Page 1 Preface Open Source Software Table of Contents SIPROTEC 5 Introduction Overcurrent Protection Basic Structure of the Function 7SJ82/7SJ85 System Functions Applications V7.50 and higher Function-Group Types Manual Protection and Automation Functions Capacitor Bank Protection Control Functions Supervision Functions Measured Values, Energy Values, and...
Page 2 Although including rights created by patent grant or registration of a Siemens AG has made best efforts to keep the document as utility model or a design, are reserved. precise and up-to-date as possible, Siemens AG shall not...
Page 3: Preface
Preface Purpose of the Manual This manual describes the protection, automation, control, and monitoring functions of the SIPROTEC 5 devices. Target Audience Protection system engineers, commissioning engineers, persons entrusted with the setting, testing and main- tenance of automation, selective protection and control equipment, and operational crew in electrical installa- tions and power plants.
Page 4 The SIPROTEC 5 catalog describes the system features and the devices of SIPROTEC 5. • Selection guide for SIPROTEC and Reyrolle The selection guide offers an overview of the device series of the Siemens protection devices, and a device selection table. Indication of Conformity...
Page 5 Preface Additional Support For questions about the system, please contact your Siemens sales partner. Support Our Customer Support Center provides a 24-hour service. Phone: +49 (180) 524-7000 Fax: +49 (180) 524-2471 E-Mail: support.energy@siemens.com Training Courses Inquiries regarding individual training courses should be addressed to our Training Center:...
Page 6 The equipment (device, module) may be used only for such applications as set out in the catalogs and the technical description, and only in combination with third-party equipment recommended and approved by Siemens. Problem-free and safe operation of the product depends on the following: •...
Page 7: Open Source Software
License Conditions provide for it you can order the source code of the Open Source Software from your Siemens sales contact - against payment of the shipping and handling charges - for a period of at least 3 years since purchase of the Product. We are liable for the Product including the Open Source Software contained in it pursuant to the license conditions applicable to the Product.
Page 8 SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 9: Table Of Contents
Table of Contents Preface................................3 Open Source Software..........................7 Introduction..............................39 General..........................40 Properties of SIPROTEC 5....................42 Basic Structure of the Function........................43 Function Embedding in the Device..................44 Adjustment of Application Templates/Functional Scope............. 51 Function Control....................... 53 Text Structure and Reference Number for Settings and Indications........57 Information Lists.......................
Page 10 Table of Contents 3.3.4 Quality Processing/Affected by the User in Internal Device Functions......100 Fault Recording.......................104 3.4.1 Overview of Functions ....................104 3.4.2 Structure of the Function................... 104 3.4.3 Function Description....................104 3.4.4 Application and Setting Notes..................107 3.4.5 Settings........................109 3.4.6 Information List......................109 Protection Communication....................111 3.5.1 Overview........................111...
Page 11 Application and Setting Notes................184 3.10.2.5 Settings ......................184 3.10.2.6 Information List....................185 Applications.............................. 187 Overview ........................188 Application Templates and Functional Scope for the Devices 7SJ82/7SJ85......189 Function-Group Types..........................195 Function-Group Type Voltage/current 3-Phase..............196 5.1.1 Overview........................196 5.1.2 Structure of the Function Group................196 5.1.3...
Page 12 Table of Contents 5.5.2 Function-Group Type Capacitor Bank Diff..............225 5.5.2.1 Overview ......................225 5.5.2.2 Structure of the Function Group................226 5.5.2.3 Information List....................228 5.5.3 Function-Group Type Capacitor Bank Side..............228 5.5.3.1 Overview ......................228 5.5.3.2 Structure of the Function Group................229 5.5.3.3 Application and Setting Notes................
Page 13 Table of Contents 5.6.9.3 Temperature Simulation without Sensors ............275 Function-Group Type Circuit Breaker................276 5.7.1 Overview........................276 5.7.2 Structure of the Function Group................277 5.7.3 Application and Setting Notes..................278 5.7.4 Settings........................279 5.7.5 Information List......................280 5.7.6 Trip Logic........................281 5.7.6.1 Function Description....................
