.3.4 and 10.3.5). 5 o) For brush synchronous motors having a permissible locked-rotor time less than normal 6 acceleration time, one method of protection is to use a frequency-sensitive relay connected to the 7 field discharge resistor and a timer because the frequency of the induced field current flowing 8 through the discharge resistor is related to the motor speed. A frequency-sensitive adjustable time- 9 delay voltage relay is also available to provide this protection. 10 p) For brush synchronous motors having a permissible locked-rotor time greater than 11 normal acceleration time, relying upon the damper-winding protection and incomplete starting 12 sequence protection is normal. 13 q) For a large induction motor protection to start, an impedance relay element (Device 21) 14 may can be applied (see 10.5.1, Figure 8, and Figure 9).

158.13.2 Reverse rotation; loss of phase

16A directional speed switch mounted on the shaft and a timer can be used to detect starting with reverse 17rotation. Some motor loads are equipped with a ratchet arrangement to prevent reverse rotation.

18A reversal in the phase rotation, or a phase loss, can be detected by a reverse-phase voltage relay element 19(Device 47) [see 10.3.3.4 b)] if the reversal or loss occurs in the system on the supply side of the relay. 20This relay element cannot detect a reversal or loss that occurs between the motor and the point at which the 21relay element is connected to the system. Set this element for no more than 5 percent voltage imbalance. 22Unbalanced voltages create large unbalanced currents (approximately five times the percent voltage 23unbalance); these negative-sequence currents can damage motor stator windings. A backup method for 24preventing unbalanced power system damage is using a current-imbalance element (Device 46). Set this 25element to 0.2 pu negative-sequence current.

26A directional speed switch mounted on the shaft and a timer can be used to detect starting with reverse 27rotation. Some motor loads are equipped with a ratchet arrangement to prevent reverse rotation.

289. Application considerations

29

309.1 Motor protection for ASD applications

31<[Ed Larsen, Lead; Jeff Hensley; Dan Neeser, Tim O’Hearn; add ASD application information for 32medium-voltage and low-voltage applications; eg high speed fuses, shaft currents CMV, resonant 33frequency, partial discharge, long lead length NEMA Part 30 & 31 (inverter duty); things that are different 34because of ASD (no surge arrestors) (no Power Factor correction capacitors) see also C37.96-2012 draft]>

35

36

37

2 63 3 Copyright © 2010 20112013 IEEE. All rights reserved. 4 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8/D1.12, June, 2010October 2011June 2012February 2013

19.1.1 Terminology

2Adjustable speed drives (ASD) are known by many names, such as:

3  Adjustable Frequency Controller (AFC) – refers to ac drives 4  Adjustable Frequency Drive (AFD) – refers to ac drives 5  Adjustable Speed Drive (ASD) – refers to ac or dc drives 6  Inverter – refers to ac drives 7  Power converter – refers to ac drives 8  Variable Frequency Drive (VFD) – refers to ac drives 9  Variable Speed Drive (VSD) – refers to ac or dc drives 10There is no single industry recognized name. In this section they will be referred to as ASDs, as does the 11IEEE and the National Electrical Code® (NEC®).

12

139.1.2 Low Voltage AC Drive Motor Protection

14

159.1.2.1 Protection

16Use some of the content in: Electric Motors and Variable Frequency Drives Handbook Vol. 4, The 17Electricity Forum, pages 47-48, 59-60? http://www.meisterintl.com/PDFs/Electric-Motors-Drives-Vol- 184.pdf

19Use some of the content in: Adjustable Speed Drive Motor Protection Applications and Issues, Jon Gardell, 20Chairman Prem Kumar, Vice Chairman, Rotating Machinery Protection Subcommittee of the IEEE Power 21System Relaying Committee Working Group?

22How does what we are writing fit in with this paper?

23Use some of the content in: Draft Guide for AC Motor Protection, Power System Relaying Committee of 24the IEEE Power Engineering Society, IEEE Std PC37.96/D10? Possible topics might be:

25  5.1 Pullout and stall protection 26  5.2 Stator winding protection 27  5.3 Rotor thermal protection 28  5.4 Stator fault protection 29  5.5 Rotor fault protection 30  5.6 Bearing protection 31  5.7 Abnormal power supply conditions WG: need to cover here or elsewhere, but drive may 32 automatically protect against these conditions, delete 33  5.8 Surge protection LP: need, but coordinate with coverage elsewhere in doc

2 64 3 Copyright © 2010 20112013 IEEE. All rights reserved. 4 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8/D1.12, June, 2010October 2011June 2012February 2013

1How does what we are writing fit in with this standard? LP: our doc needs to stand alone

2LP: Need to show drive topology?

