Installation • Operation • Maintenance Instructions
Centurion™ Recloser Siemens Power Transmission & Distribution, Inc. P.O. Box 29503 Raleigh, NC 27626-0503
LIMITATIONS
This document is protected by copyright and is provided solely for the use of the recipient. It is not to be copied in any way, nor its contents divulged to any third party, nor to be used as the basis of a tender or specification without the express written permission of Siemens Power Transmission & Distribution, Inc.
This document discloses confidential intellectual property that belongs to Siemens Power Transmission & Distribution, Inc. This document does not invest any rights to Siemens intellectual property in the recipient. Moreover the recipient is required not to disclose any of the intellectual property contained in this document to any other party unless authorized in writing by Siemens Power Transmission & Distribution, Inc.
NOTE
These instructions do not purport to cover all details or variations in equipment, nor to provide for every possible contin- gency to be met in connection with installation, operation or maintenance. Should further information be desired or should particular problems arise which are not covered sufficiently for the purchaser's purpose, the matter should be referred to the local sales office.
The contents of this instruction manual shall not become part of or modify any prior or existing agreement, commitment or relationship. The sales contract contains the entire obligation of Siemens Power Transmission & Distribution, Inc. The warranty contained in the contract between the parties is the sole warranty of Siemens Power Transmission & Distribution, Inc. Any statements contained herein do not create new warranties or modify the existing warranty. Table of Contents
List of Figures ...... v 3.3.3 Control Electronics - Thermal Ratings ...... 6 1 Introduction ...... 1 3.4 Protection and Auto-Reclose Functions...... 6 1.1 Safety ...... 1 3.4.1 Inverse Time Protection ...... 7 1.2 Qualified Person...... 1 3.4.2 Definite Time Protection ...... 7 1.3 Signal Words...... 1 3.4.3 Instantaneous Protection ...... 7 1.4 Hazardous Procedures ...... 2 3.4.4 Sensitive Ground Fault Protection 1.5 Field Service Operation ...... 2 (SGF) ...... 7 3.4.5 Cold Load Pickup ...... 7 2 Scope of this Technical Manual.. 3 3.4.6 Inrush Restraint ...... 7 2.1 General ...... 3 3.4.7 Loss Of Phase Protection ...... 7 2.2 Equipment Versions Covered 3.4.8 Live Load Blocking ...... 8 by this Manual ...... 3 3.4.9 High Current Lockout (HCLO) ...... 8 2.3 Control Version...... 3 3.4.10 Automatic Protection Group 2.4 Firmware Versions Covered Selection ...... 8 by this Manual ...... 3 3.4.11 Auto-Reclose ...... 8 2.5 Firmware Identification System...... 3 3.4.12 Other Protection Features ...... 8 2.6 Related Documents...... 3 3.4.13 Loss of Primary Voltage Detection ...8 2.7 Year 2000 Compliance Statement For Centurion Reclosers with 3.5 Power System Measurements ...... 8 type MJ-R Control ...... 4 3.5.1 General ...... 8 3.5.2 Demand History ...... 9 3 Specification...... 5 3.5.3 Event History ...... 9 3.1 Environmental ...... 5 3.2 Recloser...... 5 4 Recloser Construction and 3.2.1 Basic Timings ...... 5 Operation 11 3.2.2 Electrical Ratings ...... 5 4.1 Recloser Mounting...... 11 3.2.3 Endurance Capability ...... 5 4.2 Manual Trip ...... 11 3.2.4 Sequence Capability ...... 5 4.3 Line Connections ...... 11 3.2.5 Creepage and Clearances ...... 6 4.4 Surge Arresters...... 11 3.2.6 Current Transformers ...... 6 4.5 Control Cubicle Connection ...... 11 3.3 Control Cubicle...... 6 4.6 Recloser Memory...... 11 3.3.1 Radio/Modem Provisions ...... 6 4.7 Contact Life...... 12 3.3.2 Control Panel ...... 6
Siemens Power Transmission & Distribution, Inc. i 5 Control Cubicle Construction ... 15 9.6 Ground Fault Control ...... 32 5.1 Tropical, Moderate and 9.7 Changing Protection Settings ...... 32 Temperate Versions...... 15 9.8 Overcurrent Protection...... 32 5.2 Equipment Panel...... 15 9.9 Inverse Time Protection ...... 33 5.3 Radio Mounting Tray Space ...... 18 9.9.1 Protection Curves ...... 34 5.4 Sealing & Condensation ...... 18 9.9.2 Interactions between curve 5.5 Mounting & Grounding ...... 18 parameters ...... 34 5.6 Control Power...... 19 9.10 Definite Time Protection ...... 36 5.7 Control Power Supply Options ...... 19 9.11 Sensitive Ground Fault (SGF)...... 36 5.8 Cable Entry ...... 19 9.12 Loss Of Phase Protection ...... 37 5.9 Current Injection Point...... 20 9.13 Live Load Blocking...... 37 5.10 Computer Port...... 20 9.14 Auto-Reclose ...... 37 9.15 Sequence Reset ...... 37 6 Control Electronics Operation .. 21 9.16 Lockout ...... 38 6.1 Control & Protection Module (CAPM) ..... 21 9.16.1 High Current Lockout ...... 38 6.2 Operator Panel Subsystem (OPS) ...... 21 9.16.2 Single Shot Mode ...... 38 6.3 Control Cable Entry Module (CCEM)...... 21 9.17 Inrush Restraint ...... 39 6.4 Description of Operation ...... 21 9.18 Cold Load Pickup (CLP) ...... 39 9.18.1 Cold Load Pickup Example ...... 40 7 Operator Control Panel...... 25 9.18.2 Cold Load Pickup Status Display ...40 7.1 Turning on the Control Panel...... 25 9.18.3 Operator Control of 7.2 Organization of Liquid Crystal Display .... 25 Cold Load Pickup ...... 40 7.3 Microprocessor Running LED ...... 25 9.19 Sequence Coordination (Sequence Control)...... 42 7.4 TRIP/CLOSE Keys, ENABLE/DISABLE Isolate Switches...... 26 9.20 Automatic Protection Group Selection .... 42 7.5 Display Groups...... 26 9.21 Fail to Operate Under Protection ...... 42 7.6 Selecting Displays...... 26 10 Event Log ...... 43 7.7 Changing Settings...... 26 10.1 Event Log Display Updating...... 43 7.7.1 Use of Quick Keys ...... 26 10.2 Protection Generated Events...... 43 7.7.2 Use of SELECT, ½ ¾and MENU Keys ...... 27 10.3 Loss of Supply Events ...... 44 7.8 Password Protection ...... 27 11 Power System Measurements... 45 8 Work Tags and Control Mode ... 29 11.1 Switchgear Terminal Designation ...... 45 8.1 Local/Remote Mode...... 29 11.2 Power Flow Direction ...... 45 8.1.1 Local Mode ...... 29 11.3 Real Time Displays...... 45 8.1.2 Remote Mode ...... 29 11.4 Averaged Data Displays...... 46 8.2 Work Tagging ...... 29 11.5 Maximum Demand Data Displays...... 46 8.2.1 Removing a Work Tag ...... 30 8.3 Definition of Local or Remote Access ..... 30 12 Communications Interfaces ...... 47 12.1 V23 Interface...... 47 9 Protection...... 31 12.2 RS232 Interface...... 47 9.1 Overview ...... 31 12.3 Radio/Modem Power...... 47 9.2 Multiple Groups of Protection Settings.... 31 12.4 Connections to Electronics Compartment 48 9.3 Operator Settings...... 31 9.4 Protection Control ...... 31 9.5 Sensitive Ground Fault Control ...... 31 ii Table of Contents Siemens Power Transmission & Distribution, Inc. 13 Accessories ...... 49 16.4 Fault Finding ...... 72 13.1 Centurion System Software ...... 49 16.4.1 Control Cable Check ...... 72 13.2 Input Output Expander (IOEX) Card ...... 49 16.4.2 Switchgear Check ...... 72 13.2.1 Inputs ...... 49 16.4.3 Control Cubicle Check ...... 73 13.2.2 Outputs ...... 50 16.5 Replacement of Electronic Modules ...... 73 13.2.3 System Healthy Indicator ...... 50 16.6 Replacement of Cables...... 73 13.2.4 Power Consumption ...... 51 16.7 Installing or Replacing Heater...... 73 13.3 Test and Training Set (TTS)...... 51 16.8 Abnormal Operating Conditions...... 73 13.4 Manual Operation Set ...... 51 16.8.1 Low Power Mode ...... 73 13.5 Remote Control Panel...... 51 16.8.2 Excess Close Operations ...... 74
14 Receiving and Handling...... 53 A IEC255 Inverse Time 14.1 Receiving ...... 53 Protection Tables ...... 75 14.2 Inspection...... 53 B IEEE Inverse Time 14.3 Shipping Damage Claims...... 53 Protection Tables ...... 77 15 Installation ...... 55 C TCC Cross Reference Table ...... 79 15.1 Unpacking & Checking...... 55 15.2 Unpacking Procedure...... 55 D Recloser Inverse Time TCCs .....81 15.3 Plugging and Unplugging Control Cable . 57 15.4 Testing & Configuring...... 57 E System Status Pages ...... 91 15.5 Transport to Site...... 59 15.6 Tools Required ...... 59 F Protection Pages ...... 93 15.7 Parts Required (Not supplied by Siemens) ...... 59 G Replaceable Parts & Tools ...... 95 15.8 Site Procedure ...... 59 15.9 HV Connections ...... 60 H Standard Event Types...... 97 15.10 Surge Arrester Mounting and Terminating ...... 61 I Maintenance Event Types...... 101 15.11 Grounding ...... 62 15.12 LV Auxiliary Power from LV Conductors .. 67 J Control Cubicle Schematics...... 103 15.13 LV Auxiliary Power from Dedicated Utility Transformer ...... 68 K Equipment Weights and 15.13.1Auxiliary Power from Crate Dimensions ...... 113 Integrated Transformer ...... 68 15.14 Protection of Radio Equipment ...... 68 L Pinouts ...... 115 15.15 IOEX Cabling ...... 68 15.16 Transformer Switching...... 68 Glossary ...... 117
16 Maintenance...... 71 Index ...... 119 16.1 Recloser Maintenance ...... 71 16.2 Control Cubicle Maintenance...... 71 16.2.1 Control Cubicle Cleaning ...... 71 16.2.2 Battery Replacement ...... 71 16.2.3 Protection and Operation Check ....71 16.2.4 Door Seal ...... 71 16.3 Battery Care...... 71
Siemens Power Transmission & Distribution, Inc. iii iv Table of Contents Siemens Power Transmission & Distribution, Inc. List of Figures
Figure 1: Recloser Features ...... 13 Figure 21: Unplugging the Control Cable ...... 56 Figure 2: Control Cubicle ...... 16 Figure 22: SCEM Compartment ...... 58 Figure 3: Equipment Panel ...... 17 Figure 23: H.V. Cable Termination ...... 61 Figure 4: Radio Mounting Space (dim in mm) ...... 18 Figure 24: Recloser End Mounting and Dimensions ..63 Figure 5: Control System Block Diagram ...... 23 Figure 25: End Mounting Example ...... 64 Figure 6: Operator Control Panel ...... 25 Figure 26: Center Mounting and Dimensions ...... 65 Figure 7: Display Page Organization ...... 28 Figure 27: Center Mounting Example ...... 66 Figure 8: Time Multiplier, effects on the Figure 28: L.V. Auxiliary Supply Connection ...... 67 Inverse Curve ...... 33 Figure 29: Common Grounding and LV Supply ...... 69 Figure 9: Additional time, effects on the Figure 30: Utility Aux Transformer and Integrated Inverse Curve ...... 33 External Transformer ...... 70 Figure 10: Instantaneous, effects on the Figure 31: Control Cubicle Schematic 1 - Inverse Curve ...... 33 General Arrangement ...... 103 Figure 11: Minimum Time, effects on the Figure 32: Control Cubicle Schematic 2 - Inverse Curve ...... 34 Battery Loom ...... 104 Figure 12: Maximum Time, effects on the Figure 33: Control Cubicle Schematic 3 - Inverse Curve ...... 34 Main Loom Connection ...... 105 Figure 13: Threshold Element, effects on the Figure 34: Control Cubicle Schematic 4 - Inverse Curve ...... 34 Single Integrated Aux Power Supply ...... 106 Figure 14: Protection Curve modified by Minimum, Figure 35: Control Cubicle Schematic 5 - Maximum Times, and Single LV Aux Power Supply ...... 107 Instantaneous Element ...... 35 Figure 36: Control Cubicle Schematic 6 - Figure 15: Interaction between Instantaneous, Integrated Plus LV Aux Power Supply ....108 Threshold Current, and Maximum Time ....35 Figure 37: Control Cubicle Schematic 7 - Dual LV Figure 16: Composite curve changes due to different Aux Power Supply ...... 109 settings of Threshold Current Multiplier .....36 Figure 38: Control Cubicle Schematic 8 - Figure 17: Coordination between fuse and IEC 255 Heater/Thermostat Connection ...... 110 Inverse Curve using the Threshold Current Multiplier ...... 36 Figure 39: Control Cubicle Schematic 9 - Control Cable Service Drawing ...... 111 Figure 18: Effect of Inrush Current Settings on a Protection Curve ...... 39 Figure 40: Centurion Recloser to PC Cable (DB9) ...115 Figure 19: Cold Load Multiplier (CLM) settings Figure 41: Centurion Recloser to PC Cable (DB25) .115 applied to Protection Curves ...... 41 Figure 20: Plugging in the Control Cable ...... 56
Siemens Power Transmission & Distribution, Inc. v vi List of Figures Siemens Power Transmission & Distribution, Inc. 1 Introduction 1 Introduction The Centurion Recloser is a state-of-the-art, Contact the nearest Siemens representative if any electronically controlled, outdoor, three-phase Recloser additional information is desired. for pole and substation applications. The design has been optimized for easy integration into distribution automation and remote control schemes. The Centurion Recloser features vacuum interrupters that are enclosed in epoxy moldings eliminating the need Hazardous voltages. to use oil or SF gas insulation. The mechanism is 6 Will cause death, serious enclosed within a powder-coated steel tank and has a personal injury or property hot-dip galvanized steel lid. A pole-mounting bracket is damage. supplied, which makes installation quick and easy. Cables can be connected to the Recloser using parallel groove To avoid electrical shock or other clamps or cable lugs. The switchgear is operated by a low injury, this equipment must be energy magnetic actuator that is not solely dependent on installed, operated and maintained the presence of a high voltage AC supply. only by qualified persons thoroughly familiar with the equipment, The MJ-R Control is housed in a stainless steel Control instruction manuals and drawings. Cubicle designed for harsh environmental conditions. An Read and understand this instruction all-weather, user-friendly Control Panel is provided for manual before using equipment. programming and operation of the Centurion Recloser. Remote monitoring and control are available through the integral communications ports; a remote terminal unit (RTU) is not required. 1.2 Qualified Person Please note: For the purpose of this manual, a Qualified Person is one who is familiar with the installation, construction, or • Terminology in italics like this is explained in the operation of the equipment and the hazards involved. In glossary at the back of the manual. addition, this person must have the following qualifications: • Events are identified in the text by using ‘single quotes.’ Refer to Section 10: Event Log on page 43. • Training and authorization to energize, de-energize, clear, ground, and tag circuits and equipment in • References to MJ-R Control Panel display pages accordance with established safety procedures. appear as Refer to “Section Heading” on page [x]. For example, refer to Section 7: Operator Control • Training in the proper care and use of protective Panel on page 25. equipment such and rubber gloves, hard hat, safety glasses, face shields, and flash clothing in • All dimension conversions are approximate. accordance with established safety procedures. • Training in rendering first aid. 1.1 Safety The Centurion Reclosers are designed to meet all applicable ANSI, NEMA, and IEEE standards. Successful 1.3 Signal Words application and operation of this equipment depends as The signal words “Danger,” “Warning,” and “Caution” much upon proper installation and maintenance by the used in this manual indicate the degree of hazard that user as it does upon the careful design and fabrication by may be encountered by the user. These words are Siemens. defined as: The purpose of this instruction manual is to assist the • Danger - Indicates an imminently hazardous user in developing safe and efficient procedures for the situation that, if not avoided, will result in death or installation, maintenance, and use of the equipment. serious injury. • Warning - Indicates a potentially hazardous situation that, if not avoided, could result in death or serious injury. • Caution - Indicates a potentially hazardous situation that, if not avoided, may result in minor or moderate injury.
Siemens Power Transmission & Distribution, Inc. 1 1 Introduction
• Caution (without safety alert symbol) - Indicates a potentially hazardous situation that, if not avoided, may result in property damage.
1.4 Hazardous Procedures In addition to other procedures described in this manual as dangerous, user personnel must adhere to the following: • Always work only on a de-energized Recloser. The Recloser should be isolated, grounded, and have all control power removed before performing any tests, maintenance, or repair. • Always perform maintenance on the Recloser after it has been tripped and locked out (except for test of the charging mechanisms). Check to be certain that the indicator flags read OPEN and Locked Out. • Always let an interlock device or safety mechanism perform its function without forcing or defeating the device.
1.5 Field Service Operation Siemens can provide competent, well-trained field service representatives who can provide technical guidance and advisory assistance for the installation, overhaul, repair, and maintenance of Siemens equipment, processes, and systems. Contact regional service centers, sales offices, or the factory for details, or telephone Siemens Field Service at 1-800-241-4453.
2 Siemens Power Transmission & Distribution, Inc. 2 Scope of this Technical Manual 2 Scope of this Technical Manual
2.1 General page 26.) From the System Status 11 page, press SELECT and use the arrow keys to view the capability This technical manual provides details on the switchgear list. specification, and includes installation, operation, and maintenance guidelines. This manual has been carefully The capability declarations should include: prepared; however, no responsibility is assumed for loss Centurion Recloser Manual RCIM-2200A or damage incurred by the purchaser or user due to any error or omission in this document. Likewise, this If not, please contact Siemens Power Transmission & document, while thorough, is not all-inclusive. It is not Distribution or your local distributor. possible to include every equipment detail, or instructions for every equipment variation or contingency potentially incurred during installation, operation, or maintenance of 2.5 Firmware Identification System this product. For additional information of specific The firmware resident on the MJ-R Control contains two problems or requirements, please contact your local important identification numbers. Siemens Power Transmission & Distribution representative. • The firmware version that has the form XXX-XX.XX. This number identifies the firmware loaded into non-volatile program memory. 2.2 Equipment Versions Covered by • The configuration number that has the form XXXXX. this Manual This number identifies the database configuration This manual applies to the following equipment: that controls device functionality. For example, a configuration option determines whether text on the • Centurion Recloser: Model C1512, C2712 MJ-R Operator Panel is to be displayed in English or in another language. • MJ-R Control: Model PTCC-TEM, PTCC-MOD, PTCC-TRO Note1: Implementing functionality changes to the MJ-R Control may require configuration changes, firmware If the model numbers shown on the equipment rating upgrades, or both. plates do not match, this manual is not applicable to your product. For additional information of specific problems or Note 2: When contacting Customer Service or your distributor for technical product support, please have both the requirements, please contact your local Siemens Power version number and the configuration number readily Transmission & Distribution representative. available at the time of the call. Without this information, the Customer Service representative will be unable to provide a meaningful level of support. 2.3 Control Version The firmware version and configuration numbers appear This manual only applies to CAPM4-based controls (the on the Operator Control Panel display on System Status CAPM is explained in Section 6). “CAPM4” appears on 8. (Refer to Appendix E: System Status Pages on page the operator display momentarily when the Control Panel 91. Refer to Section 7: Operator Control Panel on page 25 is turned on. (Refer to Section 7: Operator Control Panel for instructions on the Operator Control Panel.) on page 25.) A typical example of firmware version and configuration If “CAPM4” does not appear on the display, this manual is follows: not applicable to your control. Contact your Siemens representative for more information. Firmware 024-45.00 Configuration 10087 2.4 Firmware Versions Covered by this Manual 2.6 Related Documents The MJ-R Electronic Control is a microprocessor-based design. The firmware version and configuration Not detailed in this document are the following, which are determine the functionality of the MJ-R Control. The covered by their own manuals: manual and firmware applicable to your MJ-R Control can • Centurion System Software (CSS) - Used to be viewed on the display panel by referencing the configure the Recloser from a PC. Capability list on the Operator Control Panel. (Refer to the System Status page shown in “7.5 Display Groups” on
Siemens Power Transmission & Distribution, Inc. 3 2 Scope of this Technical Manual
• Test and Training Set (TTS) - Used primarily to test Windows NT, and utilizes many of the operating MJ-R Controls or for training. system time functions. BSI rules 1, 2 and 3 have been tested for this product on Windows NT version • Specific Protocol Implementation Documents - 4.0 service pack 3 operating system. No Technical reference for remote communications. responsibility is undertaken for the Year 2000 • Workshop & Field Test Procedures - Instructions for compliance of these operating systems (Microsoft testing the switchgear. Windows 3.1x, Windows 95, Windows 98, and Windows NT) now or in the future, or for the effect • CAPM Replacement Procedure - Instructions on they may have on the CSS Year 2000 compliance. removing and replacing electronic components. • British Standards Institute (PD2000-1:1998) rules: For further information on these products, contact Siemens Power Transmission & Distribution or your local Year 2000 conformity shall mean that neither distributor. performance nor functionality is affected by dates prior to, during and after year 2000. Rule 1. No value for current date will cause any 2.7 Year 2000 Compliance Statement interruption in operation. For Centurion Reclosers with Rule 2. Date-based functionality must behave type MJ-R Control consistently for dates prior to, during and after year 2000. Tests have been performed on the Centurion Recloser Rule 3. In all interfaces and data storage, the century with type MJ-R Control (hereafter referred to as the in any date must be specified either explicitly “Centurion Recloser”) to determine the performance with or by unambiguous algorithms or inferencing respect to Year 2000 issues. These products are Year rules. 2000 Compliant. Rule 4. Year 2000 must be recognized as a leap year. The Centurion Recloser has been examined for Year The information provided herein shall not become a part 2000 conformity to the British Standards Institute Year of or modify prior or existing agreement, commitment or 2000 Conformity Requirements as follows: relationship. Any sales contract for the products addressed contains the entire obligation of Siemens • The MJ-R Recloser control (firmware versions V021- Power Transmission & Distribution, Inc. The warranty 00.00 and above) (CAPM4) comply with BSI rules 1, contained in the contract is the sole warranty of Siemens 2, 3 and 4. Power Transmission & Distribution, Inc. The statements • All Centurion System Software (CSS) versions 1.0 contained herein do not create new warranties or modify and higher comply with BSI rules 1, 2, 3, and 4. any existing warranty. These statements are further explained below: NOTICE: This is a Year 2000 Readiness Disclosure under the Year 2000 Information and Readiness • Type MJ-R controller compliance: Disclosure Act. The controller software represents years explicitly as “years since 1970” and has a valid range from 1 Jan 1970 to 31 Dec 2069. BSI rules 1, 2, and 3 have been tested for all years in this period. In addition, rollover from 31 Dec 2069 back to 1 Jan 1970 has been explicitly tested to ensure no interruption in operation of the controller by any date (rule 1). Testing included all internal date references plus those shown on the Operator Control Panel plus external date references to CSS. Particular external interfaces using various communications protocols which may have time stamping such as DNP3 are tested separately for compliance and have their compliance statement in the relevant technical manual. • Centurion System Software (CSS) compliance: Centurion System Software runs under Microsoft Windows 3.1x, Windows 95, Windows 98, and
4 Siemens Power Transmission & Distribution, Inc. 3 Specification 3 Specification This section of the manual provides a detailed description Short Time Current Recovery Time...... 180s and serves as the product specification for the Centurion Rated Impulse Withstand Voltage (15 kV) ...... 110kV Recloser. For a complete understanding of the product, it Rated Impulse Withstand Voltage (27 kV) ...... 125kV is essential to also read all other sections of the manual Opening/Closing Mechanism...... Latching Magnetic Actuator that describe equipment operation. D.C. Resistance Terminal/Terminal ...... <120 micro-Ohm Tank Construction ...... Galvanized Mild Steel • For the following, please note that where timing, ...... and Powder Coated Mild Steel current, voltage or other measurement accuracy is Bushings/VI Housings...... Outdoor Cycloaliphatic Epoxy Resin given, the measurement accuracy is a percentage of Maintenance Interval (Note 1) ...... 5 Years Grounding (Note 2) ...... 12mm (0.472 in) Stud Provided the measurement value, unless otherwise stated. Applicable Standards...... ANSI C37.60
• Appendix K: Equipment Weights and Crate Note 1: In high contamination environments, periodic Dimensions on page 113 gives the weight of the checking/cleaning of insulators should be carried out Recloser, control cubicle, and other equipment. as required.
Note 2: Grounding details in “15.11 Grounding” on page 62 must be strictly adhered to. 3.1 Environmental Operating Temperature (Note 1) ...... -30 to +50°C 3.2.3 Endurance Capability Operating Humidity ...... 0 to 100% Operating Solar Radiation...... 1.1kW/m² max Operating Altitude ...... 1000m Table 1 Table Endurance Capability Note 1: Temperature range depends on control cubicle Operations version. See “5.1 Tropical, Moderate and Temperate Versions” on page 15. Mechanical Life 10,000
Note 2: For higher altitudes, derate Recloser in accordance Contact Life at: 630A 10,000 with ANSI C37.60. 2kA 2500 3.2 Recloser 6kA 280 Refer to “Figure 24 Recloser End Mounting and 12.5kA 64 Dimensions” on page 63 and “Figure 26 Center Mounting and Dimensions” on page 65 for physical dimensions. Note 1: Recloser duty cycle ratings comply with ANSI C37.60. 3.2.1 Basic Timings Note 2: Contact wear is automatically calculated for each interrupter by the electronic control based on fault Opening Time (Note 1)...... < 35ms current and mechanical operations. The remaining Arcing Time (Note 1)...... < 20ms contact life is shown on the operator control panel. Clearing Time on Instantaneous protection for Refer to “4.7 Contact Life” on page 12 for more detail. fault > 4 x Trip Current setting (Note 1) ...... < 70ms Time to contact part from receipt of trip command by operator, telemetry protocol or IOEX...... < 300ms 3.2.4 Sequence Capability Time to contact touch from receipt of close command Minimum allowable timing sequence at full short circuit current by operator, telemetry protocol or IOEX...... < 300ms rating Open-0.5s-Close/Open-2s-Close/Open-2s-Close/Open followed Note 1: The precise definitions of these times are given in by 300-second recovery time. ANSI C37.60.
3.2.2 Electrical Ratings Rated Maximum Voltage (15 kV)...... 15.5kV Rated Maximum Voltage (25 kV)...... 27kV Rated Continuous Current ...... 630A Rated Frequency...... 50/60Hz Rated Cable Charging Interrupting Current ...... 20A Rated Line Charging Interrupting Current...... 5A Rated Transformer Magnetizing Interrupting Current...... 22A Rated Symmetrical Interrupting Current ...... 12.5kA Rated Asymmetrical Making Current (Peak) ...... 32.5kA Rated Symmetrical Making Current (RMS)...... 12.5kA Short Time Current for 3 Seconds ...... 12.5kA
Siemens Power Transmission & Distribution, Inc. 5 3 Specification
3.2.5 Creepage and Clearances 10 Recloser operations. When depleted, the battery is disconnected. Insulator Material Type Outdoor Note 3: Battery replacement interval is influenced by ambient Cycloaliphatic Epoxy temperature. Refer to “16.3 Battery Care” on page 71. Resin Note 4: Grounding requirements in “15.11 Grounding” on mm in page 62 must be met.
Creepage distance 780 30.75 Note 5: Temperature compensated at 48mV/°C.