Page 14 Table of Contents 6.1.8 Settings........................312 6.1.9 Information List......................318 Group Indications of Overcurrent Protection Functions............ 322 6.2.1 Description ....................... 322 Overcurrent Protection, Phases..................323 6.3.1 Overview of Functions ....................323 6.3.2 Structure of the Function ..................323 6.3.3 Filter for RMS Value Gain................... 325 6.3.3.1 Description......................
Page 15 Table of Contents 6.4.6 Stage with Definite-Time Overcurrent Protection, Voltage-Released Under- voltage Seal-In......................373 6.4.6.1 Description......................373 6.4.6.2 Application and Setting Notes................374 6.4.6.3 Settings....................... 376 6.4.6.4 Information List....................377 Overcurrent Protection, Ground..................378 6.5.1 Overview of Functions....................378 6.5.2 Structure of the Function................... 378 6.5.3 General Functionality....................
Page 16 Table of Contents 6.6.6.4 Information List....................433 6.6.7 Direction Determination.................... 433 6.6.7.1 Description ......................433 6.6.7.2 Application and Setting Notes ................436 6.6.8 Influence of Other Functions via Dynamic Settings ............ 437 6.6.9 Application Notes for Parallel Lines and Cable Runs with Infeed at Both Ends ..... 437 6.6.10 Application Notes for Directional Comparison Protection ...........
Page 17 Table of Contents 6.8.6 Information List......................492 Instantaneous High-Current Tripping................493 6.9.1 Overview of Functions ....................493 6.9.2 Structure of the Function ..................493 6.9.3 Standard Release Procedure..................494 6.9.4 Application and Setting Notes ................... 495 6.9.5 Release Procedure via Protection Interface..............496 6.9.6 Application and Setting Notes ...................
Page 18 Table of Contents 6.12.4 Stage with Inverse-Time Characteristic Curve............. 527 6.12.4.1 Description ......................527 6.12.4.2 Application and Setting Notes ................528 6.12.4.3 Settings....................... 529 6.12.4.4 Information List....................530 6.12.5 Stage with User-Defined Characteristic Curve............. 530 6.12.5.1 Description ......................530 6.12.5.2 Application and Setting Notes ................
Page 19 Table of Contents 6.15.5.4 Information List....................585 6.15.6 Usage Information for Detection of Intermittent Ground Faults........585 6.15.7 Directional 3I0 Stage with φ(V0,3I0) Measurement............ 586 6.15.7.1 Description ......................586 6.15.7.2 Application and Setting Notes................589 6.15.7.3 Settings....................... 591 6.15.7.4 Information List....................591 6.15.8 Directional Y0 Stage with G0 or B0 Measurement............592 6.15.8.1...
Page 20 Table of Contents 6.17.4.3 Settings....................... 637 6.17.4.4 Information List....................638 6.17.5 Stage with Inverse-Time Characteristic Curve............. 639 6.17.5.1 Description......................639 6.17.5.2 Application and Settings Notes................640 6.17.5.3 Settings....................... 641 6.17.5.4 Information List....................641 6.18 Directional Negative-Sequence Protection............... 642 6.18.1 Overview of Functions....................642 6.18.2 Structure of the Function ..................
Page 21 Table of Contents 6.23 Overvoltage Protection with 3-Phase Voltage..............692 6.23.1 Overview of Functions ....................692 6.23.2 Structure of the Function................... 692 6.23.3 Stage with Definite-Time Characteristic Curve............693 6.23.3.1 Description ......................693 6.23.3.2 Application and Setting Notes ................694 6.23.3.3 Settings.......................
Page 22 Table of Contents 6.28.2 Structure of the Function ..................727 6.28.3 General Functionality....................727 6.28.3.1 Description......................727 6.28.3.2 Application and Setting Notes................728 6.28.3.3 Settings....................... 729 6.28.3.4 Information List....................729 6.28.4 Stage with Negative-Sequence Voltage/Positive-Sequence Voltage ......730 6.28.4.1 Description......................730 6.28.4.2 Application and Setting Notes................