3Use some of the content in: NEMA Application Guide for AC Adjustable Speed Drive Systems, Bezesky and 4Kreitzer, PCIC 2001-7? Bredhold: get 2007 edition

5Use some of the content in: Application issues for PWM adjustable speed AC motor drives, von Jouanne et 6al, Industry Applications Magazine Sept/Oct 1996?

7

89.1.2.2 Included in ASD

9Where the ASD is marked to indicate that motor overload protection is included, additional overload 10protection is not required.

11WG: can’t assume that the drive provides OL protection, need to look for marking

12

139.1.2.3 Bypass Circuits

14For ASD systems that utilize a bypass device to allow motor operation at rated full-load speed, motor 15overload protection must be provided in the bypass circuit.

16WG: Must be provided when in bypass mode, does not necessarily need to be in the bypass ckt itself

17

189.1.2.4 Multiple Motor Applications

19For multiple motor applications, individual motor overload protection shall be provided in accordance with 20NEC® Article 430, Part III.

21Use some of the content in: Application Guide for AC Adjustable Speed Drive Systems, NEMA, 5.2.12 pg. 2249-50?

23DN: yes, multiple motors & group motor applications (contact John McKensie & Mike Liptak from SE)

24

259.1.2.5 Overtemperature Protection

26Overheating of motors can occur even at current levels less than a motor’s rated full-load current. 27Overheating can be the result of the shaft-mounted fan operating at less than rated nameplate RPM. For 28motors that utilize external forced air or liquid cooling systems, overtemperature can occur if the cooling 29system is not operating. In these instances, overtemperature protection using direct temperature sensing is 30recommended, or additional means should be provided to ensure that the cooling system is operating (flow 31or pressure sensing, interlocking of ASD system and cooling system, etc.)

2 65 3 Copyright © 2010 20112013 IEEE. All rights reserved. 4 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8/D1.12, June, 2010October 2011June 2012February 2013

1ASD systems must protect against motor overtemperature conditions where the motor is not rated to 2operate at the nameplate rated current over the speed range required by the application. Such protection 3may be provided by:

4  Motor thermal protector in accordance with 430.32 5  Adjustable speed drive system with load and speed-sensitive overload protection and thermal 6 memory retention upon shutdown or power loss, except that thermal memory retention upon 7 shutdown or power loss is not required for continuous duty loads. 8  Overtemperature protection relay utilizing thermal sensors embedded in the motor and meeting the 9 requirements of 430.32(A)(2) or (B)(2). 10  Thermal sensor embedded in the motor whose communications are received and acted upon by an 11 ASD system. 12For multiple motor applications, individual motor overtemperature protection shall be provided as required 13in 430.126(A).

14Use some of the content in: Application Guide for AC Adjustable Speed Drive Systems, NEMA, 5.2.1.3 15pg. 29, 5.2.1.5 pg. 30?

16

179.1.3 Medium Voltage AC Drive Motor Protection

18Use some of the content in: The protection technology of high voltage variable frequency drive system, 19Qing Xion et al, IEEE paper?

20WG: refer to IEEE 1566. Currently being updated. Ballot next year. LP will get me in contact with that 21WG, Rick Paes.

22

239.1.4 DC Drive Motor Protection

24Use some of the content in: Electric Motors and Variable Frequency Drives Handbook Vol. 4, The 25Electricity Forum, pages 41-46? http://www.meisterintl.com/PDFs/Electric-Motors-Drives-Vol-4.pdf

26LP: Chris Heron can help

27

289.1.5 Other Considerations

29

309.1.5.1 Shaft Voltage and Bearing Currents and Common Mode Voltages

31Use some of the content in: Application Guide for AC Adjustable Speed Drive Systems, NEMA, 5.2.10 pg. 3244-49?

33LP: IEEE 1349 has new section on CMV calculations 2 66 3 Copyright © 2010 20112013 IEEE. All rights reserved. 4 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8/D1.12, June, 2010October 2011June 2012February 2013

19.1.5.2 Partial Discharge

2WG: Chris Heron met with others (Malcolm Seltzer-Grant) on this topic for section 8. Usually an issue at 35kV and above, but inverters can lower that level, seen as low as 2.3kV and even down to 480V. Need to 4describe phenomenon or protection? Need to cover. Have seen 4kV in other stds. Can happen if drive is 5closely coupled to machine. IEC stds. Write paragraph that phenomenon & protection not the same when 6a drive is used, refer to section 8. Protection is in way motor is wound. PD monitor (negative seq.). 7Motor mfgrs may use higher insulation level if they know motor will be on a drive.