Taut string clearance 295 11.50 3.3.1 Radio/Modem Provisions phase/ground (center The Centurion Recloser is designed to accommodate a mount bracket) radio, modem, or other communications equipment Taut string clearance 295 11.50 supplied by the end-user or optionally by Siemens Power phase/ground (end mount Transmission & Distribution. DC power, space, and data bracket) – 27kV Rating interfaces provided within the control cubicle are as follows: Taut string clearance 265 10.25 DC Power Supply Voltage (user selectable) ...... 5 to 15VDC phase/ground (end mount DC Power Supply Max Continuous Current...... 3A bracket) – 15.5kV Rating DC Power Supply Max Current...... 5A for 30 sec with 20% duty cycle Taut string clearance 325 12.75 Radio/Modem Space on phase/phase Radio Panel ...... 330 x 215 x 85mm(13"x8"x3.5" ± 0.25") Radio/Modem Interface (Note 1)...... V23 or RS232 Taut string clearance 375 14.75 Radio/Modem Power Shutdown Time phase/phase centers (user selectable) ...... 1 to 1440 minutes Timing Accuracy ...... ±10s
Note: Taut string clearance = Strike distance Note 1: Further details in “12.3 Radio/Modem Power” on page 47. 3.2.6 Current Transformers Ratio...... 2000:1 3.3.2 Control Panel Accuracy (10 - 630A) ...... (whichever is greater) ±1% ±1A Local Operator Control is through the Operator Control Accuracy (630 - 12,500A) ...... ±5% Panel. Refer to later sections. Note: The CT ratings are supplied for information only. The integral CTs are not designed for connection to user-supplied 3.3.3 Control Electronics - Thermal Ratings components or equipment. The Control electronics meet or exceed device ratings as follows: 3.3 Control Cubicle Continuous Primary Current ...... 800A Short Time Primary Current ...... 12.5kA for 3s Refer to Figure 2 for physical dimensions. Short Time Current Recovery Time...... 60s Standard Control Cable Length (Note 1)...... 7m (23 ft) Recloser Operations Maintenance Interval (Note 3)...... 5 Years (Note 1) ...... 20 in 1 minute, 1 per minute thereafter Auxiliary Supply Voltage (Low voltage AC main supply)...... Input Tolerance +10 -20% Note 1: Further details in “16.8 Abnormal Operating Auxiliary Supply Rating ...... 50 VA Conditions” on page 73. Battery Rating ...... 24V 7.2 AH Battery Hold-Up Time when fully charged (Note 2) ...... 5 Days Battery Recharge Time 3.4 Protection and (new battery to 80% nominal capacity) ...... 10 Hours Auto-Reclose Functions Battery Replacement Interval (Note 3)...... 5 Years Battery Low Voltage (Note 5) ...... 23V The protection and auto-reclose functions are described Battery High Voltage (Note 5) ...... 32V in the following sections. Two sets of protection settings Grounding (Note 4) ...... 10mm (2/5 in) Ground Stud are available. For a full description of protection functions, Heater Power (where equipped) ...... 120W refer to later sections. Please also note the following: Note 1: Control cable length options: 4, 7, and 11 meters, • The trip current setting must be selected separately approx 13, 23, & 36 feet, respectively. for the phase, ground, and sensitive ground fault Note 2: Assumes no radio/modem power drain. At the end of (SGF) protection. When set, the trip current settings the holdup period, power is available for a minimum of apply to each trip in a sequence.
6 Siemens Power Transmission & Distribution, Inc. 3 Specification
• Time current curves, trip multipliers, and other Note 1: Current accuracy applies to protection relay function parameters must be individually selected for each only and excludes accuracy of current transformers. trip operation in a protection sequence. Identical settings for each operation can be chosen. 3.4.4 Sensitive Ground Fault Protection (SGF) 3.4.1 Inverse Time Protection SGF is available as an additional protection element and Time Current Curves (TCCs) ...... refer to Appendix A, B, & C operates only as definite time element. The number of Phase Trip Setting Range ...... 10 to 1260A SGF trips in a sequence is user selectable. Ground Trip Setting Range...... 10 to 1260A Trip Setting Resolution ...... 1A SGF Trip Setting Range: ...... 4-20A Trip Setting Accuracy (Note 2) ...... 5% SGF Trip Setting Resolution ...... 1A Maximum Current for which curve applies ...... 12.5kA SGF Trip Setting Accuracy (Note 2)...... Maximum Trip Setting Multiple for which curve applies...... 30 ...... (whichever is greater) ±5% or ±0.5A Time Multiplier...... 0.05 to 2 SGF Operating Time ...... 0.1 to 100s Time Multiplier Resolution...... 0.01 SGF Operating Time Resolution...... 0.1s Maximum Time to Trip (Note 3)...... 2 to 180s SGF Operating Time Accuracy (Note 1)...... ±50ms Maximum Time to Trip Setting Resolution...... 0.1s SGF Filter Attenuation at 150Hz...... >28dB Minimum Time to Trip (Note 3)...... 0 to 2s SGF Trips in sequence to lockout ...... 1 to 4 Minimum Time to Trip Setting Resolution...... 0.01s Note 1: Timing refers to time to initiate operation of switchgear. Additional Time to Trip (Note 4)...... 0 to 2s Switchgear opening and closing times are additional. Additional Time to Trip Setting Resolution ...... 0.01s Refer to “3.2.1 Basic Timings” on page 5. Phase Threshold Multiplier (Note 3) (Note 5)...... 1 to 10 Resolution of Multiplier Setting...... 0.1 Note 2: Current accuracy applies to protection relay function Ground Threshold Multiplier (Note 3) (Note 5)...... 1 to 10 only and excludes accuracy of current transformers. Resolution of Multiplier Setting...... 0.1 Timing Accuracy (Note 1) (whichever is greater) .. 5% or ±20ms 3.4.5 Cold Load Pickup Note 1: Timing refers to time to initiate operation of switchgear. This is an additional protection feature. Cold Load Pickup Switchgear opening and closing times are additional. modifies the operation of Inverse Time and Instantaneous Refer to “3.2.1 Basic Timings” on page 5. Protection. Note 2: Current accuracy applies to protection relay function Cold Load Multiplier Range ...... 1 to 5 minutes only and excludes accuracy of current transformers. Cold Load Multiplier Resolution ...... 0.1 minutes Note 3: Applies to inverse time and instantaneous protection Cold Load Time Constant Range ...... 1 to 480 minutes only. Cold Load Time Constant Resolution ...... 1 minute Timing Accuracy ...... ±1 minute Note 4: Applies to inverse time protection only. Note 5: A trip is inhibited when the line current < “trip current 3.4.6 Inrush Restraint setting” x threshold multiplier. This is an additional protection feature. Inrush Restraint modifies the operation of Inverse Time and Instantaneous 3.4.2 Definite Time Protection Protection. This feature can replace any phase or ground TCC. A trip Inrush Restraint Multiplier Range ...... 1 to 30 sec current setting must also be selected. Inrush Restraint Multiplier Resolution ...... 0.1sec Definite Time Range ...... 0.5 to 100.0 sec Inrush Restraint Time Range...... 0.05 to 30 sec Definite Time Resolution ...... 0.1 sec Inrush Restraint Time Resolution ...... 0.05 sec Timing Accuracy ( Note 1)...... ±50ms Timing Accuracy (whichever is greater) ...... 5% or ±20ms
Note 1: Timing refers to time to initiate operation of switchgear. 3.4.7 Loss Of Phase Protection Switchgear opening and closing times are additional. Refer to “3.2.1 Basic Timings” on page 5. This is an additional protection feature, which operates independently of all other protection elements. 3.4.3 Instantaneous Protection Loss of Phase Threshold Voltage range ...... 2 to 15 kV This feature can modify or replace any phase or ground Loss of Phase Threshold Voltage setting resolution ...... 1 V TCC. A trip current multiplier must also be selected. Loss of Phase Threshold Voltage accuracy (Note 1)...... (whichever is greater) 5% or ±250V Multiplier of Trip Setting (applies to Loss of Phase Time range...... 0.1 to 10 sec both phase and ground) ...... 1 to 30 Loss of Phase Time resolution ...... 0.1 sec Resolution of Multiplier Setting...... 0.1 Loss of Phase Time accuracy...... ±50ms Maximum Effective Setting...... 12.5kA Trip Setting Accuracy (Note 1) ...... ±10% Note 1: Includes accuracy of voltage transformers in switchgear. Transient Overreach for X/R < 10...... <5% Transient Overreach for X/R > 10...... <10%
Siemens Power Transmission & Distribution, Inc. 7 3 Specification
3.4.8 Live Load Blocking 3.5 Power System Measurements This is an additional protection feature, which operates independently of all other protection elements. For live 3.5.1 General load blocking to operate properly, the switchgear must be HV line measurements on all three phases are made as installed with the load side connected to the (I, II, III) follows: terminals of the Recloser. Voltage Range (True RMS Phase/Ground) ...... 2 to 15kV Note: For information about Live Load Threshold Voltage, Voltage Resolution...... 1 V refer to “3.5.1 General” on page 8. Voltage Accuracy (Note 1) (Note 2) ...... 2.5% ±25V Live Terminal Threshold Voltage range (Note 4)...... 2 to 15 kV 3.4.9 High Current Lockout (HCLO) Live Terminal Threshold Voltage setting resolution (Note 4). 1 V Live Terminal Threshold Voltage accuracy This is an additional protection element. The user selects (Note 1) (Note 4)...... 5% ±250V the trip in the sequence in which HCLO will operate. Phase Current Range (True RMS) (Note 2)...... 2.5 to 800A Ground Current Range (True RMS) (Note 2)...... 1 to 800A Maximum Effective Setting...... 12.5 kA Current Resolution...... 1A Minimum Effective Setting...... 10A Phase Current Accuracy (Note 1) Setting Resolution...... 1A (whichever is greater).... 2.5% or ±2A over range 10 to 800A Accuracy ...... ±15% Ground Current Accuracy (Note 1) (whichever is greater)..... 2.5% or ±2A over range 1 to 800A 3.4.10 Automatic Protection Group Selection Maximum Fault Current Measurement (Note 1) ...... ±15% This is an additional protection feature. Apparent Power Range (Note 5)...... 0 to 36 MVA Apparent Power Resolution (Note 5) ...... 1 kVA Auto Change Time ...... 10 to 180 sec Apparent Power Accuracy Auto Change Time Resolution ...... ±1 sec (Notes 1 and 5) ...... ±5% over range 20 to 800A Note: Automatic Protection Group Selection is available only Real Power Range (Note 3)...... -36 to 36 MW in code versions 027-00.00 or later. Real Power Accuracy (Notes 1 and 3) .. ±5% of apparent power Reactive Power Range (Note 5) ...... 0 to 36 MVAR Reactive Power Resolution (Note 5) ...... 1 kVAR 3.4.11 Auto-Reclose Reactive Power Accuracy Trips in Sequence to Lockout ...... 1 to 4 (Notes 1 and 5) ...... ±5% of apparent power Reclose Time after First Trip in Sequence ...... 0.5 to 180 sec Unsigned Power Factor ...... 0.5 to 1.0 Reclose Time after Second and Power Factor Resolution...... 0.01 Third Trips in Sequence...... 2 to 180 sec Power Factor Accuracy ...... ±0.05 Reclose Time, Timing Resolution ...... 0.1 sec Measurement Filter Time Constant ...... 2s Reclose Time, Timing Accuracy (Note 1) ...... ±0.1 sec Measurement Update Rate...... 0.5s Single Shot Reset Time ...... 1 to 180 sec Note 1: Includes accuracy of switchgear current and voltage Single Shot Reset, Timing Resolution...... 1sec transformers. Single Shot Reset, Timing Accuracy ...... ±1 sec Sequence Reset Time...... 5 to 180 sec Note 2: Measurements are zeroed for currents less than lower Sequence Reset, Timing Resolution...... 1 sec value in range. Sequence Reset, Timing Accuracy ...... ±1 sec Note 3: Used to accumulate kWh reading for weekly maximum Note 1: Timing refers to time to initiate operation of switchgear. demand data. Switchgear opening and closing times are additional. Refer to “3.2.1 Basic Timings” on page 5. Note 4: Used for bushing Live/Dead display, Live Load Blocking, and Loss of Supply detection. 3.4.12 Other Protection Features Note 5: In database for transmission by a protocol. Fault Reset Time (Note 1) ...... 50 to 800ms Fault Reset Time Accuracy ...... ±20ms Sequence Coordination...... Available
Note 1: Applies to all protection elements.
3.4.13 Loss of Primary Voltage Detection Live Terminal Threshold Voltage ...... Refer to “3.5.1 General” on page 8 Loss/Restoration of Voltage Timeout ...... 0.1 to 100 sec Loss/Restoration of Voltage Timing Accuracy...... -0ms/+50 ms
8 Siemens Power Transmission & Distribution, Inc. 3 Specification
3.5.2 Demand History Demand averaging periods ...... 5, 15, 30, 60 minutes The minimum history storage is shown in the table below. Table 2
Sample period 5153060 (minutes)
Minimum 26 78 156 312 storage time (days)
3.5.3 Event History Minimum number of typical events stored in the event history file ...... 3,000 events
Siemens Power Transmission & Distribution, Inc. 9 3 Specification
10 Siemens Power Transmission & Distribution, Inc. 4 Recloser Construction and Operation 4 Recloser Construction and Operation The Recloser, shown in Figure 1 “Recloser Features” on 4.3 Line Connections page 13, utilizes ganged vacuum interrupters that are insulated and housed inside cycloaliphatic epoxy resin High voltage terminals are 20 mm diameter tin-plated moldings. Operation, for both trip and close, is by a single, copper stems with M10 x 1.5 end threads. Refer to “15.9 low voltage, magnetic actuator. The magnetic actuator is HV Connections” on page 60. Compatible connections operated by capacitors in the Control Cubicle, which are can be either: charged and discharged by the electronic control. • Parallel groove connectors suitable for the cable The pointer on the side of the tank indicates the position type, i.e., bi-metallic versions compatible with copper of the Recloser. or aluminum cables. • Standard lugs with 10 mm diameter holes. This connection is generally for smaller cables no larger 4.1 Recloser Mounting than 70 mm2 (2/0). These are also available in bi- Two Recloser pole mounting brackets are available. The metallic versions. center-mounting bracket is standard and has a point of attachment that centers the Recloser on the pole. A side- mounting bracket that positions the Recloser off to one 4.4 Surge Arresters side of the pole is optionally available. The mounting Surge arresters are recommended to protect the brackets are compatible with both wood and concrete Recloser from overvoltage. Surge arrester brackets poles. See Figure 24 through Figure 27 for more details. compatible with the pole mounting brackets are optionally Also, refer to Section 15: Installation on page 55 for site available. Refer to Figure 24 “Recloser End Mounting and installation details. Dimensions” on page 63. A substation frame is also optionally available. Contact your local representative for details. 4.5 Control Cubicle Connection A control cable links the bottom of the Recloser to the 4.2 Manual Trip Control Cubicle. Plug-in terminations are used at both the The Manual Trip Ring is located on the underside of the Control and Recloser ends of the cable. The Control tank. Pulling the Trip Ring down with a hook stick trips and cable is flexible and can be orientated to suit the locks out the Recloser. The Manual Trip Ring remains in installation. the down position and the Recloser remains in lockout Current transformers and voltage screens embedded in until the Trip Ring is returned to the normal position. In the the epoxy resin moldings send signals to the Control down position, the Recloser is both mechanically locked which monitors phase currents, ground current, phase open and electronically interlocked to prevent any close voltages and ground voltage. The voltage screens are attempts initiated at the Control Panel or from a remote embedded in three moldings on the side labeled “I, II, III.” location. (Refer to Figure 1.) If the Control cable is disconnected (at either end), the CTs and voltage screens are automatically shorted by circuitry on the SCEM card inside the Recloser.
Hazardous voltages. 4.6 Recloser Memory Will cause death, serious personal injury or property Each Recloser utilizes on-board memory to record data damage. specific to that device. This information includes the following, which can be viewed on the operator display: Always follow proper safety procedures. De-energize the •Serial Number Recloser, establish visible • Interrupting Rating disconnects on each side of the • Continuous Current Rating Recloser, and ground the Recloser • Number of Mechanical Operations (incremented on terminals before working on this close) equipment. Do not rely solely on the • Rated Voltage manual handle or the position • Contact Life Remaining (by phase) indicator to ensure a line has been de-energized.
Siemens Power Transmission & Distribution, Inc. 11 4 Recloser Construction and Operation
4.7 Contact Life The vacuum interrupters in the Centurion Recloser meet the duty ratings given in “3.2 Recloser” on page 5. Load and fault currents are measured for each phase, each time the interrupter contacts open. The remaining life for each interrupter is then calculated and stored in device resident memory. The MJ-R Control reads this information and it appears on the Operator Control Panel. If the remaining life reaches zero for any phase, the Recloser should be removed from service and considered for retirement. The remaining life of each vacuum interrupter is stored in memory in the Recloser and not in the connected Control. As a result, Controls can be separated from Reclosers (as is typical during some maintenance practices) without loss of this critical information. This design also avoids the need to rely on mechanical counters, manual logs, statistical data, or other methods to manually calculate the remaining life of a specific Recloser.
12 Siemens Power Transmission & Distribution, Inc. 4 Recloser Construction and Operation
Figure 1 Recloser Features
Siemens Power Transmission & Distribution, Inc. 13 4 Recloser Construction and Operation
14 Siemens Power Transmission & Distribution, Inc. 5 Control Cubicle Construction 5 Control Cubicle Construction The MJ-R Control and Cubicle are designed for pole and • The Electronics Compartment houses the Control substation applications. The Cubicle features a unique and Protection Module (CAPM), and the Operator hinged hatch for all weather access only to the Operator Panel Subsystem (OPS). This compartment is Panel, and a traditional full-sized door, for access to the sealed to protect the electronics from airborne entire compartment. Each can be separately padlocked contamination. for security. Refer to Figure 2 “Control Cubicle” on page 16 for Cubicle dimensions. • The Battery Compartment houses two 12-Volt batteries. • The Radio-Mounting Tray is used to mount the optional radio, modem (where equipped) or Remote IOEX card. (Refer to “13.2 Input Output Expander Unauthorized Access to Control (IOEX) Card” on page 49.) The hinged tray folds Cabinet. down to expose the radio/modem and can be detached to allow workshop mounting of the May cause mis-operation or communication equipment. equipment damage. • The Control Cable Entry Module provides Padlock the control cabinet when termination and filtering for the control cable, and is unattended to prevent unauthorized housed behind a removable panel. The incoming access by unqualified personnel. control cable connects to P1 of the CCEM, the internal wiring loom N03-505 connects to P2 of the CCEM. 5.1 Tropical, Moderate and • The Heater, when equipped. (The Heater is Temperate Versions standard with the temperate version Control Tropical, moderate and temperate climate versions of the Cubicle.) Control Cubicle are available. • The tropical version is well ventilated and is suitable for climates where the ambient temperature can reach 50°C, only occasionally falls below 0°C, and has a low temperature limit of -10°C. • The moderate version has reduced ventilation, is used in environments where the temperature rarely exceeds 40°C, occasionally falls below -5°C, and has a low temperature limit of -15°C. • The temperate version is standard. It features reduced ventilation and is equipped with a heater. It is suitable to climates where the ambient temperature rarely exceeds 40°C or falls below -30°C.
5.2 Equipment Panel The equipment panel inside the Cubicle Compartment has the following key features: (Refer to Figure 3 “Equipment Panel” on page 17.) • The Mains Compartment houses the LV transformers and circuit breakers for both the batteries and the auxiliary supply.
Siemens Power Transmission & Distribution, Inc. 15 5 Control Cubicle Construction
Figure 2 Control Cubicle
16 Siemens Power Transmission & Distribution, Inc. 5 Control Cubicle Construction
Figure 3 Equipment Panel
Siemens Power Transmission & Distribution, Inc. 17 5 Control Cubicle Construction
The entire Equipment Panel can be removed by lower portion of the Cubicle. The lower temperature disconnecting the external connections and unbolting the environment aids in maximizing battery life. panel plate. A rubber duct that houses the internal wiring is located behind the Equipment Panel along the center of the Control Cubicle. The Cubicle components are 5.3 Radio Mounting Tray Space arranged to position the power supply in the upper portion The space on the radio tray for user communication of the Cubicle while the batteries are positioned in a equipment is shown in Figure 4. cooler ambient environment, near the air vents, in the
Figure 4 Radio Mounting Space (dim in mm) steel surfaces where the effects are negligible. Surface moisture dissipates quickly due to ventilation and the heater, and any accumulation drains through the bottom 5.4 Sealing & Condensation of the cabinet. The vents of the Control Cubicle are screened to prevent vermin entry. The Cubicle is insulated and the door is sealed with a replaceable foam gasket. The Cubicle is not 5.5 Mounting & Grounding designed however, to prevent water entry under all The Control Cubicle is mounted on the pole with bolts or conditions, e.g., open hatch during inclement weather. strapping and is connected to the Recloser by the Instead, the design allows any water entering the cabinet detachable control cable. to drain through the bottom of the cabinet without affecting the electrical or electronic components. Any surface moisture dries rapidly due to ventilation and the heater. Marine grade stainless steel and other corrosion resistant substrate materials are used extensively to protect against corrosion when moisture and airborne contaminants are present. Condensation will occur naturally during typical atmospheric conditions such as high humidity and temperature cycling. The Control Cubicle is designed, however, to allow this condensation to form on stainless
18 Siemens Power Transmission & Distribution, Inc. 5 Control Cubicle Construction
The Recloser and Control Cubicle grounding schemes 5.7 Control Power Supply Options must be strictly adhered to as detailed in “15.11 Grounding” on page 62. The Control Cubicle can be manufactured in a number of different auxiliary supply configurations such as: • Single Aux Supply from LV • Single Aux Supply from HV Hazardous voltages. • Dual Aux Supplies from LV Will cause death, serious • Dual AUX Supplies, one LV, one HV personal injury or property damage. The configuration is indicated on the Control Cubicle nameplate as: Ground the Recloser frame, surge arresters (if any) and Control Cubicle • AUX SUPPLY 120VAC (or other voltage) for LV in accordance with all grounding supply instructions in this instruction Or manual. • AUX SUPPLY INTEGRATED for integrated HV supply. 5.6 Control Power The miniature circuit breakers (MCB) at the top of the Control Cubicle in the Mains Compartment protect the Control power, via an external source, is required to battery and the auxiliary supply. maintain the charge on the sealed lead-acid batteries; the batteries provide standby power when external power is When dual supplies are provided, two MCBs, one for lost. The status of both the external supply and the each supply, are also provided. battery supply is monitored by the MJ-R Control. With the single LV supply configuration, the Control A Low Power Mode is activated when the batteries are Cubicle is factory equipped with one MCB and one AUX nearing depletion due to the loss of the external supply. In OUT (power outlet). This is shown in Figure 3 “Equipment this mode, power consumption is minimized while a Panel” on page 17. reduced level of functionality is maintained. In effect, a low power event is logged in the event recorder, the radio When equipped for Integrated HV Supply, the Aux MCB supply is shut down, and the Control trips (once) and should always be closed during operation or testing, even locks out if a protection operation occurs. Refer to “16.8.1 if the auxiliary supply transformer is not energized. This Low Power Mode” on page 73. ensures correct operation of the switchgear memory card. See Appendix I: Maintenance Event Types on page 101 for a full description of battery status, auxiliary supply, and Low Power Mode events. 5.8 Cable Entry Control power is derived from one of two external All cables enter the Control Cubicle from the underside as sources: shown in Figure 3 “Equipment Panel” on page 17. Cable entries are provided for: • LV supply provided by the utility. This connects into the Control Cubicle and is called an LV Supply. In • The Recloser Control cable - plugs into connector this case, the Control Cubicle is equipped with a P1 at the bottom of the Battery Compartment. suitable transformer and its nameplate indicates the required supply voltage. • LV MCB supply lines - extend through channels behind the Equipment Panel. The two 20 mm (¾ in) • HV utility supply to a voltage transformer (VT) holes provided for cable entry can also be used for outside the Recloser tank. This external VT is external I/O entry if required. connected into the Recloser and is called an Integrated HV Supply. In this case, the rating plate • Communication Cable/Radio Antenna - includes a on the transformer indicates its voltage rating. Note 32 mm (1¼ in) hole for cable entry. the VT is designed only for the Siemens MJ-R Control Cubicle and cannot provide power for any other purpose. “15.11 Grounding” on page 62 gives details of auxiliary supply connection and grounding.
Siemens Power Transmission & Distribution, Inc. 19 5 Control Cubicle Construction
5.9 Current Injection Point A six-way connector called the “Current Injection Point” is located in the Mains Compartment. This is used with the Test and Training Set (TTS) to perform secondary injection while the switchgear is connected to the control. The current injection point can be used to test both the control and switchgear (together or separately) without disconnecting the control cable.
5.10 Computer Port A 25-pin female D-type RS232 connector is located on the Electronics Compartment cover above the MJ-R Operator Control Panel. This port is used for programming and interrogation of the control using the Centurion System Software (CSS) and a portable computer. This port is also used to upgrade the CAPM software, including installation and upgrades of telemetry protocols. Pinout for the DB9 to DB25 (or DB25 to DB25) serial cable used to connect the PC to the MJ-R RS232 computer port is described in Appendix L: Pinouts on page 115. Also see the CSS Help screen, “Connecting to a Recloser.”
20 Siemens Power Transmission & Distribution, Inc. 6 Control Electronics Operation 6 Control Electronics Operation The Control System block diagram is shown in Figure 5 6.3 Control Cable Entry Module “Control System Block Diagram” on page 23. The main (CCEM) features are explained below. The CCEM is located at the bottom of the Battery Compartment. A separable connector mounted on the 6.1 Control & Protection Module CCEM printed circuit board provides termination for the (CAPM) Recloser control cable. The CCEM also filters signals from the Recloser. The CCEM is a replaceable unit. The main module of the Control electronics is the microprocessor-based Control and Protection Module (CAPM). This manual describes the version 4 module 6.4 Description of Operation known as CAPM4. The CAPM carries out the following functions: The CAPM utilizes a Motorola 68332 microprocessor, 2 Megabytes of non-volatile “Flash” EEPROM and 1 • Protection relay functions. Megabyte of volatile read/write static memory. The non- volatile memory is used to hold programs, configuration • Auto-reclose relay functions. parameters and historical data. The volatile memory is • Sampling of the line current transformers (CTs), used as run-time workspace. There are no user- calculation of RMS phase current and ground spill adjustable hardware features on the CAPM, no links, no current. DIL switches, and no variable resistors. The microprocessor of the MJ-R Control can be re- • Sampling of the line capacitive voltage transformers programmed (both settings and firmware) using a (CVTs), calculation of RMS phase/ground voltages. portable computer. • Calculation of apparent, real, and reactive power The CAPM reads data from Recloser memory on power- from the above. up when the switchgear and control are connected. The memory data includes error check codes used by the • Monitoring of Recloser auxiliary switches. CAPM for data validation. The status of the data • Charging of the close and trip capacitors. validation is displayed on the MJ-R display panel. • Discharging of the close and trip capacitors into the When a local operator presses a button on the Control magnetic actuator to operate the Recloser, either Panel, the button push is sent as a character from the automatically or by local or remote operator Operator Panel Subsystem to the CAPM, which then command. carries out the required command. Current transformers and voltage screens in the Recloser • Charging of the battery from the auxiliary are monitored to provide the protection and measurement supply; changeover to battery on loss of functions. The Recloser operates when the CAPM auxiliary supply; and shutdown when discharges its trip or close capacitors into the Recloser approaching battery depletion. actuator. The CAPM continually monitors these • Driving the Operator Panel Subsystem (OPS). capacitors and only discharges them into the Recloser solenoids if the charge is sufficient for correct Recloser • Driving the external communications interface to operation. In addition, the CAPM closes the Recloser only allow monitoring and control from a remote if there is sufficient charge in the trip capacitor to trip the computer or operator over a communications link. Recloser. This ensures that the Recloser is always ready • Driving the Centurion System Software (CSS) over to trip if closed onto a fault. If a trip or close request occurs an RS232 link. The connector for this link is located when there is insufficient charge in the capacitors, the on the Electronics Compartment above the Operator request is ignored (this never happens in normal Control Panel. operation). The CAPM also ignores control requests and does not attempt to operate the Recloser if: The CAPM is a replaceable unit. • Both (isolate) toggle switches on the Operator Control Panel are in the isolate position. (Refer to 6.2 Operator Panel Subsystem (OPS) “7.4 TRIP/CLOSE Keys, ENABLE/DISABLE Isolate Switches” on page 26.) The OPS is comprised of the Electronics Compartment cover, an Operator Control Panel with LCD display, a • The Recloser is disconnected, the manual lockout membrane keyboard and its controlling microcomputer. handle is in the locked out position, or the Recloser The Operator Panel Subsystem is a replaceable unit. memory data cannot be read or is invalid.