Page 23 Table of Contents 6.33.4 Application and Setting Notes..................770 6.33.5 Settings........................771 6.33.6 Information List......................772 6.34 Underfrequency Load Shedding..................773 6.34.1 Overview of Functions....................773 6.34.2 Structure of the Function................... 773 6.34.3 General Functionality....................774 6.34.3.1 Description......................774 6.34.3.2 Application and Setting Notes................777 6.34.4 Stage Description......................
Page 24 Table of Contents 6.37.7 Setting Notes for the Reactive Power Stage..............805 6.37.8 Settings........................806 6.37.9 Information List......................807 6.38 Reverse-Power Protection....................809 6.38.1 Overview of Functions....................809 6.38.2 Structure of the Function................... 809 6.38.3 General Functionality....................810 6.38.3.1 Description ......................810 6.38.3.2 Application and Setting Notes................
Page 25 Table of Contents 6.42.2 Structure of the Function................... 853 6.42.3 Function Description....................853 6.42.4 Application and Setting Notes..................857 6.42.5 Settings........................860 6.42.6 Information List......................861 6.43 Restricted Ground-Fault Protection.................. 862 6.43.1 Overview of Functions ....................862 6.43.2 Structure of the Function ..................862 6.43.3 Function Description....................863 6.43.4...
Page 26 Table of Contents 6.45.7 Application and Setting Notes for General Settings ............924 6.45.8 Application and Setting Notes for 1 Cycle of the Cyclic Automatic Reclosing Function ........................930 6.46 Fault Locator........................933 6.46.1 Overview of Functions....................933 6.46.2 Structure of the Function ..................933 6.46.3 Function Description....................934 6.46.4...
Page 27 Table of Contents Overcurrent Protection for Capacitor Banks..............969 7.2.1 Overview ........................969 7.2.2 Overcurrent Protection, Phases for Protection of RLC Filter-Circuit Elements....969 7.2.2.1 Structure of the Function ..................969 7.2.2.2 Function Description ................... 970 7.2.2.3 Application and Setting Notes ................971 Thermal Overload Protection for Capacitor Banks.............973 7.3.1 Overview of Functions ....................
Page 28 Table of Contents 7.6.3 Stage with Inverse-Time Characteristic Curve............1021 7.6.3.1 Description......................1021 7.6.3.2 Application and Setting Notes................1023 7.6.3.3 Settings......................1025 7.6.3.4 Information List....................1025 7.6.4 Stage with Definite-Time Characteristic Curve............1027 7.6.4.1 Description......................1027 7.6.4.2 Application and Setting Notes................1028 7.6.4.3 Settings......................
Page 29 Table of Contents 8.2.3.4 Settings......................1103 8.2.3.5 Information List....................1104 Control Functionality.....................1105 8.3.1 Command Checks and Switchgear Interlocking Protection........1105 8.3.2 Command Logging ....................1121 8.3.3 Settings........................1125 8.3.4 Information List....................... 1126 Synchronization Function....................1127 8.4.1 Overview of Functions..................... 1127 8.4.2 Structure of the Function..................1127 8.4.3 Connection and Definition..................
Page 30 Table of Contents 8.6.4 Settings........................1178 8.6.5 Information List....................... 1179 CFC-Chart Settings......................1180 8.7.1 Overview of Functions..................... 1180 8.7.2 Function Description....................1180 8.7.3 Application and Setting Notes..................1180 8.7.4 Settings........................1181 8.7.5 Information List....................... 1181 Transformer Tap Changers.................... 1182 8.8.1 Function Description....................1182 8.8.2 Application and Setting Notes..................1186 8.8.3 Settings........................1192 8.8.4...
Page 31 Table of Contents 9.3.4.6 Information List....................1258 9.3.5 Voltage-Balance Supervision..................1258 9.3.5.1 Overview of Functions ..................1258 9.3.5.2 Structure of the Function................... 1258 9.3.5.3 Function Description..................1258 9.3.5.4 Application and Setting Notes ................1260 9.3.5.5 Settings......................1260 9.3.5.6 Information List....................1260 9.3.6 Voltage-Sum Supervision..................