8

99.1.5.3 ASD Output filters and reactors

10Use some of the content in: Electric Motors and Variable Frequency Drives Handbook Vol. 4, The 11Electricity Forum, pages 47-52? http://www.meisterintl.com/PDFs/Electric-Motors-Drives-Vol-4.pdf

12Use some of the content in: Application Guide for AC Adjustable Speed Drive Systems, NEMA, 5.2.9 pg. 1338-44?

14WG: Need to cover? Yes. Reflected wave issue, inverter duty withstands better. Consider dV/dt filters.

15WG: Need to cover (dV/dt filters). Can also be addressed in drive topology. Related to long lead length 16issue. Get David Shipp to help. Move this topic to long lead length section. Call the section “ASD Output 17Filters and Reactors” rather than “Long Lead Length”.

189.1.5.4 NEMA MG-1 Part 30 and 31 Inverter Duty

19Use some of the content in: Application Guide for AC Adjustable Speed Drive Systems, NEMA, 5.2.9.1 pg. 2038?

21Part 30 covers general purpose motors

22Part 31 covers inverter duty motors

23WG: Need to cover? Yes, because protection needs vary depending on type of motor.

24WG: Need to cover duty cycle, re motor heating. Maybe in a separate section? Under thermal protection?

259.1.6 Selecting Drives

26Since the scope of this dot standard, and this specific section, is motor protection, do we/should we cover 27selection of the drive itself? I think not, but if the answer is yes, subtopics might be:

289.1.6.1 Selection Considerations

29 1) Load characteristics 30 2) Motor nameplate data 31 3) Motor speed control range, heating and performance considerations 32 4) Breakaway torque requirements

2 67 3 Copyright © 2010 20112013 IEEE. All rights reserved. 4 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8/D1.12, June, 2010October 2011June 2012February 2013

1 5) Load acceleration/deceleration requirements 2 6) Environment (temperature, altitude, humidity) 3 7) Multimotor or single motor 4 8) AC line 5 9) Code requirements 6 10) Application considerations 7WG: Need to cover? Not for drive per se, but need to cover protection options that might be needed in the 8drive. Reference earlier sections. Break down into LV & MV. In MV multifunction relay will provide 9necessary options.

10Write introductory paragraph. Assuming the drive selected is adequate, then need to provide protection 11considerations…(punch list). Reference IEEE 1566 data sheet.

12

139.1.6.2 Regeneration and Dynamic Braking

14Use some of the content in: Application Guide for AC Adjustable Speed Drive Systems, NEMA, 5.2.5 pg. 1536-37?

16WG: Need to cover? Deals with drive protection, not motor protection? What about dc injection braking? 17What about mechanical braking? Yes, we need, but unsure what to say. Leave in for now.

18Need separate subsection: if compressor or pump sled provides protection function/monitoring (RTD, 19vibration) need coordination between sled and drive. David Rains will write.

209.1.6.3 Protection Device Monitoring by Auxiliary Control Equipment

21In some applications vibration and temperature monitoring devices may be monitored by an auxiliary 22control panel; e.g. compressor or pump unit control panel, DCS or station control panel. In these 23applications; permissive to start, alarm and shutdown signals shall be coordinated with the drive to ensure 24the protection of the motor and the driven equipment.

25

269.1.7 Drive Protection

27Since the scope of this dot standard, and this specific section, is motor protection, do we/should we cover 28protection of the drive itself? I think not, but if the answer is yes, subtopics might be:

29WG: Need to cover? Yes, to the extend that the motor branch circuit overcurrent protection also protects 30the motor. Will touch on it somehow.

31

32

2 68 3 Copyright © 2010 20112013 IEEE. All rights reserved. 4 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8/D1.12, June, 2010October 2011June 2012February 2013

1

2

39.2 Motors protection for hazardous (classified) locations

4[

69.3 DC Motor protection

7

8

9

2 69 3 Copyright © 2010 20112013 IEEE. All rights reserved. 4 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8/D1.12, June, 2010October 2011June 2012February 2013

1Annex A Bibliography

2[B1] Bradfield, H. L., and Heath, D. W., “Short-Circuit Protection of Energy-Efficient Motors,” IEEE 3Industry Applications Magazine, vol. 3, no. 1, pp. 41–44, Jan./Feb. 1997.