Siemens Power Transmission & Distribution, Inc. 21 6 Control Electronics Operation
The Recloser, electronics, and power supplies are monitored for correct operation. This data is used to generate a signal that is available either for transmission by a telemetry protocol or as an output on the optional IOEX (Input/Output Expander) module. The “system healthy” status can also be monitored remotely both through telemetry protocol and through the IOEX module.
22 Siemens Power Transmission & Distribution, Inc. 6 Control Electronics Operation ” ” TERMINALS I “ “ X TERMINALS “ X ”
Figure 5 Control System Block Diagram
Siemens Power Transmission & Distribution, Inc. 23 6 Control Electronics Operation
24 Siemens Power Transmission & Distribution, Inc. 7 Operator Control Panel 7 Operator Control Panel Figure 6 shows the Operator Control Panel. The panel keyboard with switches and LEDs. The Control Panel is consists of a four-line, backlit liquid crystal display and a simple and intuitive.
LEFT scroll key
Display panel. Back lit, LCD, 4-line, 40 SELECT menu characters per line item key
CLOSE key. Red push button with red LED RIGHT scroll key contact indicator
CLOSE circuit isolate LOCAL/REMOTE switch. SPST toggle Quick Key switch with beeping alarm GROUND PROTECTION TRIP circuit isolate Quick Key switch. SPST toggle switch with beeping “disable” alarm
COLD LOAD Quick Key TRIP key. Green push PANEL ON/OFF Microprocessor RECLOSE ENTER key button with green LED toggle key running. ON/OFF contact position Blinking green Quick Key indicator LED
Figure 6 Operator Control Panel 7.2 Organization of Liquid Crystal Display 7.1 Turning on the Control Panel The four-line liquid crystal display is usually organized as follows: The PANEL ON/OFF key turns the panel on and off. When off, the display is blank and all keys are inoperative. ------Page Title ------The panel will turn itself off if no keys are pressed for ten minutes. Data Field 1 Data Field 2 Data Field 3 Data Field 4 When activated, the Control Panel shows a start-up message for 5 seconds and changes to the System Data Field 5 Data Field 6 Status 1 display (refer to Appendix E: System Status Pages on page 91). However, if both the Aux supply and The six data fields are used on each display page. Display the battery were previously disabled, it will be necessary pages with this format are shown in Appendix E: System to set the time and date using the ½ ¾, SELECT and Status Pages on page 91 and Appendix F: Protection MENU keys before other displays can be selected. Pages on page 93. Special display pages with different formats are shown in the relevant sections in this manual.
7.3 Microprocessor Running LED This LED will flash at 2-second intervals to indicate the control electronics are operating normally. A fault
Siemens Power Transmission & Distribution, Inc. 25 7 Operator Control Panel condition (e.g., loss of power) is indicated if the flashing used to select sub-groups of pages such as weekly stops or becomes intermittent. Under normal conditions, maximum demand and the ½ ¾ keys are used to select the MICROPROCESSOR RUNNING LED flashes at all pages within the sub-group as shown in Figure 7 “Display times, including when the panel is turned off. Page Organization” on page 28. Therefore, to select a particular display page: 7.4 TRIP/CLOSE Keys, •Press the MENU key to get the group on display ENABLE/DISABLE Isolate Switches •Press ¾ to get the page or sub-group required. The operator presses the TRIP and CLOSE keys to •Press SELECT to get to the sub-page required, if generate trip and close requests to the CAPM when the necessary. MJ-R Control Panel is ON. The key presses are ignored if the adjacent ENABLE/DISABLE switches are in the DISABLE (isolate) position. 7.7 Changing Settings When the switches are in the ISOLATE position, the close There are two ways that settings may be changed from and trip coils in the magnetic actuator are disconnected the Control Panel: from the control electronics. Thus, the • The Quick Keys allow rapid changing of operator ENABLE/DISABLE switches constitute physical isolation settings on the System Status 1 page (refer to points for the control circuitry. Appendix E: System Status Pages on page 91). Embedded in the TRIP/CLOSE keys are LEDs that Quick Keys are located on the lower right hand side indicate the position of the vacuum interrupter contacts of of the panel. the Recloser. Red indicates closed; green indicates open. •The SELECT, ½, ¾, and MENU keys which can be used to change all settings. 7.5 Display Groups 7.7.1 Use of Quick Keys The various displays of the MJ-R Control are divided into Quick Keys are a way to quickly change the settings four groups that are in turn, divided into pages. The four commonly used by an operator or linesman. The following display groups are as follows: Quick Keys are available: • SYSTEM STATUS - shows all status information for Table 3 Quick Keys the Recloser and Control electronics, e.g., battery low, operations counter, and SGF enabled/disabled. Quick Key Operator Setting Controlled See Appendix E: System Status Pages on page 91 for more details. Local Remote Local Mode / Remote Mode • EVENT LOG - shows the event records for the Ground Prot SGF ON/OFF, Ground Fault ON / Recloser. See Section 10 - Event Log on page 61 OFF and Appendix H: Standard Event Types on page 97 Auto On/Off Auto-Reclose ON/OFF for details. Cold Load Cold Load Pickup IDLE/ NO • MEASUREMENT - displays all HV line CHANGE / MAX measurements, e.g., line current, line voltages, maximum demand data. Refer to Section 11: Power System Measurements on page 45 for more details. Note: Some Quick Key selections may not be available to the operator if previously disabled. (Refer to Appendix E: System • PROTECTION - displays all the protection settings Status Pages on page 91 and Appendix F: Protection Pages on currently in use, e.g., trip current settings, time- page 93.) current curves, reclose times. More information is A Quick Key can be pressed at any time and has the given in Section 9: Protection on page 31 and effect of displaying the System Status 1 page, with the Appendix F: Protection Pages on page 93. selected field flashing. Subsequent button presses on the selected Quick Key will cycle the flashing field through the options available. Pressing the ENTER key puts the 7.6 Selecting Displays newly selected setting into service. The display then The MENU key selects the display group. The ½ ¾ keys returns to the previously selected display page. When a select pages within the group; this is shown in Figure 7 Quick Key is in use, the ½ ¾ keys and SELECT key are “Display Page Organization” on page 28. On the disabled. A corresponding message appears when the measurement display group the SELECT key can also be Help key is pressed.
26 Siemens Power Transmission & Distribution, Inc. 7 Operator Control Panel
7.7.2 Use of SELECT, ½ ¾ and MENU Keys Only a few settings can be changed by the Quick Keys; however, all settings can be changed by the following procedure: • Find the group and page on which the setting is shown (Press MENU for group, ½ ¾ for page). • Press and release the SELECT button until the required setting starts to flash. •Press ½ ¾ keys to change the setting to the new value required. •Press MENU or ENTER to activate the new setting.
7.8 Password Protection Some settings require passwords to be entered before they can be changed. See Appendix E: System Status Pages on page 91. If a password protected field is selected for change, the user is prompted for the password. At the prompt, a password (which can be up to five characters in length) is entered as follows: • ½ ¾ keys are pressed until the first character of the password is displayed. • SELECT key is pressed. • This sequence is repeated until the required number of characters has been entered. Once entered, the password does not need to be entered again while the Operator Panel is on. However, if the Operator Panel turns off, it will be necessary to re-enter the password to make further setting changes. The password is factory set to
Siemens Power Transmission & Distribution, Inc. 27 7 Operator Control Panel
Figure 7 Display Page Organization
28 Siemens Power Transmission & Distribution, Inc. 8 Work Tags and Control Mode 8 Work Tags and Control Mode The MJ-R Control is always in either the Local or Remote 8.1.2 Remote Mode Mode. Work Tag can be applied in either mode. The mode • In Remote Mode, a manual Close cannot be and tag specify the circumstances where Close conducted unless initiated by a remote operator. operations will be permitted to ensure operational safety. . • In Remote Mode, Work Tag can only be applied or removed by a remote operator. • In Remote Mode, local commands to initiate Close or to modify Work Tag are denied. The following message flashes on the display panel: “Not Allowed Hazardous voltages. - Change to Local Control and/or remove Work Tag.” Will cause death, serious personal injury or property damage. Always follow proper safety Hazardous voltages. procedures. De-energize the Recloser, establish visible Will cause death, serious disconnects on each side of the personal injury or property Recloser, and ground the Recloser damage. terminals before working on this Always follow proper safety equipment. Do not rely solely on the procedures. De-energize the manual handle or the position Recloser, establish visible indicator to ensure the line has been disconnects on each side of the de-energized. Recloser, and ground the Recloser terminals before working on this equipment. Do not rely solely on the 8.1 Local/Remote Mode manual handle or the position indicator to ensure the line has been The Local/Remote selection is accessed on the System de-energized. Status 1 page (refer to Appendix E: System Status Pages on page 91). There is also a Quick Key on the Operator Panel for direct access to this function. Setting this mode establishes which operator has the ability to issue manual 8.2 Work Tagging close commands or to apply or remove a Work Tag. See • Close operations are different with Work Tag. When the definition of Local or Remote Access in “8.3 Definition active, Work Tag disables Close operations including of Local or Remote Access” on page 30. The local/remote local, remote, and automatic operations. A switch does not affect automatic close, e.g., reclosing protection trip will always result in lockout on the first during a protection sequence. operation when Work Tag is active. Note: Local or Remote Mode can be set locally only through the • A password is required to enable or disable a Work Operator Control Panel. Auto-Reclose functions operate Ta g . normally and are not disabled by the Local/Remote switch. See the definition of Local or Remote Access in “8.3 Definition of • Work Tags are selected on the System Status 2 Local or Remote Access” on page 30. page. Refer to Appendix E: System Status Pages on page 91. When active, the following message 8.1.1 Local Mode flashes on the title line of the operator display panel: • In Local Mode, a manual Close cannot be conducted “Warning - Work Tag Applied.” unless initiated by a local operator. This means an • If a Close is attempted by a local operator and is operator can go to the Control Panel, set the mode blocked by Work Tag, the following message flashes to local, and disable all remote close operations. on the display panel: “Not Allowed - Change to Local • In Local Mode, Work Tag can be applied or removed Control and/or remove Work Tag.” only by a local operator.
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8.2.1 Removing a Work Tag • In Local Mode, only a local operator can apply or remove a Work Tag. • In Remote Mode, only a remote operator can apply or remove a Work Tag. • It is possible, however, for a local operator to remove a Work Tag applied by a remote user. To accomplish this, it will be necessary to obtain the remote user’s password, switch the unit to Local Mode, then proceed with the steps to remove the Work Tag.
8.3 Definition of Local or Remote Access An operator can gain local access to the MJ-R Control in three ways: • The Operator Control Panel. • An IOEX card designated as “Local.” This might apply, for example, to a substation Recloser using an IOEX card to connect to a panel inside a control house. • A PC connected to the computer port on the Operator Control Panel. Refer to “13.1 Centurion System Software” on page 49 for more details. An operator can gain remote access to the MJ-R Control in two ways: • An IOEX card designated as “Remote.” This might apply, for example to an IOEX card used to interface to a SCADA system remote terminal unit. Refer to “13.2 Input Output Expander (IOEX) Card” on page 49. • A remote control protocol. These are almost always designated remote access. Full information is given in the relevant protocol manual. An IOEX card is designated Local or Remote from the Operator Control Panel. Refer to “13.2 Input Output Expander (IOEX) Card” on page 49 and System Status 6 in Appendix E: System Status Pages on page 91.
30 Siemens Power Transmission & Distribution, Inc. 9 Protection 9 Protection
9.1 Overview 9.3 Operator Settings This section describes the many different protection Operator settings are different from protection settings. features of the MJ-R Control. The operation is Operator settings are used routinely by an operator to set summarized as follows: the control into the required mode; for example, to disable Auto-Reclose and Sensitive Ground Fault prior to live line • When a line fault occurs, the Recloser is tripped. A work. variety of protection elements can be programmed to cause the trip, and at the same time, prevent The operator settings located on the System Status 1 nuisance tripping. page, are as follows: • A protection trip is typically followed by a delay and • Local/Remote Mode then a reclose. • Ground Fault (GF), Sensitive Ground Fault (SGF) • This trip/close sequence can be repeated a number ON/OFF selections of times. In addition, many protection parameters • Auto-Reclose ON/OFF can be programmed with different values for each trip in the sequence. • Cold Load Pickup selections • If the fault cannot be cleared, the control goes to • Protection Group or Protection OFF selections lockout and waits for an operator to initiate the next close. You can also program the control to lockout Once set, these operator settings are not affected if the without completing the entire reclose sequence. Active Protection Group is changed. • The control stores two groups of protection settings For example: If Auto-Reclose is in force before the Active that can be selected by the operator; these are Group is changed from A to B, Auto-Reclose will also be called the A and B protection groups. in force after the change. Note: Ground Fault, Sensitive Ground Fault, and Protection OFF • In addition, operator settings are provided that settings will be unavailable to the operator if they have been modify basic reclose operation without disabled on the System Status 10 page. (Refer to Appendix E: reprogramming protection settings. System Status Pages on page 91.)
9.2 Multiple Groups of Protection 9.4 Protection Control Settings The selection of System Status 1: Protection OFF inhibits The control supports two independent groups of all protection pickups, deactivates all overcurrent protection settings: protection, and deactivates Loss of Phase Protection. Only manual local/remote trips and closes are performed. • Protection Group A Note that Live Load Blocking still operates even if • Protection Group B Protection OFF is selected. The operator selects either Group A or Group B to be It is possible to configure the control so the Protection Active. (Refer to Appendix E: System Status Pages on OFF setting cannot be reached. This is set using the page 91.) System Status 10: Prot OFF Not Allowed setting. In this case, the operator cannot select the Protection OFF When a new Protection Group is activated or a protection state, only the A or B Protection Groups. Selecting Prot trip occurs, an event is written to the Event Log indicating OFF Not Allowed turns on the protection if it is not already the Protection Group in operation. The event logged is on. either ‘Prot Group A Active’ or ‘Prot Group B Active.’ All protection parameters are programmed and stored independently for each group. For example, if the 9.5 Sensitive Ground Fault Control sequence reset time is required to be 20 seconds in both Sensitive Ground Fault (SGF) protection can be made A and B groups, then it must be explicitly set to 20 either available or not available with the System Status seconds in both groups. 10: SGF Available/Not Available setting. When not Protection settings are usually set once by the protection available, SGF is turned off and does not appear on the engineer and are not altered during normal operation of Display Panel. the equipment.
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9.6 Ground Fault Control message is displayed (and must be acknowledged by the operator) before the changes are put into service. It is also possible to disable control over Ground Fault protection with the System Status 10: G/F OFF Changes can also be made by remote operators using Allowed/Not Allowed setting. When Ground Fault OFF is CSS or SCADA systems. If a CSS operator changes set to Not Allowed, operator control of Ground Fault settings, the local operator will see the page title flash to protection is disabled (and Ground Fault protection is indicate changes are pending. When any user puts his or permanently ON). This can be used in conjunction with her changes into service, all pending changes, including the SGF Available setting to restrict operator control to those made by other users, go into service. SGF only. 9.8 Overcurrent Protection 9.7 Changing Protection Settings The Control and Protection Module (CAPM) continually All protection parameters and operator settings are held samples the current flowing in the secondary current in non-volatile memory on the CAPM. This ensures they transformers. The samples are digitally processed by the are retained through power interruptions. However, if a CAPM to monitor line current for the purposes of different CAPM is installed in a control cubicle, or if the overcurrent protection. The phase currents are summed control cubicle is replaced, then the protection digitally to give the ground current for the purpose of parameters need to be re-programmed into the CAPM. ground fault protection. Digital filtering algorithms are The CAPM can be re-programmed either through the applied to line currents to minimize transient overreach. Operator Panel or through the Centurion System The three current transformer currents are also grouped Software (CSS). as analog signals to give the ground (or spill) current. The technician-level password is required before any These are sampled and digitally processed for the changes can be made. Also, two groups of protection purposes of sensitive ground fault protection (SGF). A low settings can be programmed. When programming pass filter on the spill current reduces sensitivity to protection settings, the technician first selects a group of harmonics above 60 Hz, reducing SGF sensitivity to protection parameters to display, e.g., Protection Setting transformer in-rush and other harmonic interference. 1 Group (A or B) Displayed. This group can then be If any of these signals (phase, ground, or SGF) exceed changed. Please note, however, displaying a group the relevant Trip Current Setting, the appropriate relay does not make that protection group active; that is Picks Up. In the case of Definite Time, the timing done by making the proper selection in the System Status sequence starts immediately. In the case of Inverse Time 1: Prot A/B Active field. and Instantaneous Protection, the timing sequence A Protection Group can be active while another initiates when the signal exceeds the Threshold Current. Protection Group is being displayed. To avoid confusion, If the current falls below 90% of the trip current setting for the title line of the Protection Setting page always longer than the Fault Reset Time, then that particular identifies the Protection Group currently being displayed protection element’s timing sequence is canceled and re- by showing an “A” or “B” suffix, such as Protection Setting initialized. When all the protection elements have reset, 3-B. the peak currents on the faulted elements are logged. The operator can change settings for either the active Phase and Ground Trip Current settings are selected group or the inactive group. When an active group is separately, but are only set once for all trips in a being changed, the page title flashes to indicate that the sequence. Other protection parameters (e.g., time- modified settings are different from the ones currently in current curve, reclose times, and multipliers) are set service. When completed, the changes to the active separately for each trip in a reclose sequence. This group do not go into service immediately. Instead, the allows, for example, Instantaneous Protection on the first changes are stored in a database in the control and are trip in a sequence and Inverse Time Protection on activated when: subsequent trips in the sequence. • The operator moves off the pages in a Protection To do this, seven different protection setting pages are Group. provided. Two of these pages (one for phase and one for • The operator turns the Control Panel off. ground) must be configured for each active trip in a sequence. These pages are shown in Appendix F: • The Control Panel turns itself off after the time-out Protection Pages on page 93. period. The operation of the different protection types is detailed • The control is powered off and on again. next. This allows the operator to edit the entire Protection Group and activate all the new settings simultaneously. A
32 Siemens Power Transmission & Distribution, Inc. 9 Protection
9.9 Inverse Time Protection • Additional Time - Set independently for each trip, sets an Additional Time To Trip which is added to the A variety of Inverse Time-Current Curves (TCCs) are Inverse Curve Tripping Time. Refer to Figure 9. provided and are available for your protection requirements. In general, an Inverse TCC responds faster (initiates trip faster) as a given fault magnitude increases. These TCCs can be selected for both phase and ground protection elements. Inverse Time Curves are implemented in the firmware in the following way. The line current is monitored after pickup. When it rises above the Threshold Current, the Time to Trip is calculated and the timing starts. This calculation is repeated every few milliseconds in response to changing line currents. When the remaining Time to Trip reaches zero, the trip request is issued. If the current falls below the Threshold Current, the timing stops but the protection does not reset. This means the relay will never trip at currents below the Threshold Current when an Inverse Time Protection element is utilized. Figure 9 Additional time, effects on the Inverse Curve The parameters that control Inverse Time Protection are: • An Instantaneous Trip element can be applied which will trip the Recloser if the current rises above a user • Inverse Curve Type - Set independently for each set multiple of the phase or ground trip current trip. Refer to “9.9.1 Protection Curves” on page 34. setting. If the Instantaneous Multiplier is set below the Threshold Current Multiplier, an Instantaneous • Phase Trip Current Setting - Refer to “9.8 Trip will occur only after the line current exceeds the Overcurrent Protection” on page 32. Threshold Current. Refer to Figure 10. • Ground Trip Current Setting - Refer to Section “9.8 Overcurrent Protection” on page 32. • Time Multiplier - Set independently for each trip. Multiplies the Time to Trip. Refer to Figure 8.
Figure 10 Instantaneous, effects on the Inverse Curve • Minimum Time - Set independently for each trip, sets the Minimum Time to Trip. Refer to Figure 11.
Figure 8 Time Multiplier, effects on the Inverse Curve
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.
Figure 11 Minimum Time, effects on the Inverse Curve Figure 13 Threshold Element, effects on the Inverse Curve • Maximum Time - Ensures the TCC Trip Time does 9.9.1 Protection Curves not exceed the preset limit. Refer to Figure 12. There are 48 inverse protection curves stored in the control's non-volatile memory. The library of available curves is defined in the following Appendices: • 3 Standard IEC255 curves are defined in Appendix A: IEC255 Inverse Time Protection Tables on page 75. • 3 Standard IEEE Std C37.112 curves are defined in Appendix B: IEEE Inverse Time Protection Tables on page 77. • 42 typical Recloser curves are defined in Appendix C: TCC Cross Reference Table on page 79. Any of the 48 curves can be selected for any (phase or ground) trip in the sequence.
Figure 12 Maximum Time, effects on the Inverse Curve Note: When Instantaneous-only Protection parameters are selected, Minimum Time To Trip and the Threshold Multipliers • The Phase Threshold Multiplier is used to prevent apply; Additional and Maximum times to trip do not. tripping if the line current is below the Threshold Current. The Threshold Current is the Trip Current 9.9.2 Interactions between curve parameters setting multiplied by the Threshold Multiplier. Refer This section describes some of the interactions that can to Figure 13. occur between the user-selectable Inverse Curve • The Ground Threshold Multiplier is used to prevent parameters. To understand the interactions between the tripping if the line current is below the Threshold curve settings, it is important to know how the curves are Current. The Threshold Current is the Trip Current constructed. The following is the order in which the curve Setting multiplied by the Threshold Multiplier. Refer settings are applied: to Figure 14. • Curve selected • Time Multiplier • Additional Time • Instantaneous Element • Maximum Time • Threshold Current •Minimum Time
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Figure 14 is an example of a protection curve modified by The example in Figure 16 shows the effects on a the Instantaneous Element, Maximum and Minimum composite curve as the Threshold Current Multiplier is Times. increased. Figure 16, part A shows a composite curve which has an Inverse Time Curve modified by both Maximum Time and Instantaneous Protection. Also shown in part A is an example of 3 different levels of Threshold Current Multiplier, settings: 1, 2 and 3. Figure 16, part B, C and D are the curves resulting from the Threshold Current Multiplier settings 1, 2, and 3. Threshold Current has a significant effect on the protection characteristics and at any given time is determined by the: • PROTECTION SETTING 2 (A or B): Phase/Ground Threshold • Cold Load Pickup - Refer to “9.18 Cold Load Pickup (CLP)” on page 39. • Inrush Restraint - Refer to “9.17 Inrush Restraint” on page 39.
Figure 14 Protection Curve modified by Minimum, Maximum Times, and Instantaneous Element Figure 15 is an example of using Maximum Time, Instantaneous, and Threshold Current Multipliers. The Maximum Time is set to 2s, the Instantaneous Multiplier is set to x10 and the Threshold Current Multiplier is set to x2. In this example, pickup will occur at the Trip Current setting, the Timing Sequence will begin at 2 times the Trip Current setting and the Instantaneous Trip will occur at 10 times the Trip Current setting.
Figure 15 Interaction between Instantaneous, Threshold Current, and Maximum Time
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Figure 17 Coordination between fuse and IEC 255 Inverse Curve using the Threshold Current Multiplier
9.10 Definite Time Protection This TCC is available for both phase and ground protection as an alternative to Inverse-Time TCCs. With Definite Time, the Recloser trips at a fixed time regardless of current magnitude. The Threshold Multipliers (Phase, Ground, Inrush, and Cold Load), as well as the Minimum, Additional, and Maximum Times do not apply where Definite Time is active.
9.11 Sensitive Ground Fault (SGF) Sensitive Ground Fault (SGF) can be set to be available or not available, and is located in the System Status 10: SGF Available field. When disabled, SGF does not appear and cannot be activated from the Operator Display Panel. It cannot be enabled without the appropriate password. Password protection ensures SGF is not accidentally activated at inappropriate locations. When SGF is available, the function can be selected without a password on the System Status 1 page. Selection is accomplished by cycling between the Figure 16 Composite curve changes due to different settings following three settings: of Threshold Current Multiplier • G/F OFF, SGF OFF - Ground Fault off and Sensitive An example of where the Threshold Current may be used Ground Fault off is shown in Figure 17. Coordination is lost for currents to the left of the intersection of the two curves (fuse and IEC • G/F ON, SGF OFF - Ground Fault on and Sensitive 255 inv). Selecting a Threshold Current Multiplier above Ground Fault off the intersection point (for example, 3x pickup) changes the composite TCC and prevents trips below the • G/F ON, SGF ON - Ground Fault on and Sensitive Threshold Current. This allows coordination with the fuse Ground Fault on to be maintained. G/F OFF will not be available if G/F OFF is set to Not Allowed on the System Status 10 page. Refer to “9.3 Operator Settings” on page 31.
Note: SGF operates as an additional Definite Time element. The Phase/Ground Threshold Current Multipliers, and Minimum, Additional, Maximum Time elements do not apply.
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SGF causes the Recloser to trip when the ground current remote operator command; a manual operator close rises above the SGF Trip setting for longer than the SGF command clears the lockout condition. Definite Time setting. The SGF Definite Time setting can When Auto-Reclose is turned off, reclose operations do be set differently for each trip in a reclose sequence. not occur. Instead, the control goes directly to lockout after a single protection trip. (Refer to “9.16.2 Single Shot 9.12 Loss Of Phase Protection Mode” on page 38.) To control the number of trips in a reclose sequence, two Loss of Phase (LOP) Protection will immediately trip and parameters must be set, the Total Protection Trips to lockout the Recloser if phase/ground voltage on one or Lockout, and the number of SGF Trips to Lockout. All two phases falls below a user-defined Loss of Phase protection trips in a sequence (including SGF) increment Voltage Threshold for longer than a user-defined Loss of a protection trip counter that causes the Recloser to Phase Time. LOP Protection can be turned on and off lockout once the “total protection trips to lockout” value is from PROTECTION SETTING 9 (A or B) Loss Phase Prot reached. In addition, SGF trips, anywhere in a sequence, OFF/ON in Appendix F: Protection Pages on page 93. increment a different counter that causes the Recloser to In addition, LOP Protection will cause a Recloser on a de- lockout once the “number of SGF trips to lockout” value is energized feeder to trip and lockout after the LOP time if reached. only one or two phases are re-energized. For example, protection can be set for four “total LOP Protection is configured on the PROTECTION protection trips to lockout” and two “SGF trips to lockout.” SETTING 4 (A or B) page in Appendix F: Protection This would mean that if any two trips in a sequence were Pages on page 93. SGF trips, the Recloser would lockout. If the “number of SGF trips to lockout” were set to 1, an SGF trip anywhere in the sequence would cause a lockout.
9.13 Live Load Blocking Note: The Protection Trip Counter determines which set of When PROTECTION SETTING 3 (A or B): Live Load protection settings is in force, not the SGF Trips Counter. If, for Block ON is selected, all close requests will be example, the third trip in the sequence is the second SGF trip, disregarded if any load side terminal is live. the Recloser will have operated on the settings of “ground protection trip number 3.” For Live Load Blocking to operate properly, the The bottom left field on the System Status 1 page shows switchgear must be installed with the load connected to what is happening during a reclose sequence. (Refer to the (I, II, III) side bushings of the Recloser. The Power Appendix E: System Status Pages on page 91.) The Flow Direction must be set to Source X, Load I. This display is normally blank when the Recloser is closed but requirement is due to the CVTs being fitted only to the (I, when a reclose sequence is in progress, it shows II, III) side. “Reclose 1” after the first reclose, “Reclose 2” after the Live Load Blocking is selected from the PROTECTION second reclose, etc. In other words, this display shows SETTING 6 (A or B): Live Load OFF/ON field noted in the status of the Protection Trip Counter. Appendix F: Protection Pages on page 93. Live Load When the Recloser is open and the protection is in Blocking uses the Live Bushing Threshold set on System lockout, a lockout status displays for the Protection Trip Status 5: “LIVE” if > 2000V. Counter. When an operator closes the Recloser, the Note: If the Recloser has not been installed in the above display goes blank to show that lockout is cleared. This orientation, the Live Load Blocking will not perform as expected display is very useful when performing current injection and should be disabled, i.e., PROTECTION SETTING 3: Live testing. Load Block OFF noted in Appendix F: Protection Pages on page 93. 9.15 Sequence Reset 9.14 Auto-Reclose A Sequence Reset Timer is used to reset the Reclose Sequence Counter to zero. When reset, the next fault When Auto-Reclose is turned on, the Control starts the sequence again at Trip 1. The sequence reset automatically recloses following a protection trip. The timer usually starts timing after an automatic reclose. If user-set delay between trip and reclose is called the the fault is still present, the protection picks up again and reclose time, which can have a different setting for each holds the Sequence Reset Timer at zero. The timer trip in a sequence. If the fault persists, the Recloser trips restarts when the fault has been cleared. The Sequence again under protection. This occurs repeatedly, until Reset Timer “expires” when it reaches the user-set either the fault is cleared or the protection relay reaches Sequence Reset Time. A ‘Sequence Reset’ event is then lockout that is the end of the defined reclose sequence. In logged. lockout, the Recloser can be closed only by local or
Siemens Power Transmission & Distribution, Inc. 37 9 Protection
The Sequence Reset Time is set on PROTECTION Single Shot Mode is activated when: SETTING 4 (A or B): Seq Reset Time 30s as noted in Appendix F: Protection Pages on page 93. • Auto-Reclose is turned off. • The switchgear is closed by operator command (regardless of the Auto-Reclose). This starts the 9.16 Lockout Single Shot Timer, which counts for a user-selected Lockout is set by any manual trip including the TRIP time. PROTECTION SETTING 4 (A or B): SS Reset button on the Operator Control Panel, the mechanical trip Time 1s in Appendix F: Protection Pages on page ring on the bottom of the Recloser, or by remote operator 93. trip. Lockout also occurs after the following events: Single Shot Mode is de-activated when: • After a trip, when the Control is in Single Shot Mode. • Auto-Reclose is turned back on. Refer to “9.15 Sequence Reset” on page 37. • The Single Shot Timer above expires, i.e., protection • After a trip, when the Work Tag is applied. pickup does not occur (see below). • At the end of a sequence, when the Protection Trip When Single Shot Mode is active, it is displayed in the Counter reaches the preset number of trips in Auto- System Status 1: Single Shot Active field. The user Reclose Mode. determines the protection parameters that are active for the Single Shot Protection Trip by selecting a number • When the SGF Trip Counter reaches the preset (from 1 to 4). This number corresponds to the protection number of SGF trips in Auto-Reclose Mode. settings (1 to 4) defined in the trip sequence. In effect, any • When a High Current Lockout trip has occurred. trip parameters in the sequence can be selected to be Refer to “9.14 Auto-Reclose” on page 37. active for single shot protection. • Loss of Phase Protection trip. When Single Shot Mode de-activates, protection reverts to the fully programmed sequence. • After a trip when control is in Low Power Mode. Refer to “16.8.1 Low Power Mode” on page 73. Notes: • After a mechanism in open position, failed to close. • Close commands and Auto-Reclose ON/OFF commands can come from a number of sources 9.16.1 High Current Lockout (i.e., from the Control Panel, CSS, Telemetry or IOEX). Single shot is activated or de-activated If a trip occurs and the measured peak fault current regardless of the source of these commands. exceeds the “High Current Lockout” setting, the Control goes directly to lockout and does not reclose. A High • The Single Shot Timer does not alter normal trip Current Lockout only occurs when the setting is equal to, times. When closing into a fault, Single Shot or higher than, the Phase Pickup Current. operates normally, even when the trip time is longer than the Single Shot Time Setting. If the fault clears High Current Lockout is enabled on PROTECTION before a trip occurs (e.g., by a downstream fuse), SETTING 9 (A or B): High Current LO OFF/ON in the timer is used to ensure the line remains fault free Appendix F: Protection Pages on page 93 and only for the duration of the Single Shot Time before applies during the preset, “Activation Trip” or one of the Single Shot Mode is de-activated. subsequent trips in a sequence. • This is done by triggering the Single Shot Timer High Current Lockout can occur on the first trip operation when a close operation occurs. If a protection pickup when Single Shot Mode is active or when an operator occurs during this period, the timer is reset to zero closes onto a fault. Of course, in both these situations the and held there while pickup is active. A protection Control would have gone to lockout anyway without High reset restarts the timer provided it has not already Current Lockout being triggered. The difference is that an timed out. event is recorded in the event log as extra information for fault analysis when High Current Lockout is triggered. • Single Shot Protection trips are logged independently of the Protection and SGF trips. 9.16.2 Single Shot Mode When a trip occurs in Single Shot Mode, a ‘single shot’ event is generated. In Single Shot Mode, the Control goes directly to lockout after one trip operation and will not auto-reclose, i.e., • Both the Single Shot Trip Number and the Single when deliberately closing onto a fault when fault chasing. Shot Reset Time are set on the PROTECTION When configuring for Single Shot Mode, the protection SETTING 4 (A or B) in Appendix F: Protection settings are selected from the four existing protection Pages on page 93. settings.
38 Siemens Power Transmission & Distribution, Inc. 9 Protection
9.17 Inrush Restraint When closing onto a typical load there is always a short- lived inrush current caused by, for example, transformer magnetization currents, low resistance lamp filaments, and motor starts. The purpose of Inrush Restraint is to prevent the Recloser from tripping when these inrush currents occur. Inrush Restraint works by raising the Phase and Ground Threshold Currents for a short period of time to allow the inrush to flow. The Inrush Time and Multiplier settings are specified on the Protection Settings 5 page. Typical values would be 200 ms with a multiplier of 5. Inrush Restraint is armed for operation whenever the load current goes to zero (zero current is defined as all three phase currents less than 2.5 Amp); for example, when the load is dropped either by the ACR itself, or by an upstream or downstream circuit breaker. When the load current becomes non-zero (at a later time, either through the closing of the ACR or some upstream or downstream device), the Inrush Restraint is activated and the Inrush Multiplier is used in place of the Threshold Current Multiplier for the selected time. In order for Inrush Restraint to be effective, the Inrush Multiplier must be larger than the Threshold Current Multiplier. Figure 18 is an example of the Inrush Settings applied to an Inverse Curve. In this example, the Threshold Current Figure 18 Effect of Inrush Current Settings on a Protection Multiplier is set to x1.1, the Instantaneous Multiplier is set Curve to x10, the Inrush Multiplier is set to x5, and the Inrush Time is set to 0.5 second. After a close, for the first 0.5 of a second, the Threshold Current increases to 5 times Trip 9.18 Cold Load Pickup (CLP) Current Setting. It then drops back to the original setting of 1.1x Trip Current Setting once the Inrush Time is When a typical feeder experiences an outage for a period complete. Under these circumstances the instantaneous of time (hours), usually the load also loses its diversity. In trip does not occur. If, on the other hand, the effect, the demand at the time of restoration is higher than Instantaneous Multiplier is set to 4x, an instantaneous trip usual because thermostats for many devices, such as would occur when line current exceeded 5x the Trip refrigerators, freezers, air-conditioner/heater systems, Current Setting. turn on simultaneously. The longer the period without supply, the greater the loss of diversity and the higher the Note 1: When Cold Load Protection is turned on, the Multiplier load current when supply is restored. used for inrush is always the larger of the Inrush Multiplier and the Cold Load Multiplier. The purpose of the Cold Load Pickup (CLP) feature, therefore, is to allow for this loss of diversity automatically, Note 2: Inrush Restraint affects Phase and Ground Protection, and to maintain the load without tripping. In effect, the but does not apply to Definite Time or SGF. feature raises (or lowers) the effective trip threshold levels Note 3: If normal currents are expected to drop below 2.5A, at a rate proportional to the time that the load current was Inrush Restraint cannot be used. In this case, turn the lost (or restored). The effective trip threshold level is Inrush Restraint off. calculated and adjusted at 1-minute intervals throughout Inrush Restraint parameters are set on PROTECTION this process. SETTING 12 (A or B) in Appendix F: Protection Pages on The user specifies a multiplier and a time. The Control page 93. detects when load current is zero and starts timing (see Inrush Restraint) a timer called the Operational Cold Load Time. Using this timer, an Operational Cold Load Multiplier is calculated using the following formula.
Siemens Power Transmission & Distribution, Inc. 39 9 Protection
Operational Cold Load Mult= Multiplier is set to x1.75, the Cold Load Multiplier is set to x2, and the Cold Load time is set to two hours. Time since current off 1 + ------¥ ()User set cold load multiplier – 1 User set cold load time • Part A of Figure 19 describes how the Cold Load The Operational Cold Load Multiplier is used to modify Multiplier changes over time when line current is the Phase and Ground Threshold Current Multipliers. interrupted and restored after a minimum of two hours. Therefore, the Phase and Ground Protection Thresholds increase at a rate specified by the customer when the • Part B of Figure 19 shows the original Protection load is switched off, but only up to the user-set Cold Load Curve. Multiplier. The control calculates the new threshold • Part C of Figure 19 shows the Protection Curve in values each minute. use when the line current is first restored. The Cold For example, if the user-set Cold Load Time is 2 hours, Load Multiplier is x2. (The trip level is two times the the user-set Cold Load Multiplier is x2, and the current trip setting). Note that in this case an Instantaneous has been off for 1 hour, then the Operational Cold Load Trip does not occur until the line current exceeds 2 Time is 1 hour. Consequently, the Phase and Ground times the trip setting. Thresholds are increased to equal the Operational Cold Load Multiplier of 1.5. • Part D of Figure 19 shows the Protection Curve in use one hour after restoration. The Cold Load Once load current is restored, the Operational Cold Load Multiplier is x1.5. An Instantaneous Trip now occurs Timer starts to count down. This means that the at the set value of 1.75 times the trip setting. Operational Cold Load Multiplier reduces back to 1 and hence the Phase and Ground Threshold Currents also • After 1.8 hours, the Cold Load Multiplier reverts to reduce back to their values. Note that the rate of increase the original settings as shown in Part B of Figure 19. and decrease of threshold currents is the same. 9.18.2 Cold Load Pickup Status Display In this way, the loss of load diversity is automatically compensated for, and is independent of the switch point The operational status of the Cold Load Pickup is shown (e.g., the substation, Recloser, or load-side device). in the System Status 1: Cold Load field. This can show the following states: Cold load can be controlled either by using the Cold Load Quick Key. (Refer to “7.7.1 Use of Quick Keys” on page • Cold Load OFF: Cold Load Pickup has been 26). The User Set Cold Load Time and the User Set Cold configured OFF in the currently active Protection Load Multiplier are set on the PROTECTION SETTING Group, no operator control of Cold Load Pickup is 12 (A or B) in Appendix F: Protection Pages on page 93. possible. The Operational Cold Load Multiplier will not go above the • Cold Load IDLE: Cold Load Pickup is configured user-set Cold Load Multiplier or below the user-set ON but Cold Load Pickup is not affecting the thresholds on PROTECTION SETTING 2 (A or B) in thresholds. Probably because the load current is on Appendix F: Protection Pages on page 93. and Operational Cold Load Time is zero. This is the normal condition. On power up, the load is assumed to be diverse, i.e., the Operational Cold Load Time is zeroed and “Cold Load CLP 60 min X1.5mult (for example). The display IDLE” displays. shows the Operational Cold Load Time and Multiplier. This affects the Protection Thresholds. In • Cold Load affects Phase and Ground Protection this example the Operational Cold Load Time is 60 Thresholds including Instantaneous but not SGF. mins and the Multiplier is 1.5. • High Current Lockout and Definite Time settings are • Cold Load Pickup affects Phase, Ground, and not affected. Instantaneous Protection settings. • Cold Load Pickup cannot be used if normal currents are expected to drop below 2.5A and should be 9.18.3 Operator Control of Cold Load Pickup turned off. If Cold Load Pickup is ON in the currently active Protection Group, it can be controlled by using either the • The Cold Load Pickup feature is the subject of a Cold Load Quick Key (Refer to Section “7.7.1 Use of patent application. Quick Keys” on page 26) or the Select ½ ¾ keys. 9.18.1 Cold Load Pickup Example Figure 19 is an example of the Cold Load settings applied to an Inverse Curve. In this example, the Threshold Current Multiplier is set to x1.1, the Instantaneous
40 Siemens Power Transmission & Distribution, Inc. 9 Protection
Figure 19 Cold Load Multiplier (CLM) settings applied to Protection Curves
Siemens Power Transmission & Distribution, Inc. 41 9 Protection
Quick Key options are: 9.20 Automatic Protection Group • Cold Load IDLE: Zeroes the Operational Cold Load Selection Time. Note that if the load current is off, the Sometimes a Recloser is used at a location in a supply Operational Cold Load Time starts to increase. network where the power flow can be in either direction depending on the configuration of the rest of the network. • Cold Load NO CHANGE: The Operational Cold One example of this is a network tie point. In this case, the Load Time remains unchanged. Note that the operator may have to select a different group of protection Operational Cold Load Time increases if the load settings to compensate for a change in power flow when current is off and decreases if the load current is on. changing the network configuration. • Cold Load MAX: Sets the Operational Cold Load Automatic Protection Group Selection allows the Time to the maximum. If the load current is on, the Protection Groups to be selected without the operator Operational Cold Load Time starts to decrease. coming to the Recloser. It automatically changes between You can exercise more control with Select ½ ¾ keys: Protection Groups A or B depending on the direction of power flow. It is made active by selecting System Status • Cold Load IDLE: Zeroes the Operational Cold Load 1: Protection Auto. The display then shows the currently Time. Note that if the load current is off, the active set by displaying System Status 1: Auto ‘A’ Active Operational Cold Load Time starts to increase. or System Status 1: Auto ‘B’ Active. • Set the Operational Cold Load Time and Multiplier to When active, the Protection Group is automatically a desired value. Note that the Operational Cold Load selected according to the following rules: Time increases or decreases depending on the whether the load current is OFF or ON. • Protection Group A is always used when the power flow is in the positive direction (source to load). 9.19 Sequence Coordination • If the power flow is greater than 50 kW in the (Sequence Control) reverse direction (load to source) for longer than the period set on System Status 10: Auto Change Time Sequence Coordination causes the Recloser to step to 60s, without any protection element pickups during the next count in the reclose sequence due to a reset of this time, then Protection Group B will be selected. all protection elements, whether the Recloser tripped or not. The sequence will only advance if Auto-Reclose is on • To revert back to Protection Group A, the power flow and the Single Shot Timer has timed out. must be greater than 50 kW for longer than the period set on System Status 10: Auto Change Time Consider this situation. Two Reclosers are in series on a 60s, without any protection element pickups feeder. Both Reclosers are programmed to protect fused occurring during this time. taps with fast tripping on the first trip and slow tripping on the second trip. Assume a permanent fault occurs Note 1: On power down, the Controller saves the current downstream from the second Recloser that is also status of Protection Auto and uses that to determine detected by the first Recloser. The Recloser nearest to the active Protection Group on power up. the fault would trip, step to its next (slow trip) setting, and Note 2: Automatic Protection Group Selection is only available reclose. The Recloser upstream (the Recloser nearest in software versions 027-00.00 or later. the substation) operating on fast trip settings would now This feature is not the same as Directional Protection, trip and reclose. The operation of the upstream Recloser which is used in interconnected systems fed from both is not preferred and should be prevented, if possible. sides and determines protection settings from direction of This problem is overcome by activating Sequence fault current. Automatic Protection Group Selection, Coordination on the upstream Recloser. With Sequence however, is used in radial systems fed from a single Coordination, the upstream Recloser detects the fault source and determines protection settings from the and steps to the next stage when the downstream direction of load current rather than fault current. Recloser clears the fault. In this way an upstream Recloser coordinates its sequence with a downstream 9.21 Fail to Operate Under Protection Recloser. If the fault does not re-occur, the trip count • If the Recloser fails a protection-initiated trip, a resets to zero after the Sequence Reset Time elapses. ‘mechanism fail’ is logged in the event record. No SGF settings can be coordinated in the same manner further attempts to trip occur until all the protection using Sequence Coordination. elements reset. The Recloser attempts to trip when the next pickup/protection trip sequence occurs. • If the Recloser fails to Auto-Reclose, the relay goes to lockout.
42 Siemens Power Transmission & Distribution, Inc. 10 Event Log 10 Event Log When the status of the control electronics or switchgear element generates an event. These events are not change, events are generated and recorded in the Event generated, however, until all elements have reset. Log. Examples of such events are ‘Load Supply on’ or This means they are time stamped after the ‘Lockout.’ Events are viewed on the Event Log pages and protection trip in the event log. can also be up-loaded and viewed with the Centurion System Software. • Automatic Reclose of the Recloser. The following is an example of the Event Log display. • Expiration of the Sequence Reset Timer. This indicates the Protection Relay has reset to the beginning of the reclose sequence. ------EVENT LOG ------12/01/98 12:09:02.06 Close Coil Connect The following is an example of a typical sequence of events for a phase-to-phase fault with Instantaneous 12/01/98 12:90:03.95 Operator Close Protection on the first trip, Inverse Time Protection on the 12/01/98 12:90:33.95 Sequence Reset second trip, and two trips to lockout.
Events are dated and time stamped to a 10 ms resolution ------EVENT LOG ------and are displayed in the order they occurred. 23/06/98 07:02:53.90 Pickup Start of fault The ½ key scrolls the display down to show older events; 23/06/98 07:02:53.92 Prot Group A Active Protection the ¾ key scrolls the display up to show more recent group A events. Pressing the key removes the title of the ½ 23/06/98 07:02:53.92 Phase Prot Trip Phase element display to make more room for events. The title is restored caused trip only when the Event Log is selected again from the top- level menu. Appendix H: Standard Event Types on page 23/06/98 07:02:53.92 Prot Trip 1 1st trip 20ms after pickup 97 lists all the events in alphabetical order and explains when they are generated. More explanations of 23/06/98 07:02:53.92 A Max 543 AMP Peak A phase protection-generated events are given in the following current sections. 23/06/98 07:02:53.92 B Max 527 AMP Peak B phase current 23/06/98 07:02:54.76 Automatic Reclose 1st reclose 10.1 Event Log Display Updating 23/06/98 07:02:54.77 Pickup Pickup again The Event Log display updates automatically with new 23/06/98 07:02:57.24 Prot Group A Active Protection events provided the most recent event is on the bottom group A line of the screen. When new events occur, they are 23/06/98 07:02:57.24 Phase Prot Trip Phase element entered at the bottom of the screen and the older events caused trip are scrolled up. 23/06/98 07:02:57.24 Prot Trip 2 2nd trip 2.47 sec later 10.2 Protection Generated Events 23/06/98 07:02:57.24 A Max 1315 AMP Peak A phase current The Recloser generates events to aid the user in analysis 23/06/98 07:02:57.24 B Max 1351 AMP Peak B phase of faults or to aid when testing the Recloser. Events are current generated which indicate the following: 23/06/98 07:02:57.38 Lockout Lockout after 2 • Protection ‘Pickup’ occurs when any of the enabled trips protection elements pick up (this event is particularly useful during current injection testing of the Some faults may cause pickup of both ground and phase Recloser). elements, but only one actually trips the Recloser. In this case, the trip event shows the element that caused the • Recloser trip under protection. A series of events trip and the max current events shows the recorded indicate: the active protection setting; whether the magnitude of the fault. trip was caused by Phase, Ground or SGF Protection elements; and the number of the trip, i.e., either single shot or trips 1, 2, 3 or 4. • The magnitude of the maximum RMS fault current detected by the protection relay. Some faults cause more than one protection element to pickup; each
Siemens Power Transmission & Distribution, Inc. 43 10 Event Log
10.3 Loss of Supply Events The control electronics use signals from the voltage screens embedded in the epoxy moldings to determine if the terminals are live. (Refer to “4.5 Control Cubicle Connection” on page 11 for further details). A “Live Terminal” status is indicated on real-time displays (see later) when the voltage exceeds a user-selected threshold voltage setting (SYSTEM STATUS 4: “LIVE” if > 2000V). Terminals are designated as “Dead” when the voltage falls below the Threshold Setting. The live/dead status is used to generate events when supply is lost. To achieve a “Supply On” status, the live bushing status must be sustained on all three source side bushings for the amount time set by the user in the System Status 4: Supply Timeout 5.0s field. If this occurs, a ‘Source Supply ON’ event is generated. Similarly, when supply is lost on any phase for the supply timeout period, a ‘Source Supply OFF’ event is generated. The load side also generates ‘Load Supply ON’ and ‘Load Supply OFF’ events. The designated line-side and source-side bushing designations (“i” and “x” respectively) can be swapped by changing the “Source x” and “Load i” designations. (Refer to the Protection Settings 3 page or to “11.3 Real Time Displays” on page 45.) Note, the designated line and source sides can be swapped in relation to the Recloser bushings. If the voltage on any phase changes from LIVE to DEAD (or vice-versa), and the change is sustained for the Supply Timeout period, the change is recorded in the event log, e.g., ‘Bi Live,’ ‘Bi Dead.’
44 Siemens Power Transmission & Distribution, Inc. 11 Power System Measurements 11 Power System Measurements The Control and Protection Module (CAPM) digitizes the • Which direction is positive power flow for use on the current transformer signals (CT) and voltage screen kWh totals in the Maximum Weekly Demand display. signals (CVT) from the Recloser. These are used for protection and to provide a variety of data for the operator. • Which is the source or load for Live Load Blocking.
11.1 Switchgear Terminal Designation 11.3 Real Time Displays The six terminals on the Recloser are labelled I, II, III and The CT and CVT signals are digitally processed to X, XX, XXX. The phase orientation for these terminals measure data, which is displayed on the Operator Control must be set to match actual field conditions. This is called Panel in real time. Data displayed is as follows: “setting the phasing.” Setting the phasing affects all the • Currents in each phase and ground current. displays, events, etc., concerned with switchgear terminals. For example, the phase notation for any • Real Power (kW), as a signed quantity unless Power voltage measurements, live/dead terminal displays, fault Flow Unsigned has been selected in the System trips, or other events are affected. Status 4: Power Flow Signed/Unsigned field. Phasing is set from the System Status 5 page. (See • Power Factor (PF), as an unsigned quantity. Appendix E: System Status Pages on page 91.) • Terminal Voltage. The voltages can be either phase- The first line of the display allows the operator to cycle to-phase or phase-to-ground. This is a selectable between the six possible phase combinations (ABC, ACB, item from the System Status 4: Display Ph/Ph Volt BAC, BCA, CAB, CBA). When the operator presses field. Enter, the Control orients the currents and voltages to match the selection. • Live/dead terminal indication on the I, II, III side of the Recloser. After the phase orientation has been set, the operator should record the details in the Control Cubicle to indicate The displayed data looks like this. the relationship between the terminals and phases. Refer MEASUREMENT 1 to “15.8 Site Procedure” on page 59. ------INSTANTANEOUS DEMAND ------SYSTEM STATUS 5 Ground 0 Amp A Phase 123 Amp --- SWITCHGEAR TERMINAL DESIGNATION --- 2749 kW B Phase 128 Amp I/X Terminals A Phase 0.93 PF C Phase 121 Amp II/XX Terminals B Phase III/XXX Terminals C Phase The measurement pages 2 and 3 will be displayed differently according to the Source I/Load X or Source X/Load I power flow selection on the System Status 4 11.2 Power Flow Direction page. If the Source I/Load X power flow direction is selected, the measurement pages 2 and 3 appear as Since the Recloser can be connected into the HV lines follows: with either the I or X bushings as the source bushings, the Control must be configured for the correct direction of MEASUREMENT 2 (phase to ground selected) power flow. The direction of power flow is defined as ------SOURCE SIDE VOLTAGES ------being positive from Source to Load. Ai phase to ground 8660 Volt The six terminals on the Recloser are labelled I, II, III and Bi phase to ground 8660 Volt X, XX, XXX. The engineer can configure which set of Ci phase to ground 8660 Volt terminals corresponds to the source and load. The power flow direction is configured on System Status 4: Source I, Load X (this is default) or System Status 4: Source X, MEASUREMENT 3 (phase to ground selected) Load I field. When changed this reverses the power flow ------LOAD SIDE VOLTAGES ------direction but not the phasing. Refer to “11.1 Switchgear Terminal Designation” on page 45. Ax phase to ground Unavailable Bx phase to ground Unavailable The power flow direction setting is used to determine: Cx phase to ground Unavailable • Whether the source or load corresponds to (i) or (x) on the voltage measurement displays.
Siemens Power Transmission & Distribution, Inc. 45 11 Power System Measurements
If the Source X/Load I power flow direction is selected, the • Real Power (kW) averaged over the period. This is a measurement pages 2 and 3 appears as follows: signed quantity unless Power Flow Unsigned has MEASUREMENT 2 (phase to ground selected) been selected in the System Status 4: Power Flow Signed/Unsigned field. See Appendix E: System ------SOURCE SIDE VOLTAGES ------Status Pages on page 91. Ax phase to ground Unavailable • Power Factor (PF) averaged over the period. Bx phase to ground Unavailable The displayed data appears as follows: Cx phase to ground Unavailable MEASUREMENT 4
MEASUREMENT 3 (phase to ground selected) ------AVERAGE DEMAND ------
------LOAD SIDE VOLTAGES ------12/04/1998 13:45:00 A Phase 123 Amp Ai phase to ground 8660 Volt 2749 kW B Phase 128 Amp Bi phase to ground 8660 Volt 0.93 PF C Phase 121 Amp Ci phase to ground 8660 Volt When first selected, the average demand display shows the most recent period. To view older periods, press the If phase-to-phase voltages are selected rather than SELECT key and then the keys. To return to the phase-to-ground on System Status 4, then the ½ ¾ most recent period, press the MENU key. measurement pages 2 and 3 text changes. An example of the new text is as follows: MEASUREMENT 2 (phase to phase selected) 11.5 Maximum Demand Data Displays ------SOURCE SIDE VOLTAGES ------For each week, the period with the largest average Ai/Bi phase to phase 15000 Volt apparent power is recorded and displayed on the Operator Control Panel. Each value is reset on power up, Bi/Ci phase to phase 15000 Volt and the data displays as follows: Ci/Ai phase to phase 15000 Volt • The date of the last day of the week for the peak MEASUREMENT 3 (phase to phase selected) period on display.
------LOAD SIDE VOLTAGES ------• The time of the end of the peak averaging period. Ax/Bx phase to phase Unavailable • The apparent power (kVA) during the peak period. Bx/Cx phase to phase Unavailable • The reactive power (kVAR) during the peak period. Cx/Ax phase to phase Unavailable • The total integrated real power flow (kWh) during the System Status 3 displays the live/dead indication as week. In a system where power can flow both ways, follows: this quantity shows either the net energy flow (i.e., zero, if equal energy had flowed both ways) or the SYSTEM STATUS 3 total power flow (regardless of the setting on System ------LIVE/DEAD INDICATION ------Status 4: Power Flow Signed/Unsigned). Ai Live Ax Unavailable The displayed data appears as follows: Bi Live Bx Unavailable MEASUREMENT 5
Ci Live Cx Unavailable ------WEEKLY MAXIMUM DEMAND ------week ending 28/1/1998 total 7565 kWh 11.4 Averaged Data Displays peak period 22/1/1998 17:15:00 peak demand 31141 kW 0.93 PF The real-time data is averaged over a user-set period to provide average demand data, and can be displayed on the Control Panel. The averaging period can be set to 5, 15, 30, or 60 minutes. Data displayed is as follows: • Date and time of the end of the averaging period. • Currents in each phase averaged over the period.