4[B2] Gregory, G. D., “Single-Pole Short-Circuit Interruption of Molded-Case Circuit Breakers,” IEEE 5I&CPS Conference Record, Section 5, Paper 1, pp. 1–8, May 1999.

6[B3] Gregory, G. D., and Padden, L. K., “Application Guidelines for Instantaneous Trip Circuit Breakers in 7Combination Starters” (a working group report), IEEE Transactions on Industry Applications, vol. 34, no. 84, pp. 697–704, July/Aug. 1998.

9[B4] Gregory, G. D., and Padden, L. K., “Testing and Applying Instantaneous Trip Circuit Breakers in 10Combination Motor Starters,” IEEE PCIC Conference Record, pp. 41–49, 1998.

11[B5] Love, D. J., “Ground Fault Protection of Electric Utility Generating Station Medium-Voltage 12Auxiliary Power System,” IEEE Transactions on Power Apparatus and Systems, vol. PAS-97, No. 2, 13March/April 1978, pp. 583–586.

14[B6] Love, D. J. and Hashemi, N., “Considerations for Ground Fault Protection, Medium-Voltage 15Industrial and Co-Generating Systems,” IEEE Transactions on Industry Applications, vol. IA-24, 16July/August 1988, pp. 548–553.

17[B7] Nailen, R. L., Managing Motors, 1st ed. Chicago: Barks Publications, Inc., 1991, pp. 4-61 and 4-62.

18[B8] Nailen, R. L., “Motor Inrush Current: What Does It Really Mean?” Electrical Apparatus Magazine, 19pp. 56–60, June 1986.

20[B9] NEMA MG 10-1994, Energy Management Guide for Selection and Use of Fixed Frequency Medium 21AC Squirrel-Cage Polyphase Induction Motors.

22[B10] Padden, L. K., and Pillai, P., “Simplifying Motor Coordination Studies,” IEEE Industry 23Applications Magazine, vol. 5, no. 2, pp. 38–52, Mar./Apr. 1999.

24[B11] Prabhakara, F. S., Smith Jr., R.L., and Stratford, R. P., Industrial and Commercial Power Systems 25Handbook, 1st ed. Mcgraw-Hill, 1995, pp. 8–46.

26[B12] Smith III, A. J., “Short Circuit Ratings, Labels and Fault Withstandability of Molded-Case and 27Insulated-Case Circuit Breakers and Combination Motor Starters,” IEEE PCIC Conference Record, pp. 9– 2818, 1991.

29[B13] UL 489, Standard for Molded Case Circuit Breaker and Circuit Breaker Enclosure.

30[B14] Yuen, M. H., Rittenhouse J. D., and Fox F. K., “Large Wound-Rotor Motor with Liquid Rheostat 31for Refinery Compressor Drive,” IEEE Transactions on Industry and General Applications, vol. IGA-1, 32pp.140–149, Mar./Apr. 1965.

33

2 70 3 Copyright © 2010 20112013 IEEE. All rights reserved. 4 This is an unapproved IEEE Standards Draft, subject to change. 1 IEEE P3004.8/D1.12, June, 2010October 2011June 2012February 2013

1Annex B Protection setting considerations

2

3B.1 Typical motor protection settings

4Typical recommended protection settings for motor protection devices are shown below:

5

6 Table B.1 Typical motor protection device settings Descriptions Alarm Trip Thermal overload 105% (110% = SF 1.0), (125% = SF 1.15) Unbalance (voltage, current) ±10% ±15% - 20% Ground fault 0.1 ground CT 0.15 ground CT Under/Over Voltage ±10% ±15% – 20% Stator winding temperature -15oC insulation max -10oC insulation mac Bearing temperature 15 oC before damage 10 oC before damage Short circuit 600% - 720% 7

8B.2 Current unbalance and ground fault protection in HRG system

9

13B.3 Overcurrent protection in fixed capacitor applications

14

161. Dependent upon the capacitor location, overload or overcurrent setpoint should be adjusted.

172. Fixed capacitor will modify motor open circuit time constant. We may add some equations to calculate a 18revised motor open circuit time constant to help engineers to determine the minimum time for blocking 19motor starting until motor residual voltage reaches to an acceptable level.

203. Many process plants tends to implement motor re-acceleration scheme. Therefore, motor capacitor 21application may not be recommended for re-acceleration motors in the process plants unless there will be 22sufficient time to decay motor residual voltages. This should be discussed with plant process engineers.>

23

2 71 3 Copyright © 2010 20112013 IEEE. All rights reserved. 4 This is an unapproved IEEE Standards Draft, subject to change.

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