46 Siemens Power Transmission & Distribution, Inc. 12 Communications Interfaces 12 Communications Interfaces The Control and Protection Module (CAPM) provides When PTT is asserted, the transistor is turned on and external communications interfaces for connection into connects the PTT signal to 0V. (i.e., the equivalent of a communications systems. This interface can be used to relay contact to ground). The FET is rated for a maximum monitor and control the Recloser by a remote computer. of +32V and negative voltages are not permitted. Typical applications would be connection into a SCADA A busy signal can be provided by the radio to indicate system for remote operator control or connection into a receive channel busy. High level is +4.5 to +5V, low level distribution automation system for automatic control by a 0V to +0.5V. Levels in excess of +13V should not be supervising computer. applied. Two physical interfaces are provided on the CAPM and A 600 ohm line isolator accessory is also available from either can be used for this purpose: Siemens (TERM1). • V23 FSK modem with radio interface signals • RS232 interface 12.2 RS232 Interface In addition, a switch mode power supply is provided to An RS232 interface is available on CAPM plug P8, which power the radio/modem. This section describes each is a standard D25 male connector. interface. This interface is provided to connect to conventional modems that provide the correct signaling for the 12.1 V23 Interface communications network used, e.g., fiber optic modem or telephone dial up modem. Signals provided are: An integral FSK modem provides half-duplex V23 signaling at 1200 bits per second. This interface is P8 Pin Direction Use primarily designed for use with voice frequency radio systems and provides additional signals for this purpose. 1 - 0V (ground) The FSK interface is available on CAPM plug P10 as a 2 From CAPM Tx Data (TxD) 15-way “D” connector (part number N03-530). The cable 3 To C A P M Rx Data (RxD) is run to the bottom of the radio panel. A special cable may be required to connect P10 to some specific radios. 4 From CAPM Request to send (RTS) A contact to Siemens or your radio manufacturer may be 5 To C A P M Clear to send (CTS) required in these cases. 7 - 0V (ground) Signals provided on P10 are as follows: 8 To C A P M Data carrier detect (DCD) 9 From CAPM +10V Cable P10 Pin Direction Use 10 From CAPM -10V (N03-530) 20 From CAPM Data terminal ready (DTR) 5 5 - 0 Volts (ground) 4 4 To CAPM Receive, 10 kOhm Pins 9 and 10 are not standard RS232 signals. These are impedance power supply pins that can provide up to 10mA for Sensitivity 0.1V to modems that get their power from the RS232 connector 2V pk-pk (e.g., some types of short haul, fiber optic modems). 15 15 From CAPM Press to talk (PTT) Note: The exact use of signals depends on the protocol software 11 11 From CAPM Transmit, 600 Ohm installed. impedance Level 2.5V pk-pk 6 6 To CAPM Busy, 10 kOhm 12.3 Radio/Modem Power impedance A switch mode power supply for a radio/modem is built into the CAPM and draws its power from the auxiliary Transmit and receive are unbalanced signals relative to 0 supply and/or the battery. volts and are not isolated. If a DC level is imposed by the radio on the transmit line then this should be less than 2.5 VDC. The Press to Talk (PTT) signal is used to key up a radio transmitter. PTT is implemented using a field effect transistor (FET) with an on resistance of less than 1 ohm.
Siemens Power Transmission & Distribution, Inc. 47 12 Communications Interfaces
The supply is available on plug P3 of the CAPM via a disconnect type terminal block. Connections are as follows:
Standard Cable P3 Pin Direction Use Type N03-530 15 Pin D Female 8 AUX + From CAPM Radio/modem power supply positive 1 GND From CAPM 0V (ground)
Note that the power supply is not isolated. The user sets the radio/modem power supply voltage from the Operator Control Panel in the System Status 7: Radio Supply 12 Volts field. This is a password-protected parameter. (Refer to Appendix E: System Status Pages on page 91.) The radio/modem power supply can be automatically shutdown to conserve battery power after a failure of the auxiliary power supply. The shutdown takes place after the radio hold-up time, user set on System Status 6: Radio Hold 60 min has elapsed. If the Radio Hold time is set to zero, then the radio supply will not shutdown, except under special low power circumstances. (Refer to “16.8 Abnormal Operating Conditions” on page 73.) The radio/modem power supply is restored when the auxiliary supply returns to normal. An operator can switch radio/modem power supply on and off for radio maintenance without passwords in the System Status 6: Radio Supply ON field. If the radio supply has been shut down, it will be indicated on System Status 6.
12.4 Connections to Electronics Compartment Connections to the CAPM (if not factory supplied) must be run through the rubber cable duct in the middle of the equipment panel. This duct provides entry into the electronics compartment and seals out airborne pollution. Normally, it will not be necessary to run additional cables into the electronics compartment. If additional cables are required, i.e., for radio/modem data or power connections, spare slots in the duct are available. The spare slots are sealed with a rubber cord. To run cables into the electronics compartment, remove the cord and use the slots. All cables running into the electronics compartment must be round, sheathed, and between 9mm and 10.5mm in diameter to ensure a good seal. Heat-shrink sleeve can be used to increase the diameter of a cable. Section 7 gives instructions for removing the electronics compartment cover to gain access to the CAPM.
48 Siemens Power Transmission & Distribution, Inc. 13 Accessories 13 Accessories You can purchase the following separately: Embedded in the switchgear control is server software for the CSS package. The server provides two interfaces for • Centurion System Software connection to CSS: • Input Output Expander (IOEX) Card • The computer port on the front of the Electronics • Test and Training Set (TTS) Compartment. This is a standard RS232 connection running at 9600 bps and is normally used to connect • Manual Operation Set a portable notebook PC for maintenance purposes such as downloading settings or uploading the event • Remote Control Panel record. • Port P8 on the CAPM card. This is a standard 13.1 Centurion System Software RS232 port running at 2400 bps and can be used to connect via a modem to a PC located elsewhere Section 7: Operator Control Panel describes the MJ-R such as in an office or a workshop. This would Operator Control Panel. An alternative interface to the typically be a dial-up modem connected to a MJ-R Control can be established by connecting a telephone line or a digital cellular telephone modem notebook, or other suitable computer, to the RS232 allowing the PC to control the Recloser from another interface on the Operator Control Panel. The Centurion location. System Software (CSS) is designed for this purpose, and provides the user with an advanced display and Connection can be made from a PC to the CSS server at management system. either port but only one port can be used at any one time. With CSS, protection settings and other parameters can The CSS server software is designated as a Local be pre-configured on a personal computer and uploaded Access, refer to “8.3 Definition of Local or Remote to MJ-R Controls at various on-site locations. Multiple site Access” on page 30. setups and settings changes can be implemented more efficiently; historical data (e.g., demand measurements) from multiple locations can also be downloaded into the 13.2 Input Output Expander (IOEX) notebook computer for analysis and processing Card elsewhere. The IOEX card provides eight optically isolated dry input Remote communication over radio or telephone lines is contacts and eight dry output contacts to allow also possible using CSS. Both point-to-point and point-to- connection of an external RTU. The eight output relays multipoint capabilities are available for remote monitoring have contact ratings of 2A at 150V AC or 1A at 150V DC and control of the Centurion Recloser. non-inductive. The eight input relays require an input level The Centurion System Software is purchased as an of 60-130V AC or 18-150V DC. The IOEX mounts onto additional item. For further information, contact your local the Control Cubicle radio tray and is provided with a Siemens representative. stainless steel cover and cable for connection to the CAPM. CSS provides facilities for: • Online and offline management of all protection 13.2.1 Inputs settings. The standard configuration for inputs and outputs is shown next. • Tripping and closing of the switchgear and other operator control functions. • Uploading of historical data (e.g., event record or demand measurements) into the computer, which can be taken away and processed elsewhere.
Siemens Power Transmission & Distribution, Inc. 49 13 Accessories
13.2.2 Outputs Table 4 Inputs Table 5 Outputs
Pin Inputs ON Pin Output On Output Off Number Number (relay closed) (relay open) Recloser 25-26 Tripped Closed 1-2 Trip the Recloser, set lockout, and inhibit all close operations 27-28 Closed Tripped
3-4 Close the Recloser 29-30 Flag A/B Trip indication. See table 5-6 SGF protection ON below.
7-8 SGF protection OFF 31-32 Lockout Not in lockout
9-10 Auto-Reclose ON 33-34 SGF protection ON SGF protection OFF 11-12 Auto-Reclose OFF 35-36 Auto-Reclose ON Auto-Reclose 13-14 Protection Set A Selected OFF 15-16 Protection Set B Selected 37-38 Flag B, Trip indication. See table • IOEX close - The Recloser close input only functions below. when the control is set to the designated IOEX mode with Work Tag off. For example, if the IOEX 39-40 System Healthy Abnormal card is designated as local, an IOEX close input (Refer to Section condition operates if the control is in Local Mode with Work 17.3) Tag off. Refer to Section 8: Work Tags and Control Mode on page 29. • Tripping and control of all other settings - all other Table 6 Trip Indications based on Trip Source operations function normally in both Local and Trip Source Flag A, Trip Flag B, Trip Remote modes and are independent of the Work indication indication Tag status. Reset, Set to this Off Off • If the IOEX Trip input is held on when either the state on Recloser IOEX close or manual close input is activated, the Close. Recloser does not close. This is indicated in the event log by a ‘Close Blocking ON’ and ‘Close Phase Trip On On Blocking OFF’ event whenever the IOEX Trip input changes state. Ground Trip Off On • The SGF Protection ON functionality operates SGF Trip On Off normally as discussed in “9.11 Sensitive Ground Fault (SGF)” on page 36. If the Ground Fault Note A: The Trip Source outputs do not indicate other causes Protection or the SGF availability for the active of a trip such as Loss of Phase. Protection Group is turned off, SGF Protection will NOT turn on. Note B: The IOEX contacts are not guaranteed to change during fast Auto-Reclose sequences but will indicate Note: If both SGF Protection ON and OFF inputs are on, the the final steady state condition within 300 ms. default is SGF Protection ON. If both Auto-Reclose ON and OFF inputs are on, the default is Auto-Reclose ON. 13.2.3 System Healthy Indicator The IOEX system healthy indicator is present when all of the following are true: • Aux supply OK. • Battery supply OK. • SCEM Data valid.
50 Siemens Power Transmission & Distribution, Inc. 13 Accessories
• CAPM electronics OK. 13.5 Remote Control Panel • Contact Life greater than 20% on all phases. The Remote Control Panel provides dual control for Siemens Reclosers installed in substation applications. • IOEX to CAPM communications OK. The Remote Control Panel duplicates the Operator • Failure of any of these will cause the system healthy Control Panel to provide almost identical functionality to flag to be extinguished. that provided at the Control Cubicle. The Remote Control Panel is purchased as an additional 13.2.4 Power Consumption item. For further information, contact your local Siemens If an IOEX card is supplied in the Control Cubicle, the representative. battery hold-up time can be affected. This is due to the current drawn by the IOEX card and its relay coils. An IOEX card draws 10 mA without any relays turned on. The relays draw approximately 20 mA each for an IOEX- 1 and 10 mA each for an IOEX-2. There can be up to four relays energized at once with at least one relay energized at all times. Therefore, an IOEX-1 draws a minimum of 30 ma and a maximum of 90 mA while an IOEX-2 draws a minimum of 20 ma and maximum of 50 ma. The battery hold-up time rating does not include an IOEX card.
13.3 Test and Training Set (TTS) For simplified testing in the field or in the workshop, a purpose built test set called a Test and Training Set (TTS) is available. The TTS is a suitcase-sized test set that connects to the Control Cubicle. It allows a standard secondary injection test set to be connected to inject currents into the Control Cubicle. The TTS also simulates the switchgear and allows comprehensive testing of the control electronics. The TTS is highly suited to train staff in maintenance and operations. The test and training set is purchased as a separate item. For further information, contact your Siemens distributor.
13.4 Manual Operation Set The Manual Operation Set provides a means to manually trip or close the Recloser when a Control Cubicle is either not available or not functioning properly. The set operates the magnetic actuator inside the Recloser using the trip/close capacitor, and batteries internal to the set. No external power source is required. The Manual Operation Set is purchased as an additional item. For further information, contact your local Siemens representative.
Siemens Power Transmission & Distribution, Inc. 51 13 Accessories
52 Siemens Power Transmission & Distribution, Inc. 14 Receiving and Handling 14 Receiving and Handling
14.1 Receiving cannot be made on vehicles prior to unloading, close inspection during unloading must be performed and Each Centurion Recloser is securely blocked and braced visible damage noted on the delivery receipt. Take for shipment. Every precaution is taken to ensure its safe pictures if possible. arrival. The Reclosers must be handled carefully when unloading and moving to avoid damaging the equipment. 3. Note any visible damage on the delivery receipt. Obtain the driver's signature on the receipt. The damage should be detailed as much as possible. It is essential that you include a notation “Possible internal damage, subject to inspection” on the delivery receipt. If the driver will not sign the delivery Heavy weight with a high receipt with damage noted, the shipment should not center of gravity. be signed for by the consignee or his agent. Can cause death, serious 4. Notify the Siemens sales office immediately of any personal injury or property damage. damage. 5. Arrange for a carrier inspection of damage Observe all handling instructions immediately. in this instruction manual to IMPORTANT: Do not move equipment from the prevent tipping or dropping of place it was set when unloading. Equipment must be equipment. inspected by carrier prior to handling after receipt. This eliminates loss due to claims by carrier that equipment was damaged or further damaged on-site 14.2 Inspection after unloading. Inspect the equipment as soon as possible after receiving 6. Be sure equipment is properly protected from any for any damage that may have occurred in transit. further damage by covering it properly after unloading. 1. Before unloading, make a physical inspection of the Recloser, checking for shipment damage or 7. If practical, make further inspection for possible indications of rough handling by the carrier. concealed damage while the carrier’s inspector is on- site. If inspection for concealed damage is not 2. Check the shipping manifest to be certain that all practical at the time the carrier’s inspector is present, items have been received. you must inspect it within 15 days of receipt of 3. If there is a shortage, make certain it is noted on the equipment. If concealed damage is found, you must freight bill and contact the carrier immediately. again notify the carrier and complete the inspection prior to taking any corrective action to repair. Also 4. Notify the Siemens sales office of any shortage or notify Siemens sales office immediately. damage. 8. Obtain the original copy of the carrier inspection report and forward it along with a copy of the noted 14.3 Shipping Damage Claims delivery receipt to the Siemens sales office. Obtain approval by Siemens from the carrier before any IMPORTANT: The way visible shipping damage is treated repair work can be performed. Before approval can by consignee prior to signing the delivery receipt can be obtained, Siemens must have the documents. The determine the outcome of the damage claim to be filed. carrier inspection report and/or driver’s signature on Notification to carrier within the 15-day limit on concealed the delivery receipt does not constitute approval to damage is essential if loss resulting from unsettled claims repair. is to be eliminated or minimized. Note: Any adverse judgment as to whether the equipment 1. When shipment arrives, note whether equipment is was properly loaded or properly prepared by shipper for properly secured for transit. Note trailer number on over-the-road travel cannot be made at the destination. which the equipment arrived. Note blocking of Shipments are not released from the factory with a clear equipment. During unloading, make sure count bill of lading. Approved methods are employed for agrees with delivery receipt. preparation, loading, blocking and securing of the equipment before it leaves the Siemens factory. 2. Make immediate inspection for visible damage upon Therefore, if the equipment is received in a damaged arrival, and prior to unloading. When total inspection condition, this damage to the equipment had to occur
Siemens Power Transmission & Distribution, Inc. 53 14 Receiving and Handling while enroute due to conditions beyond Siemens’ control. If the procedure outlined above is not followed by the consignee, purchaser, or his agent, Siemens cannot be held liable for repairs. Siemens will not be held liable for repairs in any case where the work was performed prior to authorization from Siemens.
54 Siemens Power Transmission & Distribution, Inc. 15 Installation 15 Installation The control system block diagram is shown in Figure 5. 4. Carefully unbolt the 30 kg (66 lbs) mounting bracket. The main features are explained below. Support the bracket with a crane and lifting sling, if necessary, to avoid dropping the bracket on the Recloser and remove the bracket from the crate. 15.1 Unpacking & Checking Each crate includes: • A Centurion Recloser. NOTICE • Pole mounting bracket that is either an end or center Take great care not to drop mount type. This is bolted to the wall of the crate the bracket, which weighs and is equipped with necessary nuts and bolts to nearly 28 kg (62 lbs), onto attach it to the Recloser. the Recloser. • Control Cubicle. 5. Remove the screws that secure the Recloser and lift • Control Cable. out using the crane, lifting slings, lifting points shown Optional extras that may have been purchased include: in Figure 1 “Recloser Features” on page 13. Store carefully in a clean dry place. • Surge arrester mounting brackets. Two are supplied 6. Remove the screws that secure the Control Cubicle with a Recloser end mounting bracket and one is and lift out. Store carefully in a clean dry place. supplied with a Recloser center mounting bracket. Arrester brackets are screwed to the floor of the crate and are equipped with necessary nuts and bolts to attach it to the Recloser. • Clamp bands to attach the mounting bracket to circular poles that cannot be drilled (there are different clamp bands to suit different pole diameters). • Cable clamps to connect the HV cables to the Recloser. On receipt, the unit should be checked for completeness and shipping damage. If any problems are found, contact your local Siemens representative immediately.
15.2 Unpacking Procedure Tools required: • Reversible battery drill or ratchet drive with 3/8" hex socket. This is used to disassemble the crate and to remove most of the parts attached to the crate. • Two 16 mm wrenches (or two adjustable wrenches). These are used to remove the mounting bracket from the crate. • Crane, 4 D-Shackles and two lifting slings with a 150 kg (330 lbs) capacity. Procedure: 1. Remove screws from top of crate. 2. Remove screws from front of crate. 3. Lift out the control cable.
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Note: The Control Cubicle weighs approx. 35 kg (77 lbs).
Check Orientation
Locate and push home Wiggle to check locking
Figure 20 Plugging in the Control Cable
1 Grip and squeeze to open locking clips 2 Wiggle to release 3Pull
Figure 21 Unplugging the Control Cable
56 Siemens Power Transmission & Distribution, Inc. 15 Installation
15.3 Plugging and Unplugging 4. Connect the other end of the control cable into Control Cable connector P1 on the Control Cable Entry Module (CCEM). Refer to Figure 20 and Figure 21. 5. If desired, the LV auxiliary supply (external supply) can be connected as shown in Figure 28. 6. Turn on the battery and auxiliary supply circuit breakers at the top of the Control Cubicle. Potential voltage surges. Complete the following tests: May result in mis-operation or 1. Trip and close the Recloser from the Control Cubicle. damage to the equipment. 2. Insulation test the high voltage connections to ground Switch off the AC & DC low voltage to check for shipping damage on the high voltage miniature circuit breakers in the side of the Recloser. See table below. control cubicle before connecting or disconnecting the control cables.
When installing or testing the Recloser, you must connect and disconnect the control cable. Figure 20, Figure 21, Vacuum Interrupters may emit and the following describe proper methods for connecting X-radiation. and disconnecting the control cables. Can cause serious personal • Power down the Control Cubicle by switching off all injury. miniature circuit breakers (MCBs). This should be done whenever connecting or disconnecting the X-rays can be produced when a high control cable from the Control Cubicle. voltage is placed across two circuit elements in a vacuum. • To plug in, hold the plug by the long sides; check the Keep personnel more than six (6) orientation; gently locate it on the socket and push feet away from the Recloser during firmly home. Check for a locked connection by application of test voltages. After test wiggling the plug. If the plug cannot be pushed on completion, ground all accessible with moderate force, the connection was not located terminals to dissipate any static properly. A heavy force is never required to seat the charges. plug. • To unplug, hold the plug by the short sides and grip hard to release the internal clips (not visible from the Table 7 High Potential Test Voltage outside). Wiggle to allow the clips to release, then pull the plug out. Never pull the plug out by the Rated Power Field Test Voltage cable. Maximum Frequency Voltage Withstand
kV (rms) kV (rms) kV (rms) kV (dc) 15.4 Testing & Configuring 15 50 37.5 53 1. Unpack the crate as above and put the Control Cubicle and the control cable in a clean safe place 27 60 45 63.6 where they will not be damaged or soiled. 2. Make a temporary ground connection between the Note: Do not use high potential testers incorporating half-wave Control Cubicle and the Recloser. This need only be rectification. These devices produce high peak voltages. 1 mm² (16 AWG or larger) copper wire. These high voltages will produce X-ray radiation. These devices 3. Unbolt the blanking plate from the bottom of the show erroneous readings of leakage current when testing vacuum circuit Reclosers. Recloser and connect the cover end of the control cable to P1 on the Switch Cable Entry Module (SCEM), located just inside the tank. Refer to Figure 22 and “15.3 Plugging and Unplugging Control Cable” on page 57. Do not bolt the cover to the tank unless this is the final installation since the sealing gasket on the cover should not be re-used once fully compressed.
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6. The radio/modem plate can be unscrewed and a radio or modem equipped, connected, and tested as required. Important Notes: • When a Recloser is connected to a Control Cubicle, High potential tests employ the control reads the switchgear memory. Five hazardous voltages. minutes after an operation occurs, the Control Will cause death or serious Cubicle writes to Recloser memory with the latest personal injury. operations count and contact wear data. The Control Cubicle beeps during the writing process. Always Always follow proper procedures. wait 5 minutes after an operation before turning off Isolate the equipment, exclude the Control Cubicle so the changed data can be unnecessary personnel and use written to the Recloser. Do not turn off or unplug the safety barriers. Keep away from the Control Cubicle during the writing process. Recloser during application of test voltages. After test completion, • Maintain and operate the battery using the ground all accessible terminals to instructions given in “16.3 Battery Care” on page 71. dissipate any static charges. Note that supplying the batteries with reverse polarity will cause damage to the electronic systems. 3. Configure the protection settings. An application note detailing workshop and field test 4. Perform primary current injection as required. procedures (part number N00-113) is available. Contact 5. Perform secondary current injection as required your local Siemens representative for more details. using a Test and Training Set (TTS).
Figure 22 SCEM Compartment
58 Siemens Power Transmission & Distribution, Inc. 15 Installation
15.5 Transport to Site • 20mm sealing cable entry glands to suit auxiliary (external) supply cables; 32 mm sealing cable entry If the unpacking and testing were carried out in the glands to suit antenna or communications cable as workshop, the Recloser and Control Cubicle must now be required. transported safely to the installation site. It is important the following steps are carried out: • Antenna, antenna feeder cable and surge arrester where a radio is equipped (unless supplied by 1. Turn off all Control Cubicle circuit breakers and Siemens). disconnect all auxiliary power supplies. Disconnect the control cable from both Recloser and Control • Cable ferrites for IOEX cables (if IOEX card is Cubicle; re-install the blanking plate on the bottom of supplied). the Recloser. 2. Either remove the batteries from the Control Cubicle and safely transport separately, or make sure the 15.8 Site Procedure batteries are securely anchored in the Control To erect and test the Recloser, carry out the following Cubicle with the strapping. steps; mounting details are given in Figure 24, 25, 26 and Transport the Recloser, Control Cubicle, and all parts in a 27. safe and secure manner to the installation site. The recommended method is to re-pack the equipment in the original crating.
Hazardous voltages. 15.6 Tools Required Will cause death, serious • Torque wrench and socket set personal injury or property damage. • Tools to prepare pole as required Always follow proper safety • Crane or other lift for Recloser and Control Cubicle, procedures. De-energize the four D shackles, and slings Recloser, establish visible disconnects on each side of the Recloser, and ground the Recloser 15.7 Parts Required (Not supplied by terminals before working on this Siemens) equipment. Do not rely solely on the • Two 20 mm (¾ in) galvanized or stainless steel bolts manual handle or the position with washer and nuts, etc. to bolt mounting bracket indicator to ensure the line has been to power pole. Refer to Figure 23 “H.V. Cable de-energized. Termination” on page 61 and Figure 26 “Center 1. Transport Recloser to the installation site and carry Mounting and Dimensions” on page 65. If the out testing prior to installation as required. optional pole clamps have been purchased, this is not required. 2. Ensure the pole is of sufficient strength to support the Recloser. Reference applicable construction • Mounting parts for the Control Cubicle. Either 20 standards or structural engineer to calculate the mm (¾ in) stainless steel pole clamp or 10 mm stresses involved. galvanized or stainless steel bolts, nuts, etc. Refer to Figure 2 “Control Cubicle” on page 16. 3. Securely mount the Recloser bracket on the power pole. • Mounting hardware for control cable. This is standard 25 mm (1 in) sheathed conduit and can be 4. Lift and position the Recloser. Lower the Recloser mounted to the pole with ties, straps, P-clips or onto the mounting bracket and fix with the four 16 saddles. mm nuts and bolts provided; tighten to 100 Nm (73.75 ft lbs). Add surge arrester brackets and surge • Ground wire and lugs for the grounding scheme and arresters as required. parts for LV mains auxiliary power connection. Refer 5. Complete the high voltage connections and note the to Figure 23 “H.V. Cable Termination” on page 61, terminal wiring on the record sheet in the cubicle. Figure 28 “L.V. Auxiliary Supply Connection” on page 67, and “15.11 Grounding” on page 62. 6. Lift the Control Cubicle into position and bolt or strap to the power pole. Note that the Control Cubicle mounts are provided with keyed holes to facilitate
Siemens Power Transmission & Distribution, Inc. 59 15 Installation
being lifted onto the mounting bolt and simply slid 14. Confirm that the batteries are installed and strapped into position. into place. Confirm also that the leads are properly connected. Leads are properly connected with: 7. Run the ground connections as shown in Figure 29. Refer also to “15.11 Grounding” on page 62. • Batteries connected in series (gray lead connecting black terminal of one battery to red terminal of the other battery).
• Red lead connected to the remaining red battery terminal. Hazardous voltages. • Black lead connecting to the remaining black Will cause death, serious battery terminal. personal injury or property damage. Ground the Recloser frame, surge arresters (if any) and Control Cubicle in accordance with all grounding The batteries supplied with the instructions in this instruction Recloser can deliver high manual. discharge currents. 8. For power from the (external) LV supply to the MCBs, May result in personal injury or install wiring as shown in Figure 29. Refer also to damage to equipment. “15.12 LV Auxiliary Power from LV Conductors” on page 67. It is vital that the Recloser is grounded Do not reverse polarity when making as instructed. Carry out the wiring connections battery connections. Immediately inside the Control Cubicle as shown in Figure 28. replace any frayed leads or Make sure the LV mains cable is run in the damaged connectors. channel behind the equipment panel. 15. Power up the Control Cubicle and test the operation 9. For LV supply from a dedicated transformer supplied of the Recloser. by the utility, connect as shown in Figure 30. Refer to 16. Mount the antenna and run antenna feed to Control “15.13 LV Auxiliary Power from Dedicated Utility Cubicle or run external communications cable to Transformer” on page 68. Control Cubicle. Use cable entry shown in Figure 2 10. For integrated supply from an external transformer, with a sealing 32 mm gland. connect as shown in Figure 30. Refer to “15.13.1 17. The Recloser is now ready for energizing and Auxiliary Power from Integrated Transformer” on commissioning. This should include setting the page 68. terminal designation (“11.1 Switchgear Terminal 11. Remove the cover plate from the bottom of the Designation” on page 45) and the power flow Recloser tank and connect the control cable to plug direction (“11.2 Power Flow Direction” on page 45). P1 on the Switch Cable Entry Module (SCEM) located inside the tank. Refer to “15.3 Plugging and Unplugging Control Cable” on page 57 for the plug-in 15.9 HV Connections procedure. Make sure the rubber sealing ring on the The HV terminals are dia 20 mm tin plated copper stems Recloser side of the cover plate is not pushed out of with M10 x 1.5 tapped holes in the ends. Connections are place. If this happens simply re-seat it in the hole and made to the Recloser terminals using one of the methods bolt up the cover. Note that the cover can be bolted below. See Figure 23. on in different orientations to best suit the installation. 12. Run the control cable from Recloser to Control • Parallel groove clamps that grip both the cable and Cubicle. the stem. These are standard line equipment available in bimetallic versions to connect to copper 13. Remove the blanking plate of the Control Cubicle and or aluminum conductors. These are suitable for all feed the control cable through the bottom of the cable sizes. Refer to Appendix G: Replaceable Parts Control Cubicle and plug into connector P1 on the & Tools on page 95 for a recommended type. control cable entry module (CCEM), as shown in Figure 20 “Plugging in the Control Cable” on page • Crimp lugs with holes for M10 bolts. These are 56. suitable for cable sizes up to approximately 70 mm2 (2/0) and are available in bi-metallic versions.
60 Siemens Power Transmission & Distribution, Inc. 15 Installation
Figure 23 H.V. Cable Termination
15.10 Surge Arrester Mounting and Terminating Surge arrester brackets can be mounted on the Recloser tank. Refer to Figure 24, Figure 25, Figure 26, and Figure 27. These provide a single 14mm diameter hole for mounting and automatically grounding the surge arresters via the tank top. When the Recloser is end mounted, surge arrester brackets can be mounted on both sides of the Recloser. When center mounted a single surge arrester bracket can be installed on the I side of the Recloser, and the X side surge arresters can be installed on a cross arm. When surge arresters are mounted on a cross arm, it is essential that the ground for the surge arresters is connected to the ground terminal on the Recloser.
Siemens Power Transmission & Distribution, Inc. 61 15 Installation
those paths. This arrangement should be followed on both conducting and insulating power poles. NOTICE The main ground bond should be physically separated from the control cable as they run down the power pole by Omitting this procedure the maximum spacing available. This should be at least invalidates the warranty. 200 mm (8 in) for wood and concrete poles and 100 mm (4 in) for steel poles. Surge arresters should be connected to the cables that connect the Recloser terminals to the lines. Connecting closer to the Recloser is better than further away. It is usually easiest to install the brackets and surge arresters on the Recloser prior to lifting it onto the pole. Use the two bolts provided, but do not use the holes for the Recloser mounting bracket. Then, when the Recloser is lifted into position, the correct holes are free for attaching the Recloser to the mounting bracket. Note that the Recloser mounting bolts attach the surge arrester brackets to the Recloser and the Recloser to the mounting bracket.
15.11 Grounding Figure 29 shows the grounding common to all installations.
Hazardous voltages. Will cause death, serious personal injury or property damage. Ground the Recloser frame, surge arresters (if any) and Control Cubicle in accordance with all grounding instructions in this instruction manual.
This arrangement bonds the Recloser frame and the surge arresters directly to ground through a main ground bond consisting of a copper conductor of at least 70 mm2 (2/0). Any surges will flow down this path. Do not ground surge arresters by a different path, doing this may cause damage to the control electronics or Recloser. Also, any antenna and antenna surge protection should be bonded to the Recloser or the main ground bond. The Control Cubicle is connected to this main ground bond by a tee-off. This can be by way of a parallel groove clamp or crimped tee connector. Use of split bolts is not recommended. The Control Cubicle electronics are internally protected from potential differences that may occur between Recloser frame and Control Cubicle frame while surge currents are flowing down the main ground bond. No other connections to ground from the Control Cubicle are allowed since surge currents also flow in
62 Siemens Power Transmission & Distribution, Inc. 15 Installation
Figure 24 Recloser End Mounting and Dimensions
Siemens Power Transmission & Distribution, Inc. 63 15 Installation
Figure 25 End Mounting Example
64 Siemens Power Transmission & Distribution, Inc. 15 Installation
Figure 26 Center Mounting and Dimensions
Siemens Power Transmission & Distribution, Inc. 65 15 Installation
Figure 27 Center Mounting Example
66 Siemens Power Transmission & Distribution, Inc. 15 Installation
Figure 28 L.V. Auxiliary Supply Connection also necessary to connect the neutral of the LV system to the main ground bond using a tee-off as shown in Figure 29. A LV surge arrester must also be grounded to the tee- 15.12 LV Auxiliary Power from LV off as shown. Conductors This connection scheme bonds the LV and HV grounds and protects the primary insulation of the auxiliary supply transformer in the Control Cubicle when surge currents are flowing. Additional LV surge arresters should be equipped to all the other LV phases (if they exist) to balance the supply for other users connected to the LV system. Hazardous voltages. If local conditions or wiring rules prohibit the bonding of Will cause death, serious the HV and LV systems in this way, auxiliary supply to the personal injury or property control cubicle from the LV mains system is not possible. damage. One of the alternative arrangements detailed next should Ground the Recloser frame, surge be used instead. arresters (if any) and Control Cubicle in accordance with all grounding instructions in this instruction manual.
When connecting external power from 2-wire or 4-wire secondary conductors to the main LV circuit breaker, it is
Siemens Power Transmission & Distribution, Inc. 67 15 Installation
15.13 LV Auxiliary Power from the gland, connect the auxiliary supply to the screw Dedicated Utility Transformer terminal block on the SCEM marked "AUX SUPPLY" and replace the cover. Bond the transformer ground to the Figure 30 shows wiring and grounding if a dedicated Recloser ground stud as shown in Figure 30. transformer is supplied by the utility. Note: this transformer should not be used to supply any other The integral transformer must be specified at time of equipment without consulting Siemens to ensure no order so the correct version of Control Cubicle can be hazard is caused to the Control Cubicle electronics. supplied. Transformers are supplied crated separately from the ACR.
15.14 Protection of Radio Equipment Hazardous voltages. It is highly advisable to connect a gas discharge type surge arrester in the antenna feed to the radio. Failure to Will cause death, serious do so can result in damage to the radio and the control personal injury or property electronics. Damage of this nature is not covered by the damage. product's general warranty. Ground the Recloser frame, surge A feed-through or bulkhead type arrester mounted to the arresters (if any) and Control Cubicle outside bottom of the cubicle is ideal. If an in-line arrester in accordance with all grounding is equipped internally, it should be grounded to an instructions in this instruction Equipment Panel mounting stud with the shortest manual. possible wire. Figure 28 L.V. Auxiliary Supply Connection shows that the transformer and any steelwork are grounded to the 15.15 IOEX Cabling Recloser tank and that one side of the transformer secondary is grounded to the ground stud on the To ensure electromagnetic compatibility compliance is equipment panel inside the Control Cubicle. maintained, ferrite filters should be installed on all input/output IOEX cables. A suitable type of ferrite is 15.13.1 Auxiliary Power from Integrated specified in Appendix G: Replaceable Parts & Tools on Transformer page 95. Siemens can provide a dedicated supply that connects directly into the control electronics. This is called an Integrated Auxiliary Supply. 15.16 Transformer Switching If the Recloser application involves switching unloaded transformers, confirm that the system configuration is not prone to repetitive re-strike. Check with your Siemens representative if further advice is required. Hazardous voltages. Will cause death, serious personal injury or property damage. Ground the Recloser frame, surge arresters (if any) and Control Cubicle in accordance with all grounding instructions in this instruction manual.
An external transformer is mounted on the power pole as shown in Figure 30, which also shows suggested HV connections. The secondary of the external transformer connects into the SCEM located on the bottom of the circuit breaker. To connect the transformer secondary remove the SCEM compartment cover, pass the cable with pre-equipped cable gland through one of the holes in the cover, secure
68 Siemens Power Transmission & Distribution, Inc. 15 Installation
Figure 29 Common Grounding and LV Supply
Siemens Power Transmission & Distribution, Inc. 69 15 Installation
Figure 30 Utility Aux Transformer and Integrated External Transformer
70 Siemens Power Transmission & Distribution, Inc. 16 Maintenance 16 Maintenance Maintenance is carried out using standard electricians and mechanics tools.
The batteries supplied with the The use of unauthorized parts in Recloser can deliver high the repair of the equipment or discharge currents. tampering by unqualified personnel will result in dangerous May result in personal injury or conditions which will cause damage to equipment. death, serious injury or Do not reverse polarity when making equipment damage. battery connections. Immediately Follow all safety instructions replace any frayed leads or contained in this manual. damaged connectors.
16.1 Recloser Maintenance The battery replacement procedure is as follows: No user maintenance of the Recloser mechanism is 1. Turn off battery circuit breaker. required. The Recloser should be considered for 2. Unplug batteries and replace with new batteries. refurbishment or retired if the mechanical duty or breaking duty on any phase is exceeded. This can be 3. Confirm that battery polarity is correct. See Step 14 determined by examining the remaining contact life in “15.8 Site Procedure” on page 59. indicator on the Operator Control Panel. 4. Turn on battery circuit breaker. Every five years the epoxy resin moldings should be 5. Verify “Battery Normal status” displays. See the checked and cleaned if necessary; the pointer should be System Status 2 display page. (Refer to Appendix E: checked to ensure it is free from mechanical obstructions. System Status Pages on page 91.) In areas of high contamination, a more frequent cleaning may be appropriate. 16.2.3 Protection and Operation Check Bypass the Recloser and conduct primary injection 16.2 Control Cubicle Maintenance testing to check Recloser protection and operation. Maintenance of the Control Cubicle is required every five Alternatively use a Test and Training Set to perform years to carry out the work given below. secondary injection. The Test and Training Set Manual gives procedures for in-service and bypassed testing of 16.2.1 Control Cubicle Cleaning both the Control Cubicle and the Recloser. Check for excessive dirt on the Cubicle, particularly the 16.2.4 Door Seal roof, and clean off. Ensure the louvers are not blocked and ensure the cooling and drainage holes in the base Check the door sealing rubber for degeneration or undue are open. hardening. If necessary, replace seal.
16.2.2 Battery Replacement 16.3 Battery Care Battery replacement is recommended after a period of five years. Refer also to “16.3 Battery Care” on page 71. The battery is selected to provide good performance for the recommended five-year service period. This is based on the battery manufacturer’s data. No battery warranty is given by Siemens Power Transmission & Distribution. In some environments, an exceptionally high Control Cubicle temperature can mean a shorter battery replacement period. Consult Siemens Power Transmission & Distribution if you suspect your environment to be excessively hot.
Siemens Power Transmission & Distribution, Inc. 71 16 Maintenance
Once in service, batteries need little care. Procedures for and employ substitution techniques to determine the storage and other contingencies are as follows: location of the fault. Faulty Reclosers should be returned to Siemens for factory repair. Faulty control cables should • Battery storage, if required, shall not exceed a be replaced. Faulty Control Cubicles can be checked and maximum of one year. Battery storage temperature repaired as indicated next. shall be maintained between -10°C to 30°C, and shall be cycled every six months. 16.4.1 Control Cable Check • Batteries should be cycled prior to placing into The control cable is a “1-to-1” cable. This means a direct service if they have not been cycled within three end-to-end continuity test of all the connections in the months. The batteries have been cycled within the control cable can be made with a digital volt meter (DVM) previous 180 days at the time of shipment by set for resistance measurements. All pins should show a Siemens. 1-to-1 connection less than 0.2 Ohms with no shorts • If the batteries are depleted in service and are left between pins. for more than two weeks without external supply, they should be replaced, cycled, and capacity 16.4.2 Switchgear Check checked before being returned to service. The control cable connects to the switchgear at the To cycle a battery, discharge with a 10 Ohm 15 Watt SCEM compartment (bottom of the Recloser) or at the resistor to a terminal voltage of 10 V. Next, recharge it CCEM compartment (bottom) of the Control Cubicle. with a voltage regulated DC supply set to 13.8 V; a 3 A Some, but not all, of these connections can be tested with current limited supply is appropriate. a hand held DVM, and some faults can be detected with a simple test. The following procedure can be used to test Battery type is given in Appendix G: Replaceable Parts & the resistance between pins as shown in the following Tools on page 95. More information on battery care is table. available from the battery manufacturer. Do not apply any tests to the Recloser other than those shown in the following table.
Table 8 Resistance Tests
Pins Use Expected Result The batteries supplied with the Recloser can deliver high discharge currents. 1 to 5 Trip solenoid. 1.5 Ohm +/- 0.5 Ohm May result in personal injury or damage to 3 to 5 Close solenoid. 2 Ohm +/- 0.5 Ohm equipment. 4 to 8 I phase CT 7 Ohm +/- 4 Ohm Do not reverse polarity when making battery connections. Immediately replace any frayed 12 to 16 II phase CT 7 Ohm +/- 4 Ohm leads or damaged connectors. 20 to 24 III phase CT 7 Ohm +/- 4 Ohm
21 to 11 Auxiliary travel < 5 Ohm when 16.4 Fault Finding switch, closed Recloser is tripped indicates 100k Ohm when In the unlikely event that there is a problem with the Recloser is Recloser is closed Centurion Recloser or MJ-R Control, it may be explained tripped in “16.8 Abnormal Operating Conditions” on page 73. If not, it may be possible to systematically trace the fault 22 to 11 Auxiliary travel < 5 Ohm when and correct the problem. Potentially, a fault could arise in switch, closed Recloser is closed any of the following main components: indicates 100k Ohm when Recloser is Recloser is tripped • Centurion Recloser closed • Control Cable 23 to 11 Indicates when < 5 Ohm when Manual • MJ-R Control Cubicle the Manual Trip Trip Ring is in the Ring is down in normal position The best way to trace a fault is by a process of elimination the locked 100k Ohm when using the Test and Training Set (TTS-001) to isolate the position. Recloser is tripped faulty component. If a Test and Training Set is not and the mechanism is available, use the check procedures suggested below locked open
72 Siemens Power Transmission & Distribution, Inc. 16 Maintenance
16.4.3 Control Cubicle Check of the Operator Panel Subsystem (OPS). For access to these parts refer CAPM Replacement Procedure Fault finding within the Control Cubicle involves N00-117. Refer to Appendix J: Control Cubicle determining whether the fault lies in the electronic Schematics on page 103 for Control Cubicle wiring modules, the wiring, or elsewhere. The electronic schematics. modules are user replaceable items. Other faults require the Equipment Panel or the entire Control Cubicle be Note: The electronic modules supplied with this Recloser can be returned to the factory. damaged by static electricity, water, dirt or mishandling. Repairs or maintenance should only be conducted by competent Appendix J: Control Cubicle Schematics on page 103 personnel in a suitable workshop environment. shows the Control Cubicle wiring schematics. A suggested fault finding checklist is as follows: • If the microprocessor running LED on the Operator 16.6 Replacement of Cables Panel is blinking, the CAPM micro and the Operator It is easier to install and remove cables from the cable Panel Subsystem (OPS) microprocessor are duct if they are lightly greased with silicone grease. operational. If the LCD Display Panel does not operate, there is a problem with the display itself and the OPS should be replaced. 16.7 Installing or Replacing Heater • If the display is operating, check the System Status Control Cubicle Schematic 8 in Appendix J: Control 2 pages for an indication of any power supply Cubicle Schematics on page 103 shows the wiring problems (Aux Supply Fail and/or Battery OFF) that diagram for models equipped with a heater. The can be traced and rectified. thermostat is located inside the electronics compartment and is set to +15°C. • If the display indicates the Recloser is disconnected or if there are operating problems, the control cable and the CCEM should be inspected and replaced as 16.8 Abnormal Operating Conditions required. The performance of the capacitor charging inverter can • If the microprocessor running LED is not blinking, be affected under abnormal conditions such as when the most likely problem is loss of power. Check the battery capacity is very low. The following features protect presence of battery voltage on the battery CB and the control in this situation and allow the Recloser to the presence of aux supply on the aux supply CB continue to operate. and rectify as required. • If power supply is present, attempt to go online with 16.8.1 Low Power Mode CSS to determine whether the CAPM is functioning When the batteries are nearing depletion, the Control correctly. Replace the CAPM or the Operator Panel changes from normal to low power capacitor-charging Subsystem as required. mode. In Low Power Mode the Control takes longer to charge the capacitors and the radio supply is shut down. • If this does not rectify the problem, the Control A ‘Low Power Mode’ event is logged when this happens. Cubicle should be returned for factory repair. When a trip occurs in Low Power Mode, the Recloser goes to lockout if the capacitors cannot be recharged 16.5 Replacement of Electronic quickly enough. Operator close and trip operations can Modules be performed, but at a longer time interval than normal. If an operator trip or close request is denied, a ‘Cap Chrg’ Electronic modules are user replaceable as detailed next. maintenance event is logged. These modules can be damaged by static electricity, water, dirt, and mishandling. Therefore, competent To return to normal power mode, either replace the personnel should only conduct this repair work in a batteries or re-establish the auxiliary supply for a suitable location (such as in a workshop). minimum of 15 minutes. 1. Access the Control Cable Entry Module (CCEM) by removing its cover plate held in place by four screws. 2. To remove the CCEM, hold the ¼ inch spacer underneath the board with a wrench and remove the four M4 screws. 3. The Electronics Compartment houses the Control and Protection Module (CAPM) and the trip and close capacitors. The compartment cover forms part
Siemens Power Transmission & Distribution, Inc. 73 16 Maintenance
16.8.2 Excess Close Operations It is possible to trip/close so frequently during testing that the capacitor charging inverter shuts down to avoid overheating. When this happens, the inverter shuts down for 5 minutes and a ‘Cap Excess Closes’ event is logged. During this time all trip/close requests are denied. This does not happen in normal service as more than 20 operations per minute are required to reach this condition.
74 Siemens Power Transmission & Distribution, Inc. Appendix A IEC255 Inverse Time Protection Tables A IEC255 Inverse Time Protection Tables The Inverse Time Protection Curves in this appendix are Setting Inverse Very Extremely as defined by IEC255 standard where “I” is the actual Current Time Inverse Inverse Time current expressed as a multiple of the trip current set by Multiple (sec) Time (sec) (sec) the user: 12.00 2.75 1.23 0.56 • Type A - Inverse, for which equation is: Time to Trip = 0.14 / (I 0.02 - 1) 12.50 2.70 1.17 0.52
• Type B - Very Inverse, for which equation is: 13.00 2.66 1.13 0.48 Time to Trip = 13.5 / (I-1) 13.50 2.62 1.08 0.44 • Type C - Extremely Inverse, for which equation is: Time to Trip = 80 / (I2 - 1) 14.00 2.58 1.04 0.41
Tables for the times to trip for each of these curves are 14.50 2.55 1.00 0.38 given below. 15.00 2.52 0.96 0.36 Setting Inverse Very Extremely Current Time Inverse Inverse Time 15.50 2.48 0.93 0.33 Multiple (sec) Time (sec) (sec) 16.00 2.46 0.90 0.31 1.10 73.37 135.00 380.95 16.50 2.43 0.87 0.29 1.50 17.19 27.00 64.00 17.00 2.40 0.84 0.28 2.00 10.03 13.50 26.67 17.50 2.38 0.82 0.26 2.50 7.57 9.00 15.24 18.00 2.35 0.79 0.25 3.00 6.30 6.75 10.00 18.50 2.33 0.77 0.23 3.50 5.52 5.40 7.11 19.00 2.31 0.75 0.22 4.00 4.98 4.50 5.33 19.50 2.29 0.73 0.21 4.50 4.58 3.86 4.16 20.00 2.27 0.71 0.20 5.00 4.28 3.38 3.33 20.50 2.24 0.69 0.19 5.50 4.04 3.00 2.74 21.00 2.23 0.68 0.18 6.00 3.84 2.70 2.29 21.50 2.21 0.66 0.17 6.50 3.67 2.45 1.94 22.00 2.20 0.64 0.17 7.00 3.53 2.25 1.67 22.50 2.18 0.63 0.16 7.50 3.40 2.08 1.45 23.00 2.16 0.61 0.15 8.00 3.30 1.93 1.27 23.50 2.15 0.60 0.15 8.50 3.20 1.80 1.12 24.00 2.13 0.59 0.14 9.00 3.12 1.69 1.00 24.50 2.12 0.57 0.13 9.50 3.04 1.59 0.90 25.00 2.11 0.56 0.13 10.00 2.97 1.50 0.81 25.50 2.09 0.55 0.12 10.50 2.91 1.42 0.73 26.00 2.08 0.54 0.12 11.00 2.85 1.35 0.67 26.50 2.07 0.53 0.11 11.50 2.80 1.29 0.61 27.00 2.05 0.52 0.11
Siemens Power Transmission & Distribution, Inc. 75 Appendix A IEC255 Inverse Time Protection Tables
Setting Inverse Very Extremely Current Time Inverse Inverse Time Multiple (sec) Time (sec) (sec)
27.50 2.04 0.51 0.11
28.00 2.03 0.50 0.10
28.50 2.02 0.49 0.10
29.00 2.01 0.48 0.10
29.50 2.00 0.47 0.09
30.00 1.99 0.47 0.09
76 Siemens Power Transmission & Distribution, Inc. Appendix B IEEE Inverse Time Protection Tables B IEEE Inverse Time Protection Tables The Inverse Time Protection Curves in this appendix are Setting Std Std Very Std as defined by IEEE Std C37.112-1996 standard where “I” Current Moderately Inverse Extremely is the actual current expressed as a multiple of the trip Multiple Inverse Time Inverse current set by the user: Time (sec) (sec) Time (sec)
• Std Moderately Inverse, for which equation is: 11.50 1.14 0.64 0.34 Time to Trip = (0.0515 / (I 0.02 - 1)) + 0.114 12.00 1.12 0.63 0.32 • Std Very Inverse, for which equation is: Time to Trip = (19.61 / (I2 - 1)) + 0.491 12.50 1.11 0.62 0.30
• Std Extremely Inverse, for which equation is: 13.00 1.09 0.61 0.29 Time to Trip = (28.2 / (I2 - 1)) + 0.1217 13.50 1.08 0.60 0.28 Tables for the times to trip for each of these curves are given below. 14.00 1.06 0.59 0.27
14.50 1.05 0.58 0.26
Setting Std Std Very Std 15.00 1.04 0.58 0.25 Current Moderately Inverse Extremely Multiple Inverse Time Inverse 15.50 1.03 0.57 0.24 Time (sec) (sec) Time (sec) 16.00 1.02 0.57 0.23 1.10 27.11 93.87 134.41 16.50 1.01 0.56 0.23 1.50 6.44 16.18 22.68 17.00 1.00 0.56 0.22 2.00 3.80 7.03 9.52 17.50 0.99 0.56 0.21 2.50 2.90 4.23 5.49 18.00 0.98 0.55 0.21 3.00 2.43 2.94 3.65 18.50 0.97 0.55 0.20 3.50 2.14 2.23 2.63 19.00 0.96 0.55 0.20 4.00 1.95 1.80 2.00 19.50 0.96 0.54 0.20 4.50 1.80 1.51 1.59 20.00 0.95 0.54 0.19 5.00 1.69 1.31 1.30 20.50 0.94 0.54 0.19 5.50 1.60 1.16 1.09 21.00 0.93 0.54 0.19 6.00 1.53 1.05 0.93 21.50 0.93 0.53 0.18 6.50 1.46 0.97 0.81 22.00 0.92 0.53 0.18 7.00 1.41 0.90 0.71 22.50 0.92 0.53 0.18 7.50 1.37 0.85 0.63 23.00 0.91 0.53 0.18 8.00 1.33 0.80 0.57 23.50 0.90 0.53 0.17 8.50 1.29 0.77 0.52 24.00 0.90 0.53 0.17 9.00 1.26 0.74 0.47 24.50 0.89 0.52 0.17 9.50 1.23 0.71 0.44 25.00 0.89 0.52 0.17 10.00 1.21 0.69 0.41 25.50 0.88 0.52 0.17 10.50 1.18 0.67 0.38 26.00 0.88 0.52 0.16 11.00 1.16 0.65 0.36
Siemens Power Transmission & Distribution, Inc. 77 Appendix B IEEE Inverse Time Protection Tables
Setting Std Std Very Std Current Moderately Inverse Extremely Multiple Inverse Time Inverse Time (sec) (sec) Time (sec)
26.50 0.87 0.52 0.16
27.00 0.87 0.52 0.16
27.50 0.87 0.52 0.16
28.00 0.86 0.52 0.16
28.50 0.86 0.52 0.16
29.00 0.85 0.51 0.16
29.50 0.85 0.51 0.15
30.00 0.85 0.51 0.15
78 Siemens Power Transmission & Distribution, Inc. Appendix C TCC Cross Reference Table C TCC Cross Reference Table There are 42 Recloser Time Current Curves (TCCs) Centurion Typical Typical available and resident on the MJ-R Control of the TCC TCC1 TCC2 Centurion Recloser that approximate TCCs commonly available in the industry today. On the MJ-R Control, 27 RTCC 137 137 V these TCCs are menu selectable either by front panel programming or by programming using a PC. The 28 RTCC 138 138 W following table cross-references these TCCs. 29 RTCC 139 139 16
30 RTCC 140 140 3 Centurion Typical Typical TCC TCC1 TCC2 31 RTCC 141 141 11
1 RTCC 010* N/A N/A 32 RTCC 142 142 13
2 RTCC 101 101 A 33 RTCC 151 151 18
3 RTCC 102 102 1 34 RTCC 152 152 7
4 RTCC 103 103 17 35 RTCC 161 161 T
5 RTCC 104 104 N 36 RTCC 162 162 K-Ph
6 RTCC 105 105 R 37 RTCC 163 163 F
7 RTCC 106 106 4 38 RTCC 164 164 J
8 RTCC 107 107 L 39 RTCC 165 165 K-Gnd
9 RTCC 111 111 8-Special 40 RTCC 200 200 N/A
10 RTCC 112 112 15 41 RTCC 201 201 N/A
11 RTCC 113 113 8 42 RTCC 202 202 N/A
12 RTCC 114 114 5 Definite Time -- --
13 RTCC 115 115 P Instantaneous -- -- Tr i p 14 RTCC 116 116 D
15 RTCC 117 117 B * New “Fast” TCC to approximate typical hydraulic “A” curves. •TCC1 = microprocessor control type 16 RTCC 118 118 M •TCC2 = electronic control type 17 RTCC 119 119 14
18 RTCC 120 120 Y
19 RTCC 121 121 G
20 RTCC 122 122 H
21 RTCC 131 131 9
22 RTCC 132 132 E
23 RTCC 133 133 C
24 RTCC 134 134 Z
25 RTCC 135 135 2
26 RTCC 136 136 6
Siemens Power Transmission & Distribution, Inc. 79 Appendix C TCC Cross Reference Table
80 Siemens Power Transmission & Distribution, Inc. Appendix D Recloser Inverse Time TCCs D Recloser Inverse Time TCCs The 42 Inverse Time protection curves in this appendix represent typical Recloser electronic or microprocessor control TCCs as defined in Appemdix C. Tables for the times to trip for each of these curves are given below.
Setting TCC TCC TCC TCC TCC TCC TCC TCC TCC Multiple 010 101 102 103 104 105 106 107 111 Current
1.10 0.145 0.100 0.214 0.301 0.445 0.705 1.015 1.218 2.589
1.50 0.100 0.036 0.065 0.128 0.252 0.351 0.396 0.597 1.121
2.00 0.080 0.022 0.028 0.075 0.155 0.232 0.203 0.291 0.651
2.50 0.069 0.019 0.022 0.052 0.107 0.171 0.117 0.159 0.443
3.00 0.060 0.017 0.019 0.040 0.067 0.137 0.073 0.095 0.325
3.50 0.056 0.016 0.017 0.033 0.040 0.113 0.046 0.055 0.250
4.00 0.053 0.016 0.016 0.029 0.028 0.097 0.030 0.034 0.201
4.50 0.050 0.015 0.016 0.025 0.022 0.085 0.022 0.024 0.169
5.00 0.048 0.015 0.016 0.022 0.019 0.076 0.019 0.020 0.146
5.50 0.046 0.015 0.016 0.020 0.017 0.068 0.016 0.017 0.127
6.00 0.045 0.015 0.016 0.019 0.016 0.059 0.015 0.016 0.113
6.50 0.044 0.015 0.016 0.018 0.015 0.053 0.013 0.015 0.101
7.00 0.043 0.015 0.016 0.017 0.014 0.048 0.013 0.014 0.091
7.50 0.042 0.015 0.016 0.016 0.013 0.043 0.012 0.013 0.083
8.00 0.041 0.015 0.016 0.016 0.012 0.038 0.011 0.013 0.076
8.50 0.041 0.015 0.016 0.015 0.012 0.033 0.011 0.013 0.069
9.00 0.040 0.015 0.016 0.015 0.011 0.030 0.011 0.012 0.063
9.50 0.040 0.015 0.016 0.015 0.011 0.027 0.011 0.012 0.057
10.00 0.039 0.015 0.016 0.015 0.011 0.025 0.011 0.012 0.053
10.50 0.039 0.015 0.016 0.014 0.011 0.024 0.011 0.012 0.049
11.00 0.039 0.015 0.016 0.014 0.011 0.022 0.011 0.011 0.045
11.50 0.039 0.015 0.016 0.014 0.011 0.021 0.011 0.011 0.041
12.00 0.038 0.015 0.016 0.014 0.011 0.020 0.011 0.011 0.038
12.50 0.038 0.015 0.016 0.014 0.011 0.019 0.011 0.011 0.036
13.00 0.038 0.015 0.016 0.014 0.011 0.018 0.011 0.011 0.033
13.50 0.037 0.015 0.016 0.014 0.011 0.017 0.011 0.011 0.031
14.00 0.037 0.015 0.016 0.014 0.011 0.016 0.011 0.011 0.030
14.50 0.037 0.015 0.016 0.014 0.011 0.016 0.011 0.011 0.029
Siemens Power Transmission & Distribution, Inc. 81 Appendix D Recloser Inverse Time TCCs
Setting TCC TCC TCC TCC TCC TCC TCC TCC TCC Multiple 010 101 102 103 104 105 106 107 111 Current
15.00 0.037 0.015 0.016 0.014 0.011 0.015 0.011 0.011 0.027
15.50 0.037 0.015 0.016 0.014 0.011 0.015 0.011 0.011 0.026
16.00 0.036 0.015 0.016 0.014 0.011 0.014 0.011 0.011 0.025
16.50 0.036 0.015 0.016 0.014 0.011 0.014 0.011 0.011 0.024
17.00 0.036 0.015 0.016 0.014 0.011 0.014 0.011 0.011 0.023
17.50 0.036 0.015 0.016 0.014 0.011 0.014 0.011 0.011 0.023
18.00 0.035 0.015 0.016 0.014 0.011 0.013 0.011 0.011 0.022
18.50 0.035 0.015 0.016 0.014 0.011 0.013 0.011 0.011 0.022
19.00 0.035 0.015 0.016 0.014 0.011 0.013 0.011 0.011 0.021
19.50 0.035 0.015 0.016 0.014 0.011 0.013 0.011 0.011 0.021
20.00 0.035 0.015 0.016 0.014 0.011 0.012 0.011 0.011 0.020
20.50 0.035 0.015 0.016 0.014 0.011 0.012 0.011 0.011 0.020
21.00 0.035 0.015 0.016 0.014 0.011 0.012 0.011 0.011 0.019
21.50 0.035 0.015 0.016 0.014 0.011 0.012 0.011 0.011 0.019
22.00 0.035 0.015 0.016 0.014 0.011 0.012 0.011 0.011 0.019
22.50 0.035 0.015 0.016 0.014 0.011 0.012 0.011 0.011 0.018
23.00 0.035 0.015 0.016 0.014 0.011 0.012 0.011 0.011 0.018
23.50 0.035 0.015 0.016 0.014 0.011 0.012 0.011 0.011 0.018
24.00 0.035 0.015 0.016 0.014 0.011 0.012 0.011 0.011 0.017
24.50 0.035 0.015 0.016 0.014 0.011 0.012 0.011 0.011 0.017
25.00 0.035 0.015 0.016 0.014 0.011 0.012 0.011 0.011 0.017
25.50 0.035 0.015 0.016 0.014 0.011 0.011 0.011 0.011 0.017
26.00 0.035 0.015 0.016 0.014 0.011 0.011 0.011 0.011 0.016
26.50 0.035 0.015 0.016 0.014 0.011 0.011 0.011 0.011 0.016
27.00 0.035 0.015 0.016 0.014 0.011 0.011 0.011 0.011 0.016
27.50 0.035 0.015 0.016 0.014 0.011 0.011 0.011 0.011 0.016
28.00 0.035 0.015 0.016 0.014 0.011 0.011 0.011 0.011 0.016
28.50 0.035 0.015 0.016 0.014 0.011 0.011 0.011 0.011 0.016
29.00 0.035 0.015 0.016 0.014 0.011 0.011 0.011 0.011 0.016
29.50 0.035 0.015 0.016 0.014 0.011 0.011 0.011 0.011 0.016
30.00 0.035 0.015 0.016 0.014 0.011 0.011 0.011 0.011 0.016
82 Siemens Power Transmission & Distribution, Inc. Appendix D Recloser Inverse Time TCCs
Setting TCC TCC TCC TCC TCC TCC TCC TCC TCC Multiple 112 113 114 115 116 117 118 119 120 Current
1.10 2.415 2.954 6.054 4.692 5.752 5.396 6.949 6.401 9.354
1.50 1.024 1.264 2.376 1.792 2.301 2.291 2.511 2.505 3.755
2.00 0.563 0.704 1.398 0.726 1.216 1.396 1.248 1.518 2.013
2.50 0.356 0.467 0.952 0.374 0.748 0.920 0.754 1.145 1.302
3.00 0.257 0.358 0.699 0.219 0.499 0.649 0.523 0.940 0.925
3.50 0.198 0.293 0.532 0.141 0.351 0.489 0.384 0.809 0.696
4.00 0.158 0.259 0.420 0.096 0.259 0.391 0.295 0.716 0.549
4.50 0.132 0.233 0.334 0.067 0.200 0.321 0.234 0.652 0.462
5.00 0.113 0.215 0.261 0.049 0.159 0.270 0.193 0.602 0.398
5.50 0.099 0.203 0.206 0.038 0.129 0.231 0.162 0.572 0.348
6.00 0.088 0.196 0.164 0.030 0.107 0.200 0.139 0.549 0.311
6.50 0.079 0.189 0.127 0.025 0.090 0.176 0.121 0.529 0.281
7.00 0.073 0.185 0.098 0.021 0.078 0.156 0.107 0.512 0.257
7.50 0.068 0.182 0.076 0.019 0.068 0.140 0.096 0.499 0.236
8.00 0.063 0.180 0.053 0.018 0.060 0.126 0.087 0.487 0.220
8.50 0.059 0.179 0.038 0.017 0.053 0.115 0.078 0.477 0.207
9.00 0.056 0.177 0.032 0.016 0.048 0.105 0.071 0.468 0.195
9.50 0.053 0.176 0.028 0.015 0.043 0.097 0.066 0.461 0.185
10.00 0.050 0.175 0.025 0.014 0.039 0.089 0.060 0.455 0.175
10.50 0.048 0.174 0.024 0.014 0.036 0.083 0.056 0.452 0.167
11.00 0.046 0.174 0.022 0.014 0.034 0.078 0.051 0.448 0.161
11.50 0.044 0.173 0.021 0.014 0.031 0.073 0.048 0.445 0.155
12.00 0.043 0.172 0.020 0.014 0.029 0.068 0.045 0.441 0.150
12.50 0.041 0.172 0.019 0.014 0.027 0.064 0.042 0.439 0.145
13.00 0.040 0.172 0.018 0.014 0.026 0.059 0.040 0.436 0.141
13.50 0.039 0.171 0.018 0.014 0.024 0.055 0.037 0.434 0.137
14.00 0.038 0.171 0.017 0.014 0.023 0.052 0.035 0.432 0.134
14.50 0.037 0.171 0.017 0.014 0.022 0.048 0.034 0.431 0.130
15.00 0.036 0.170 0.016 0.014 0.020 0.044 0.032 0.429 0.128
15.50 0.035 0.170 0.016 0.014 0.019 0.041 0.031 0.429 0.126
Siemens Power Transmission & Distribution, Inc. 83 Appendix D Recloser Inverse Time TCCs
Setting TCC TCC TCC TCC TCC TCC TCC TCC TCC Multiple 112 113 114 115 116 117 118 119 120 Current
16.00 0.034 0.170 0.016 0.014 0.019 0.039 0.030 0.428 0.124
16.50 0.033 0.170 0.015 0.014 0.018 0.037 0.029 0.427 0.122
17.00 0.032 0.169 0.015 0.014 0.017 0.035 0.028 0.427 0.121
17.50 0.032 0.169 0.015 0.014 0.016 0.033 0.026 0.426 0.119
18.00 0.031 0.169 0.014 0.014 0.016 0.031 0.025 0.426 0.117
18.50 0.031 0.169 0.014 0.014 0.015 0.030 0.025 0.425 0.115
19.00 0.030 0.168 0.014 0.014 0.015 0.029 0.024 0.425 0.114
19.50 0.030 0.168 0.014 0.014 0.014 0.028 0.023 0.424 0.113
20.00 0.029 0.168 0.014 0.014 0.014 0.027 0.022 0.424 0.111
20.50 0.029 0.168 0.014 0.014 0.014 0.026 0.022 0.423 0.110
21.00 0.028 0.167 0.013 0.014 0.013 0.026 0.021 0.423 0.109
21.50 0.028 0.167 0.013 0.014 0.013 0.025 0.020 0.422 0.108
22.00 0.028 0.167 0.013 0.014 0.013 0.025 0.020 0.422 0.106
22.50 0.027 0.167 0.013 0.014 0.013 0.024 0.019 0.422 0.105
23.00 0.027 0.167 0.013 0.014 0.012 0.024 0.019 0.421 0.104
23.50 0.027 0.166 0.013 0.014 0.012 0.023 0.019 0.421 0.103
24.00 0.026 0.166 0.013 0.014 0.012 0.023 0.018 0.421 0.102
24.50 0.026 0.166 0.013 0.014 0.012 0.023 0.018 0.421 0.102
25.00 0.026 0.166 0.012 0.014 0.012 0.022 0.018 0.421 0.101
25.50 0.026 0.166 0.012 0.014 0.012 0.022 0.017 0.421 0.100
26.00 0.026 0.166 0.012 0.014 0.012 0.021 0.017 0.421 0.099
26.50 0.025 0.166 0.012 0.014 0.011 0.021 0.017 0.421 0.098
27.00 0.025 0.166 0.012 0.014 0.011 0.021 0.017 0.421 0.098
27.50 0.025 0.166 0.012 0.014 0.011 0.020 0.016 0.421 0.097
28.00 0.025 0.166 0.012 0.014 0.011 0.020 0.016 0.421 0.096
28.50 0.025 0.166 0.012 0.014 0.011 0.020 0.016 0.421 0.096
29.00 0.025 0.166 0.012 0.014 0.011 0.020 0.016 0.421 0.095
29.50 0.025 0.166 0.012 0.014 0.011 0.020 0.016 0.421 0.095
30.00 0.025 0.166 0.012 0.014 0.011 0.020 0.016 0.421 0.095
84 Siemens Power Transmission & Distribution, Inc. Appendix D Recloser Inverse Time TCCs
Setting TCC TCC TCC TCC TCC TCC TCC TCC TCC Multiple 121 122 131 132 133 134 135 136 137 Current
1.10 8.877 8.219 10.610 13.732 13.716 11.367 13.660 15.655 19.198
1.50 1.145 4.430 8.306 4.460 5.602 4.790 6.369 4.658 10.162
2.00 0.019 2.616 7.106 2.586 3.020 2.387 3.677 2.781 6.495
2.50 0.014 1.689 6425 1.571 1.920 1.507 2.566 1.884 4.756
3.00 0.012 1.102 6.101 1.002 1.329 1.079 1.969 1.339 3.667
3.50 0.011 0.653 5.901 0.722 0.973 0.847 1.616 1.024 2.933
4.00 0.011 0.347 5.730 0.552 0.754 0.698 1.367 0.833 2.416
4.50 0.011 0.114 5.624 0.438 0.613 0.617 1.197 0.686 2.006
5.00 0.011 0.037 5.537 0.353 0.511 0.553 1.072 0.550 1.694
5.50 0.011 0.022 5.460 0.287 0.432 0.508 0.974 0.448 1.464
6.00 0.011 0.019 5.398 0.236 0.371 0.484 0.900 0.367 1.287
6.50 0.011 0.017 5.359 0.198 0.323 0.463 0.849 0.304 1.155
7.00 0.011 0.016 5.334 0.169 0.284 0.446 0.805 0.252 1.062
7.50 0.011 0.015 5.312 0.146 0.253 0.436 0.767 0.210 0.990
8.00 0.011 0.014 5.290 0.127 0.227 0.432 0.735 0.172 0.928
8.50 0.011 0.013 5.269 0.110 0.205 0.427 0.711 0.142 0.873
9.00 0.011 0.013 5.251 0.097 0.186 0.423 0.689 0.116 0.824
9.50 0.011 0.012 5.233 0.086 0.170 0.419 0.670 0.087 0.786
10.00 0.011 0.012 5.216 0.077 0.157 0.416 0.651 0.064 0.753
10.50 0.011 0.012 5.210 0.070 0.146 0.415 0.635 0.049 0.730
11.00 0.011 0.011 5.208 0.064 0.137 0.415 0.619 0.038 0.714
11.50 0.011 0.011 5.208 0.058 0.128 0.415 0.607 0.032 0.699
12.00 0.011 0.011 5.208 0.053 0.121 0.415 0.599 0.029 0.685
12.50 0.011 0.011 5.208 0.049 0.115 0.415 0.591 0.026 0.671
13.00 0.011 0.011 5.208 0.046 0.109 0.415 0.584 0.024 0.662
13.50 0.011 0.011 5.208 0.043 0.103 0.415 0.577 0.022 0.653
14.00 0.011 0.011 5.208 0.040 0.098 0.415 0.571 0.021 0.645
14.50 0.011 0.011 5.207 0.037 0.093 0.415 0.566 0.020 0.640
15.00 0.011 0.011 5.207 0.035 0.089 0.415 0.561 0.019 0.635
15.50 0.011 0.011 5.207 0.033 0.085 0.415 0.556 0.018 0.629
Siemens Power Transmission & Distribution, Inc. 85 Appendix D Recloser Inverse Time TCCs
Setting TCC TCC TCC TCC TCC TCC TCC TCC TCC Multiple 121 122 131 132 133 134 135 136 137 Current
16.00 0.011 0.011 5.207 0.032 0.082 0.415 0.553 0.017 0.626
16.50 0.011 0.011 5.207 0.030 0.078 0.415 0.551 0.017 0.622
17.00 0.011 0.011 5.207 0.029 0.076 0.415 0.549 0.017 0.619
17.50 0.011 0.011 5.207 0.027 0.074 0.415 0.548 0.016 0.616
18.00 0.011 0.011 5.207 0.026 0.072 0.415 0.546 0.016 0.614
18.50 0.011 0.011 5.207 0.025 0.070 0.415 0.544 0.015 0.612
19.00 0.011 0.011 5.207 0.023 0.068 0.415 0.543 0.015 0.610
19.50 0.011 0.011 5.207 0.023 0.066 0.415 0.541 0.015 0.608
20.00 0.011 0.011 5.207 0.022 0.065 0.415 0.539 0.015 0.606
20.50 0.011 0.011 5.207 0.022 0.063 0.415 0.538 0.015 0.605
21.00 0.011 0.011 5.207 0.021 0.061 0.415 0.537 0.015 0.603
21.50 0.011 0.011 5.207 0.021 0.060 0.415 0.535 0.015 0.602
22.00 0.011 0.011 5.207 0.020 0.058 0.415 0.534 0.015 0.602
22.50 0.011 0.011 5.207 0.020 0.057 0.415 0.533 0.015 0.602
23.00 0.011 0.011 5.207 0.019 0.056 0.415 0.531 0.015 0.602
23.50 0.011 0.011 5.207 0.019 0.054 0.415 0.530 0.015 0.602
24.00 0.011 0.011 5.207 0.018 0.054 0.415 0.529 0.015 0.602
24.50 0.011 0.011 5.207 0.018 0.053 0.415 0.528 0.015 0.602
25.00 0.011 0.011 5.207 0.018 0.052 0.415 0.528 0.015 0.602
25.50 0.011 0.011 5.207 0.018 0.051 0.415 0.528 0.015 0.602
26.00 0.011 0.011 5.207 0.017 0.051 0.415 0.528 0.015 0.602
26.50 0.011 0.011 5.207 0.017 0.050 0.415 0.528 0.015 0.602
27.00 0.011 0.011 5.207 0.017 0.049 0.415 0.528 0.015 0.602
27.50 0.011 0.011 5.207 0.017 0.049 0.415 0.528 0.015 0.602
28.00 0.011 0.011 5.207 0.017 0.048 0.415 0.528 0.015 0.602
28.50 0.011 0.011 5.207 0.017 0.047 0.415 0.528 0.015 0.602
29.00 0.011 0.011 5.207 0.017 0.047 0.415 0.528 0.015 0.602
29.50 0.011 0.011 5.207 0.017 0.046 0.415 0.528 0.015 0.602
30.00 0.011 0.011 5.207 0.017 0.046 0.415 0.528 0.015 0.602
86 Siemens Power Transmission & Distribution, Inc. Appendix D Recloser Inverse Time TCCs
Setting TCC TCC TCC TCC TCC TCC TCC TCC TCC Multiple 138 139 140 141 142 151 152 161 162 Current
1.10 20.647 15.250 25.082 19.763 36.299 38.923 72.701 19.879 27.549
1.50 9.741 5.097 10.141 15.227 16.543 11.551 45.263 3.860 8.109
2.00 5.905 2.889 5.802 13.159 9.181 5.848 39.251 1.688 3.793
2.50 4.115 1.943 4.122 12.159 5.868 3.688 36.458 1.002 2.331
3.00 3.117 1.446 3.254 11.511 3.711 2.545 35.035 0.686 1.570
3.50 2.493 1.139 2.708 11.095 2.372 1.888 33.905 0.494 1.117
4.00 1.949 0.929 2.323 10.860 1.507 1.489 32.987 0.371 0.819
4.50 1.583 0.776 2.057 10.655 1.101 1.244 32.235 0.299 0.615
5.00 1.299 0.661 1.857 10.486 0.849 1.068 31.587 0.248 0.486
5.50 1.085 0.564 1.695 10.419 0.701 0.973 31.014 0.209 0.394
6.00 0.925 0.486 1.590 10.383 0.595 0.894 30.568 0.180 0.325
6.50 0.802 0.423 1.506 10.351 0.511 0.828 30.234 0.158 0.274
7.00 0.703 0.373 1.434 10.321 0.445 0.773 29.955 0.140 0.235
7.50 0.625 0.332 1.372 10.293 0.391 0.728 29.690 0.126 0.206
8.00 0.561 0.297 1.315 10.267 0.346 0.687 29.441 0.114 0.182
8.50 0.508 0.268 1.268 10.243 0.310 0.652 29.226 0.105 0.162
9.00 0.462 0.242 1.226 10.220 0.279 0.622 29.021 0.097 0.145
9.50 0.422 0.221 1.197 10.199 0.253 0.600 28.880 0.091 0.130
10.00 0.388 0.202 1.168 10.180 0.231 0.579 28.768 0.085 0.117
10.50 0.360 0.185 1.144 10.175 0.211 0.565 28.661 0.079 0.106
11.00 0.337 0.171 1.119 10.175 0.194 0.551 28.564 0.075 0.097
11.50 0.315 0.158 1.098 10.175 0.179 0.539 28.463 0.071 0.089
12.00 0.297 0.146 1.079 10.175 0.166 0.529 28.376 0.067 0.082
12.50 0.280 0.135 1.060 10.175 0.154 0.518 28.290 0.064 0.076
13.00 0.265 0.126 1.053 10.175 0.144 0.514 28.201 0.061 0.071
13.50 0.253 0.117 1.046 10.175 0.132 0.509 28.135 0.059 0.067
14.00 0.242 0.110 1.038 10.175 0.121 0.504 28.068 0.057 0.063
14.50 0.232 0.103 1.032 10.175 0.112 0.499 27.998 0.054 0.060
15.00 0.224 0.096 1.026 10.175 0.103 0.495 27.971 0.052 0.056
15.50 0.216 0.090 1.020 10.175 0.095 0.491 27.955 0.051 0.053
Siemens Power Transmission & Distribution, Inc. 87 Appendix D Recloser Inverse Time TCCs
Setting TCC TCC TCC TCC TCC TCC TCC TCC TCC Multiple 138 139 140 141 142 151 152 161 162 Current
16.00 0.208 0.085 1.014 10.175 0.088 0.487 27.939 0.049 0.050
16.50 0.201 0.080 1.009 10.175 0.081 0.485 27.924 0.047 0.048
17.00 0.195 0.074 1.003 10.175 0.076 0.482 27.910 0.046 0.045
17.50 0.190 0.070 0.998 10.175 0.070 0.479 27.897 0.045 0.042
18.00 0.184 0.065 0.996 10.175 0.066 0.477 27.883 0.043 0.040
18.50 0.197 0.062 0.995 10.175 0.062 0.475 27.869 0.043 0.038
19.00 0.175 0.058 0.994 10.175 0.059 0.472 27.857 0.042 0.036
19.50 0.171 0.055 0.993 10.175 0.056 0.470 27.845 0.041 0.034
20.00 0.168 0.051 0.992 10.175 0.053 0.469 27.833 0.040 0.033
20.50 0.154 0.049 0.991 10.175 0.050 0.468 27.821 0.040 0.031
21.00 0.161 0.046 0.990 10.175 0.048 0.468 27.809 0.039 0.030
21.50 0.158 0.043 0.990 10.175 0.046 0.468 27.799 0.038 0.029
22.00 0.155 0.041 0.989 10.175 0.045 0.467 27.788 0.038 0.028
22.50 0.152 0.039 0.988 10.175 0.043 0.467 27.777 0.037 0.027
23.00 0.149 0.037 0.988 10.175 0.042 0.467 27.766 0.036 0.026
23.50 0.146 0.035 0.987 10.175 0.040 0.467 27.757 0.036 0.026
24.00 0.144 0.033 0.986 10.175 0.039 0.466 27.751 0.035 0.025
24.50 0.142 0.031 0.986 10.175 0.038 0.466 27.746 0.035 0.024
25.00 0.140 0.030 0.985 10.175 0.037 0.466 27.740 0.034 0.024
25.50 0.137 0.028 0.985 10.175 0.037 0.466 27.735 0.033 0.023
26.00 0.135 0.027 0.985 10.175 0.036 0.465 27.729 0.033 0.023
26.50 0.134 0.026 0.985 10.175 0.035 0.465 27.725 0.033 0.022
27.00 0.133 0.025 0.984 10.175 0.034 0.465 27.722 0.032 0.022
27.50 0.132 0.024 0.984 10.175 0.034 0.464 27.720 0.032 0.021
28.00 0.131 0.023 0.984 10.175 0.033 0.464 27.717 0.031 0.021
28.50 0.131 0.022 0.984 10.175 0.033 0.464 27.714 0.031 0.020
29.00 0.130 0.022 0.984 10.175 0.032 0.464 27.711 0.031 0.020
29.50 0.129 0.021 0.984 10.175 0.032 0.464 27.709 0.031 0.020
30.00 0.129 0.021 0.984 10.175 0.032 0.464 27.709 0.031 0.020
88 Siemens Power Transmission & Distribution, Inc. Appendix D Recloser Inverse Time TCCs
Setting TCC TCC TCC TCC TCC TCC Multiple 163 164 165 200 201 202 Current
1.10 33.228 53.091 84.512 74.687 122.30 125.06
1.50 3.747 18.503 31.451 17.354 27.161 64.047
2.00 1.356 7.916 12.916 10.039 13.506 26.654
2.50 0.720 4.318 5.994 7.583 9.012 15.234
3.00 0.482 2.596 3.199 6.323 6.770 10.004
3.50 0.356 1.715 2.051 5.530 5.410 7.109
4.00 0.276 1.162 1.463 4.985 4.505 5.335
4.50 0.222 0.787 1.102 4.588 3.860 4.154
5.00 0.187 0.556 0.866 4.286 3.380 3.333
5.50 0.161 0.420 0.714 4.044 3.006 2.735
6.00 0.140 0.333 0.602 3.844 2.705 2.286
6.50 0.123 0.272 0.515 3.671 2.456 1.940
7.00 0.109 0.228 0.450 3.533 2.254 1.667
7.50 0.097 0.197 0.397 3.409 2.081 1.448
8.00 0.087 0.174 0.352 3.300 1.931 1.270
8.50 0.078 0.155 0.317 3.206 1.804 1.123
9.00 0.070 0.140 0.287 3.119 1.690 1.000
9.50 0.064 0.127 0.262 3.044 1.591 0.897
10.00 0.058 0.116 0.240 2.974 1.502 0.808
10.50 0.054 0.106 0.221 2.910 1.422 0.732
11.00 0.049 0.098 0.205 2.854 1.353 0.667
11.50 0.046 0.090 0.190 2.797 1.286 0.610
12.00 0.042 0.085 0.178 2.751 1.229 0.560
12.50 0.040 0.080 0.166 2.705 1.176 0.516
13.00 0.037 0.075 0.156 2.660 1.125 0.476
13.50 0.035 0.071 0.145 2.623 1.082 0.441
14.00 0.033 0.068 0.135 2.586 1.040 0.410
14.50 0.031 0.065 0.126 2.549 1.001 0.382
15.00 0.030 0.062 0.117 2.518 0.966 0.357
Siemens Power Transmission & Distribution, Inc. 89 Appendix D Recloser Inverse Time TCCs
Setting TCC TCC TCC TCC TCC TCC Multiple 163 164 165 200 201 202 Current
15.50 0.028 0.059 0.110 2.488 0.933 0.335
16.00 0.027 0.057 0.103 2.458 0.901 0.314
16.50 0.026 0.055 0.096 2.429 0.871 0.295
17.00 0.025 0.053 0.091 2.404 0.845 0.278
17.50 0.023 0.051 0.086 2.380 0.820 0.262
18.00 0.022 0.049 0.081 2.355 0.795 0.248
18.50 0.022 0.048 0.077 2.330 0.772 0.234
19.00 0.021 0.047 0.072 2.310 0.751 0.222
19.50 0.020 0.045 0.069 2.290 0.731 0.211
20.00 0.019 0.044 0.065 2.270 0.712 0.200
20.50 0.019 0.043 0.062 2.249 0.693 0.191
21.00 0.018 0.042 0.059 2.231 0.676 0.182
21.50 0.018 0.040 0.057 2.214 0.660 0.173
22.00 0.018 0.039 0.055 2.198 0.644 0.166
22.50 0.017 0.038 0.053 2.181 0.629 0.159
23.00 0.017 0.037 0.051 2.164 0.614 0.152
23.50 0.017 0.036 0.049 2.149 0.601 0.145
24.00 0.017 0.036 0.047 2.135 0.588 0.139
24.50 0.016 0.035 0.046 2.122 0.576 0.134
25.00 0.016 0.034 0.044 2.108 0.564 0.129
25.50 0.016 0.033 0.043 2.094 0.552 0.124
26.00 0.016 0.033 0.042 2.080 0.541 0.119
26.50 0.015 0.032 0.041 2.068 0.530 0.114
27.00 0.015 0.031 0.040 2.056 0.520 0.110
27.50 0.015 0.031 0.040 2.045 0.510 0.106
28.00 0.014 0.030 0.039 2.034 0.501 0.103
28.50 0.014 0.030 0.039 2.022 0.492 0.099
29.00 0.014 0.029 0.038 2.011 0.482 0.096
29.50 0.014 0.029 0.038 2.001 0.475 0.093
30.00 0.014 0.029 0.038 2.001 0.475 0.093
90 Siemens Power Transmission & Distribution, Inc. Appendix E System Status Pages E System Status Pages This appendix shows all the System Status group pages System Status 1 for the Operator Control Panel display. For more OPERATOR SETTINGS information, refer to Sections 6 through 9. The top line of the display is the page title. The next three lines are the < blank in normal Protection OFF O data on display. Most displays have six data fields. These operation> lines are shown in the tables in this section. Reclose 1 Protection Auto* O Where a display field shows a numeric value, the box Reclose 2 Auto 'A' Active* D below shows a typical value or the default value if Reclose 3 Auto 'B' Active* D applicable. For example, Reclose Time 0.5 sec is shown for the reclose time setting. The display, however, might show Reclose Time 3.0 sec for an actual setting. Display fields with pre-defined text options (e.g., SGF * Automatic Protection Group Selection is only available Protection ON or SGF Protection OFF) list each option, code version 027-00.00 or later. one below the other. The box showing the SYSTEM STATUS -1 - page below illustrates this. Here, the first System Status 2 data field is either: SWITCHGEAR STATUS Local Control ON or Remote Control ON Work Tag OFF P To the right of the data field column is a small column containing one or more letters. The letters are defined as Work Tag Applied follows: Aux Supply Normal D Battery Normal D • O - Operator Controlled Aux Supply Fail Battery OFF Aux Supply Battery Low Volts • D - Display Only (i.e., cannot be changed) Overvolt Battery Overvolt • P - Password Protected (i.e., can only be changed if the password is known) ACR Connected D ACR Data Valid D ACR Unplugged ACR Data Invalid
System Status 1 OPERATOR SETTINGS System Status 3 Local Control ON O G/F OFF, SGF OFF O LIVE/DEAD INDICATION Remote Control ON G/F ON, SGF OFF Ai Live D Ax Unavailable G/F ON, SGF ON Ai Dead The terminal voltages x, G/F ON xx, xxx are not measured G/F OFF in this model. The options appearing in Bi Live D Bx Unavailable this field will depend on Bi Dead the SGF and GF Control settings, see “9.5 Ci Live D Cx Unavailable Sensitive Ground Fault Ci Dead Control” on page 31 and “9.6 Ground Fault Note the values in Control” on page 32 the brackets (i and x) represent the Auto-Reclose OFF O Cold Load OFF O physical sides of Auto-Reclose ON Cold Load IDLE the switch. Cold Load NO CHANGE Cold Load MAX CLP 120min x2.3mult
Lockout D Prot 'A' Active O Single Shot Active Prot 'B' Active O
Siemens Power Transmission & Distribution, Inc. 91 Appendix E System Status Pages
System Status 4 System Status 8 PHASE VOLTAGE and POWER FLOW SWITCHGEAR WEAR/GENERAL DETAILS
"LIVE" if > 2000V P Supply Timeout 4.0s P I Contact 75.8% D CAPM S/N NP-101234 D Power Flow Signed P Source I, Load X P II Contact 75.9% D Firmware 024-45.00 D Power Flow Source X, Load I III Contact 73.5% D Configuration 10087 D Unsigned
Display Ph/Ph Volt P Display Ph/Gnd Volt System Status 9 PROTECTION OPTIONS
SGF Available P Prot OFF Allowed P System Status 5 SGF Not Available Prot OFF Not Allowed SWITCHGEAR TERMINAL DESIGNATION P G/F OFF Allowed P I /X Terminals A Phase P G/F OFF Not Allowed Note the phase designations can be Auto Allowed* Auto Change Time 60s* P rotated from this field by Auto Not Allowed* pressing the arrow key. (ABC, ACB, BAC, BCA, CAB, CBA) System Status 10 II /XX Terminals B Phase GENERAL III/XXX Terminals C Phase Date/Time O 08/27/1998 10:55:12 D
System Status 6 RADIO and IOEX System Status 11 CAPABILITY Radio Supply OFF O Radio Supply 12V P Radio Supply ON Centurion Recloser RCIM - 2200A D Radio Shutdown CSS P9 Local RCSW - 3200A D Note: See “12.3 CSS P8 Local RCSW - 3200A D Radio/Modem Power” on page 47 * Automatic Protection Group Selection is only available for further details. code version 027-00.00 or later Radio Hold 60 min P IOEX Local P IOEX Remote
System Status 7 SWITCHGEAR TYPE and RATINGS
Recloser D S/N NP-101005 D
12500A Interruption D Rated 12000 Volts D
630A Continuous D 1292 Operations D
92 Siemens Power Transmission & Distribution, Inc. Appendix F Protection Pages F Protection Pages This appendix shows all the Protection Group pages for the Operator Control Panel display. Protection Setting 4 (A or B)
Appendix E: System Status Pages on page 91 explains High Lockout OFF P Loss Phase Prot OFF P the format of this appendix. Refer to Section 9: Protection on page 31 for more information on protection operation. High Lockout ON Loss Phase Prot ON High Lockout P Phase Lost @ 10000V P 5000A Protection Setting 1 (A or B) Activation Trip 1 P Phase Lost 1.0s P Group A Displayed P Maximum Time OFF P Activation Trip 2 Group B Displayed Maximum Time 5 s Activation Trip 3 Phase Trip 200 P Ground Trip 40 Amp P Activation Trip 4 Amp
Phase Threshold P Ground Threshold 1.1 P 1.1 Protection Setting 5 (A or B)
Inrush OFF P Cold Load OFF P Protection Setting 2 (A or B) Inrush ON Cold Load ON
Seq Reset Time P Flt Reset Time 50ms P Inrush Time 0.10s P Cold Load Time 120m P 30s Inrush Mult x 4.0 P Cold Load Mult x 2.0 P Single Shot Trip 1 P SS Reset Time 1s P
Trips to Lockout 4 P Sequence Control OFF P Sequence Control ON PHASE PROTECTION TRIP NUMBER 1,2,3,4 (A or B)
IEC255 Curves P Time Multiplier 1.00 P Definite Time 1.00s Protection Setting 3 (A or B) Instantaneous Only SGF Trips Lockout P Live Load Block OFF P IEEE Curves Time Multiplier 1.00 1 Live Load Block ON Additional Curve Time Multiplier 1.00 Note: in order for this Selection function to work correctly, Note: See the unit must be Appendices for the programmed with the available curves. correct Power Flow direction. See Section 9: No Instantaneous P Reclose Time 1.0s P Protection on page 31 Instant Mult x 1.0 Reclose time not and Section 11: Power available on trip 4 System Measurements on page 45. Minimum 0.00s P Additional 0.00s P
SGF Trip 4 Amp P
Siemens Power Transmission & Distribution, Inc. 93 Appendix F Protection Pages
GROUND PROTECTION TRIP NUMBER 1,2,3,4 (A or B)
IEC255 Curves P Time Multiplier 1.00 P Definite Time 1.00s Instantaneous Only IEEE Curves Time Multiplier 1.00 Additional Curve Time Multiplier 1.00 Selection Note: See Appendices A, B, and C for the available curves.
No Instantaneous P SGF Definite 5.0s P Instant Mult x 1.0
Minimum 0.00s P Additional 0.00s P
94 Siemens Power Transmission & Distribution, Inc. Appendix G Replaceable Parts & Tools G Replaceable Parts & Tools All replacement parts are available from Siemens Power Listed below are the parts that may be required for Transmission & Distribution; some may be available from replacement following customer maintenance. Also listed the part manufacturer or the manufacturer's agent are special purpose tools. directly.
Part Supplier/Description Siemens Catalog Number
Batteries LCR12V7.2P 12 Volt Battery BAT8250012
Center Mounting Bracket Siemens U01-533
Centurion System Software (CSS) Siemens Refer Agent
Control and Protection Module Siemens ELCCAPM4 (CAPM-4)
Control Cable 7m long Siemens N03-602
Control Cubicle Door Seal TESA Tape DF50604/1224 NEO0910082
Control Cubicle Entry Module Siemens ELCCCEM1 (CCEM)
Control Cubicle Siemens Tropical Version PTCC-TRO Moderate Version PTCC-TRO Temperature Version PTCC-TEM
Control Cubicle Siemens NUS-620 Heater 240 VAC
Control Cubicle Siemens ELCMIS0142 Thermostat
Control Cubicle Siemens NUS-621 Heater 120 VAC
Electronics Compartment Cover Siemens N03-036 Gasket
End Mounting Bracket Siemens U01-529
Ferrite Filters (ID = 10mm) for Radio Spares MSFC-13T (only one ELCIND0030 (two req’d) incoming cables req'd)
Input Output Expander Card Siemens IOEX-1
Manual Operation Set Siemens N07-600
Operator Panel Subsystem Siemens N03-622
Parallel Groove Clamp for Siemens LUG163140 Aluminium cable 70-240 mm2 (2/0- 500 Kcm)
Substation Mounting Frame Siemens U05-500
Siemens Power Transmission & Distribution, Inc. 95 Appendix G Replaceable Parts & Tools
Part Supplier/Description Siemens Catalog Number
Switchgear Cable Entry Siemens U01-260 Compartment Cover Gasket
Switchgear Simulator Siemens DEMO-SET
Centurion System Software (CSS) Siemens Siemens
Test and Training Set (TTS) Siemens TTS1-02
96 Siemens Power Transmission & Distribution, Inc. Appendix H Standard Event Types H Standard Event Types The following table details the standard events that can appear in the Event Log.
Event Text Explanation
A/B/C i/x Dead B i/x terminal has changed from live to dead. A/B/C i/x Live B i/x terminal has changed from dead to live.
A Max NN Amp Following pickup of the Overcurrent Protection Element on A,B or C phase, the maximum fault current recorded was NN Amps. This event is logged B Max NN Amp only after the current has fallen back below the Phase Trip Current Setting. C Max NN Amp
ACR Open On power up and switch re-connection the Recloser is either open or closed. (ACR = Automatic Circuit Recloser) ACR Closed
Automatic Reclose The Recloser was automatically re-closed following a protection trip.
Aux Supply Normal The auxiliary power supply has become normal.
Aux Supply Fail The auxiliary power supply has failed.
Battery Normal The battery is in the normal range.
Battery OFF The battery is not connected.
Battery Low Volts The battery voltage is below the low battery threshold.
Close Blocking ON A user has software Enabled/Isolated the switch close operation. Close Blocking OFF
Close Coil Connect The Close/Trip solenoid isolate switch on the Operator Control Panel was changed to the Enable/Isolate position. Close Coil Isolate Trip Coil Connect Trip Coil Isolate
Current >= 5000A The Recloser tripped with a current above the High Current Lockout setting while the High Current Lockout was effective, the event shows the value of setting at the time the event occurred.
Denied Wrong Mode When the switch is in a different mode (Local, Remote or Work Tag Applied) to the device that attempted the close. Refer to Section 8: Work Tags and Control Mode on page 29.
Disconnected The switchgear has been disconnected.
G Max NN Amp Following pickup of the Overcurrent Protection Element on Ground or SGF, the maximum fault current recorded was NN Amps. This event is logged only after the current has fallen back below the ground setting current.
Ground Prot Trip A protection trip was generated by the specified Overcurrent Protection Element. Phase Prot Trip SGF Prot Trip
Live Load Blocking A close request was disregarded due to a load side terminal being alive.
Siemens Power Transmission & Distribution, Inc. 97 Appendix H Standard Event Types
Event Text Explanation
Load Supply OFF/ON All three load side voltages are off/on.
Lockout The protection went to lockout and will not perform any more automatic recloses. Refer to “9.16 Lockout” on page 38.
Loss Of Phase Prot A protection trip was generated by the Loss Of Phase Protection.
Mech Locked Recloser has been locked/unlocked using the Manual Trip Ring. Mech Unlocked
Mechanical Trip Recloser was tripped or closed using the Manual Mechanical Trip Ring. Mechanical Close
Normal Power Mode If the power supply voltage returns to normal then the power mode will return to normal after 15 min.
NP-xxxxxx Connected Recloser with serial number xxxxxx has been connected.
Phasing order The terminal phase designation has been changed where order is one of the following - ABC, ACB, BAC, BCA, CAB, CBA. Refer to “11.1 Switchgear Terminal Designation” on page 45.
Pickup One of the protection elements picked up (phase, ground or SGF). This event is generated by the first element to pick up, if more elements pick up subsequently then no more pickup events are generated until all the elements have reset. Refer to “9.8 Overcurrent Protection” on page 32.
Power Up The electronics just had power applied or had a power up reset or watchdog reset. The time displayed will be approximately the time that power down occurred plus 1 sec.
Power Down The electronics were powered down.
Protection OFF All of the protection features have been turned off. The Recloser will only perform a manual trip or close.
Protection ON Protection has been turned back on.
Prot Group A Active Protection Group A or B is active. Written to event whenever the active groups change or a trip occurs. Prot Group B Active
Protocol Reset The Electronic Controller has been reset by a protocol.
Prot Trip NN Trip NN in the reclose sequence.
Sequence Reset The sequence reset timer has expired. This causes the protection relay to reset to the start of the reclose sequence for the next fault.
Sequence Advance When sequence coordination is ON this event is generated when the sequence counter is advanced due to a downstream fault that did not cause a protection trip.
Single Shot A trip occurred while in Single Shot Mode.
Source Supply OFF/ON All three source side voltages are OFF/ON.
98 Siemens Power Transmission & Distribution, Inc. Appendix H Standard Event Types
Event Text Explanation
Source Trip Req A trip/close request was issued from the source. Where source can be one of, Panel, CSS, IOEX, Protocol, etc. Source Close Req Panel = Operator Control Panel CSS = Centurion System Software IOEX = Input Output Expander Card Protocol = A communications protocol such as DNP3
Work Tag Applied The Work Tag has been applied/turned off. Refer to Section 8: Work Tags and Control Mode on page 29. Work Tag OFF
Siemens Power Transmission & Distribution, Inc. 99 Appendix H Standard Event Types
100 Siemens Power Transmission & Distribution, Inc. Appendix I Maintenance Event Types I Maintenance Event Types The following table details the maintenance events that can appear in the Event Log.
Event Text Explanation
I contact < 20% Less than 20% contact life remaining in I, II or III vacuum interrupter. II contact < 20% III contact < 20%
Aux Supply Overvolt The auxiliary power supply voltage is above the recommended value.
Battery Overvolt The battery voltage is too high. This will only occur if there is a battery charger hardware failure.
Cap failure mode Trip and/or close capacitors did not charge correctly. Where failure mode is the cause of the failure. For example, "CAP Excess Closes."
Cap Chrg status Logged if a trip/close request is denied due to a capacitor inverter problem. Status is the current status of the inverter, for example "Cap Chrg Resting."
Capmload Reset The Electronic Controller has been reset by the CAPM Loader.
Loader: Close Iso The close/trip isolate needs to be activated to allow a new program to be transferred to the Control. Loader: Trip Iso
Low Power Mode If the power supply voltage reduces below a threshold for a certain time, the radio supply is turned off immediately. The Recloser still operates, but goes to lockout if the capacitors cannot be charged quickly enough.
Mechanism Fail The Recloser has failed to close or trip electrically.
New SCEM Data New SCEM data was written to the SCEM with the operation count and wear updated from the new SCEM data.
Radio Supply Failed The built-in radio supply has failed.
SCEM Corrupted The SCEM records are corrupted.
SCEM type Fail Where type can be Memory or Write.
SCEM Type type The control cable has been connected to a different type of SCEM where type can be SCEM 9, 93C46 or Unknown.
Wrong Switch No n This version of software and the connected switch type are incompatible. “n” is the switchgear type.
Siemens Power Transmission & Distribution, Inc. 101 Appendix I Maintenance Event Types
102 Siemens Power Transmission & Distribution, Inc. Appendix J Control Cubicle Schematics J Control Cubicle Schematics
Figure 31 Control Cubicle Schematic 1 - General Arrangement
Siemens Power Transmission & Distribution, Inc. 103 Appendix J Control Cubicle Schematics
Figure 32 Control Cubicle Schematic 2 - Battery Loom
104 Siemens Power Transmission & Distribution, Inc. Appendix J Control Cubicle Schematics
Figure 33 Control Cubicle Schematic 3 - Main Loom Connection
Siemens Power Transmission & Distribution, Inc. 105 Appendix J Control Cubicle Schematics
Figure 34 Control Cubicle Schematic 4 - Single Integrated Aux Power Supply
106 Siemens Power Transmission & Distribution, Inc. Appendix J Control Cubicle Schematics
Figure 35 Control Cubicle Schematic 5 - Single LV Aux Power Supply
Siemens Power Transmission & Distribution, Inc. 107 Appendix J Control Cubicle Schematics
Figure 36 Control Cubicle Schematic 6 - Integrated Plus LV Aux Power Supply
108 Siemens Power Transmission & Distribution, Inc. Appendix J Control Cubicle Schematics 120/240Vac 120/240Vac
Figure 37 Control Cubicle Schematic 7 - Dual LV Aux Power Supply
Siemens Power Transmission & Distribution, Inc. 109 Appendix J Control Cubicle Schematics
Figure 38 Control Cubicle Schematic 8 - Heater/Thermostat Connection
110 Siemens Power Transmission & Distribution, Inc. Appendix J Control Cubicle Schematics
Figure 39 Control Cubicle Schematic 9 - Control Cable Service Drawing
Siemens Power Transmission & Distribution, Inc. 111 Appendix J Control Cubicle Schematics
112 Siemens Power Transmission & Distribution, Inc. Appendix K Equipment Weights and Crate K Equipment Weights and Crate Dimensions
Part Qty Weight (kg) Weight (lbs)
Centurion Recloser 1 125 275
Surge Arrester Brackets 2 16 35
Pole Mounting Bracket, 12862 center mount
Control Cable 1 6 13
MJ-R Control Cubicle 1 35 77
Crate 1 60 132
Total 270 594
Crate Dimensions
Width 1160mm 46 in
Depth 960mm 38 in
Height 1020mm 41 in
Note: The external voltage transformer, if required, is shipped as a separate item and weighs 28 kg (62 lbs). The packing crates are designed to allow a maximum of two crates to be stacked.
Siemens Power Transmission & Distribution, Inc. 113 Appendix K Equipment Weights and Crate
114 Siemens Power Transmission & Distribution, Inc. Appendix L Pinouts L Pinouts
Figure 40 Centurion Recloser to PC Cable (DB9)
Figure 41 Centurion Recloser to PC Cable (DB25)
Siemens Power Transmission & Distribution, Inc. 115 Appendix L Pinouts
116 Siemens Power Transmission & Distribution, Inc. Glossary
Glossary Instantaneous A user-selectable protection Multiplier setting that multiplies the trip setting to establish the point at Auto-Reclose The Recloser automatically re- which an instantaneous closes after a protection trip. protection trip will occur. Refer Refer to “9.14 Auto-Reclose” on to “9.9 Inverse Time Protection” page 37 for further details. on page 33.
Cold Load A user-set protection feature to Instantaneous An additional protection element Pickup prevent protection trips Protection that will trip the Recloser temporarily when lost diversity immediately when line current causes load currents to be exceeds the Instantaneous temporarily higher than normal. Multiplier Setting times the Trip Refer to “9.18 Cold Load Pickup Current Setting. (The Threshold (CLP)” on page 39 for further Current must also be details. exceeded.) Refer to “9.9 Inverse Time Protection” on page 33. Definite Time A protection function set by the user that causes a trip at a fixed Inverse Time A protection function in which time after pickup. Refer to “9.10 the time-current curve has an Definite Time Protection” on inverse time characteristic. A page 36. variety of user-selectable features can be adjusted to Fault Reset Time An individual protection element construct a final inverse curve. will reset after pickup, when line Refer to “9.9 Inverse Time current falls below the Trip Protection” on page 33. Current Setting for that element for the user-selected reset time. Lockout Recloser status where a Refer to “9.8 Overcurrent Recloser opens, remains open, Protection” on page 32. and will not automatically reclose until closed by an Firmware The control firmware can be operator. Refer to “9.16 Lockout” Capability configured for different on page 38. capabilities such as directional protection, a variety of protocols, Number of SGF A user-set number of SGF trips etc. Each configuration can have trips to lockout that will cause lockout if they different capability. The occur before a sequence reset. capability of each module that This value is set on Protection makes up the firmware is Setting 3 (A or B): SGF Trips displayed on the system status Lockout 1. pages. The document number of the applicable technical manual Operational Cold Varies proportionally with time can also be viewed by scrolling Load Multiplier and changes the Threshold to System Status page 10 Multipliers and the effective trip (Capability), making it easy to level, accordingly. Refer to “9.18 find out exactly what any Cold Load Pickup (CLP)” on particular configuration actually page 39. does. Refer to “2.4 Firmware Operational Cold Used in Cold Load Pickup. This Versions Covered by this Load Time is the time since the load current Manual” on page 3. went to zero and is used to set Inrush Restraint Used to prevent a protection trip the Operational Cold Load due to inrush currents on an Multiplier. initial close. Refer to “9.17 Operator Control The MJ-R keypad and Display Inrush Restraint” on page 39. Panel Panel located inside the Control Cubicle. Refer to Section 7: Operator Control Panel on page 25. Man-machine interface (MMI).
Siemens Power Transmission & Distribution, Inc. 117 Glossary
Operator The first group of settings Threshold A user-selectable protection Settings displayed on the Operator Multiplier setting that defines the Display Panel. A group of Threshold Current. The parameters used by the MJ-R to Threshold Current can be define the primary functionality calculated by multiplying the of the Recloser. Refer to “9.3 Threshold Multiplier by the Trip Operator Settings” on page 31. Setting. Refer to “9.9.2 Interactions between curve Pickup The Recloser "picks up" when parameters” on page 34. the line current exceeds the Trip Current Setting. A 'pickup' event Time to Trip This is the time the Recloser will is written at this stage. take to trip after detecting a fault. This time may be derived Protection The protection elements are from a TCC or other protection Element Phase, Ground, SGF and elements. The timing sequence Instantaneous. Each individual starts when the Threshold element may cause a trip Current is exceeded. A trip is depending on the relevant initiated when the (TCC) time settings. Refer to Section 9: reaches zero. Refer to “9.8 Protection on page 31. Overcurrent Protection” on page 32. Protection A group of settings that change Groups the protection functionality of the Total Protection User-selectable setting that Recloser. Refer to “9.2 Multiple Trips to Lockout defines the total number of Groups of Protection Settings” protection trips in a sequence to on page 31. lockout. This value is set on Protection Setting 2 (A or B): Reclose Time A user-selectable protection Trips to Lockout 4. setting that sets the time between a protection trip and an Trip Current A user-selected magnitude Auto-Reclose. Refer to “9.14 Setting setting which, when exceeded Auto-Reclose” on page 37. This by the line current, causes the feature is sometimes called Recloser to "pick up.” It is also Dead Time. the base value for the Instantaneous, Cold Load, Recloser A circuit breaker with the ability Inrush and Threshold to automatically close after a Multipliers. Refer to “9.8 trip. Overcurrent Protection” on page Sequence Reset A user-set time that must elapse 32. Time after a Recloser operation before the trip counter or trip sequence can reset. Refer to “9.15 Sequence Reset” on page 37. Also known as Reclaim Time.
SGF Sensitive Ground Fault. Refer to “9.11 Sensitive Ground Fault (SGF)” on page 36.
Threshold The current above which the Current protection timing starts to function. This current can be calculated by multiplying the Trip Setting by the Threshold Multiplier. Refer to “9.8 Overcurrent Protection” on page 32.
118 Siemens Power Transmission & Distribution, Inc. Index
Index Dimensions 113 Disconnected event 97
A E Access local or remote 30 Electrical ratings 5 Operator Control Panel password 27 Enable/Disable Isolate switches 26 ACR Opened/Closed 97 Event Log 26, 43 Additional Curve Selection 93 maintenance events 101 Auto Allowed/Not Allowed setting 92 standard events 97 Automatic Protection Group Selection 8, 42, 91, 92 Automatic Reclose 6, 8, 37, 97 F Auto-Reclose OFF/ON setting 91 Ferrite filters 68, 95 Aux Supply Firmware 92 fail 97 versions covered by this manual 3 normal 97 Overvolt event 101 G B G/F OFF Allowed/Not Allowed setting 32, 92 Ground Fault Protection 32 Battery Ground Prot Trip setting 97 low volts 97 Ground Protection Trip Number (1,2,3,4) (A or B) 94 maintenance 71 Grounding 62 normal 97 OFF 97 Overvolt event 101 H Handling 53 C High Current Lockout (LO) OFF/ON setting 8, 38, 93 HV terminals 60 Cable pinout diagrams 115 Cabling of IOEX card 68 Capability display 92 I Capacitors 101 IEC255 Curves 75 Center mounting bracket 95 IEEE Curves 77, 93 Centurion System Software (CSS) 49 Input Output Expander (IOEX) card 49 replacement number 96 cabling 68 Claims for shipping damage 53 power consumption by 51 Close Blocking OFF/ON setting 97 replacement part number 95 Close Coil Connect/Isolate setting 97 System Healthy indicator 50 Cold Load Multiplier formula 40 Inrush OFF/ON setting 93 Cold Load Pickup 7, 39 Inrush Restraint 7, 39 Cold Load IDLE setting 40, 42, 91 Inrush Time 93 Cold Load MAX setting 42, 91 Installation 55 Cold Load NO CHANGE setting 42, 91 Instantaneous Only 93 Cold Load OFF/ON setting 40, 91, 93 Instantaneous Protection 7 Cold Load Time setting 93 Inverse Time Protection 7, 33 Quick Key options 42 Inverse Time Protection Curves 75, 77 Communications 47 Computer port 49 Configuration 92 L Control and Protection Module (CAPM) Live Bushing 97 overview 21 Live Load Blocking 8, 37, 93, 97 Control Cubicle Live/Dead indication 45, 46, 91 construction 15 Load Supply OFF/ON setting 98 maintenance 71 Local Control ON setting 91 power supply options 19 Local Mode 29 remote control of 51 Lockout setting 38, 91, 98 schematics 103–112 Loss of Phase Prot OFF/ON setting 37, 93 Loss of Phase Protection 7, 37, 98 D Loss of Primary Voltage Detection 8 Loss of Supply events 44 Damage claims 53 Low Power Mode 101 Definite Time 93 Definite Time Protection 7, 36 Denied Wrong Mode 97
Siemens Power Transmission & Distribution, Inc. 119 Index
M OFF/ON setting 31, 91, 98 overview 31 Maintenance 71, 95 recorded in the Event Log 43 events in Event Log 101 Protocol Reset event 98 Manual Operation Set 51 replacement number 95 Manual Trip Ring 11, 98 Q Measurements, display of 26 Quick Key options 27 Mech Locked/Unlocked event 98 Cold Load Pickup 42 Mechanical trip 98 Mechanism Fail event 101 MJ-R Control R models covered by this manual 3 Radio Supply Failed event 101 Modes Ratings Local or Remote 29 electrical 5 environmental 5 N timing 5 Real Power 45, 46 New SCEM Data event 101 Reclose Time 93 Non-Standard Inverse Time Protection Curves 81 Recloser Normal power mode 98 construction 11 dimensions 113 O grounding 62 handling 53 Operational Cold Load Multiplier formula 40 installation 55 Operational Cold Load Time 39 maintenance 71 Operator Control Panel manual trip 51 keys 25 memory 11 password entry 27 models covered by this manual 3 Operator Panel Subsystem, replacement part 95 pinouts 115 Operator Settings replaceable parts 95 overview 31 shipping problems 53 site setup 59 P specifications 5 Parallel groove clamp, replacement part 95 testing 57 Parts 95 weight 113 Password entry 27 Year 2000 compliance 4 Phase Prot Trip setting 97 Remote Control ON setting 91 Phase Protection Trip Number (1,2,3,4) (A or B) 93 Remote Control Panel 51 Phase rotation 98 Remote Mode 29 Phasing, setting the 45 Replacements 95 Pickup event 98 RS232 Interface 47, 49 Pinouts 115 Port for computer 49 S Power Sensitive Ground Fault Protection 7, 31, 36 consumption by IOEX card 51 Sequence Advance event 98 factor 45, 46 Sequence Coordination 42 flow direction 45 Sequence Reset 37, 98 low mode 101 Setting the phasing 45 maximum demand display 46 SGF Available/Not Available setting 31, 92 normal mode event 98 SGF Prot Trip setting 97 pin connections for radio/modem 48 SGF Trips Lockout setting 93 real 45, 46 Shipping problems 53 Up/Down event 98 Single Shot Active setting 91 PROT OFF Allowed/Not Allowed setting 92 Single Shot Mode 38, 98 Protection Auto setting 91 Site setup 59 Protection curves 34 Software 49 Protection functions 6 replacement number 96 Protection Groups A and B 32, 42, 98 Source Supply OFF/ON event 98 Protection OFF Not Allowed setting 31 Specifications 5 Protection Settings 92 Substation mounting frame, replacement part 95 1-4 (A or B) 93 Surge arresters changing 32 mounting 61 display of current 26 Switchgear
120 Siemens Power Transmission & Distribution, Inc. Index
Simulator replacement part 96 status 91 Terminal Designation 45, 92 System Healthy indicator 50 System Status 26
T Test and Training Set (TTS) 51, 96 Te s t i n g 5 1 , 57 part number for kit 96 Time Multiplier 93 Time to Trip 38 Timings 5 Training 51 part number for kit 96 Trip Coil Connect/Isolate setting 97 Tr i p / C l o s e key s 2 6 Troubleshooting shipping problems 53
V V23 Interface 47
W Weights 113 Work Tag 29 event 99
Y Year 2000 compliance 4
Siemens Power Transmission & Distribution, Inc. 121 Index
122 Siemens Power Transmission & Distribution, Inc.
Siemens Power Transmission & Distribution, Inc. P.O. Box 29503 Raleigh, NC 27626-0503
Manual No. RCIM-2200 © 1999 Siemens Power Transmission & Distribution, Inc. Printed in the U.S.A. SIEMENS is a registered trademark of Siemens AG. November 1999