Page 32 Table of Contents 9.3.12.6 Information List....................1281 9.3.13 Trip-Circuit Supervision.................... 1281 9.3.13.1 Overview of Functions..................1281 9.3.13.2 Structure of the Function .................. 1281 9.3.13.3 Trip-Circuit Supervision with 2 Binary Inputs............1282 9.3.13.4 Trip-Circuit Supervision with 1 Binary Input............1283 9.3.13.5 Application and Setting Notes ................1286 9.3.13.6 Settings......................
Page 33 Table of Contents 10.9.5 PMU Communication (IEEE C37.118)............... 1331 10.9.6 Parameterizing the PMU with DIGSI................1332 10.9.7 Parameterizing the PMU on the Device..............1341 10.9.8 Application and Setting Notes..................1343 10.9.9 Settings........................1344 10.9.10 Information List....................... 1345 10.10 Measuring Transducers....................1346 10.10.1 Overview of Functions .................... 1346 10.10.2 Structure of the Function ..................
Page 34 Table of Contents 11.5 Primary and Secondary Tests of the Circuit-Breaker Failure Protection ......1379 11.6 Circuit-Breaker Test....................... 1382 11.7 Functional Test of the Inrush-Current Detection ............1385 11.8 Functional Test of Transient Ground-Fault Protection ............ 1386 11.9 Functional Test of the Trip-Circuit Supervision .............. 1387 11.10 Functional Test for the Phase-Rotation Reversal.............
Page 35 Table of Contents 12.9.2 Stage with Inverse-Time Characteristic Curve............1453 12.9.3 Stage with Inverse-Time Overcurrent Protection with Logarithmic-Inverse Char- acteristic Curve......................1455 12.9.4 Stage with Knee-Point Characteristic Curve ............. 1457 12.9.5 Stage with User-Defined Characteristic Curve............1459 12.10 Inrush-Current Detection....................1462 12.11 Arc Protection.......................
Page 36 Table of Contents 12.35 Overvoltage Protection with Negative-Sequence Voltage/Positive-Sequence Voltage ..1517 12.36 Undervoltage Protection with 3-Phase Voltage.............. 1518 12.37 Undervoltage Protection with Positive-Sequence Voltage..........1521 12.38 Undervoltage Protection with Any Voltage ..............1522 12.39 Overfrequency Protection....................1523 12.40 Underfrequency Protection................... 1524 12.41 Underfrequency Load Shedding..................
Page 37 Table of Contents Typographic and Symbol Conventions................1581 Standard Variants for 7SJ82..................1584 Standard Variants for 7SJ85..................1587 Current Transformer Requirements ................1591 Connection Examples for Current Transformers............. 1594 Connection Examples of Voltage Transformers for Modular Devices....... 1600 Connection Examples of Voltage Transformers for Non-Modular Devices......1606 A.10...
Page 38 SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 39: Introduction
Introduction General Properties of SIPROTEC 5 SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 40: General
Introduction 1.1 General General The digital multifunctional protection and bay controllers of the SIPROTEC 5 device series are equipped with a powerful microprocessor. As a result, all tasks, from acquiring measurands to entering commands in the circuit breaker, are processed digitally. Analog Inputs The measuring inputs transform the currents and voltages sent by the instrument transformers and adapt them to the internal processing level of the device.
Page 41 Introduction 1.1 General Power Supply The individual functional units of the device are powered by an internal power supply. Brief interruptions in the supply voltage, which can occur during short circuits in the system auxiliary voltage supply are generally bridged by capacitor storage (see also the Technical Data). SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 42: Properties Of Siprotec 5
Introduction 1.2 Properties of SIPROTEC 5 Properties of SIPROTEC 5 The SIPROTEC 5 devices at the bay level are compact and can be installed directly in medium and high-voltage switchgear. They are characterized by comprehensive integration of protection and control functions. General Properties •...
Page 43: Basic Structure Of The Function
Basic Structure of the Function Function Embedding in the Device Adjustment of Application Templates/Functional Scope Function Control Text Structure and Reference Number for Settings and Indications Information Lists SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 44: Function Embedding In The Device
Basic Structure of the Function 2.1 Function Embedding in the Device Function Embedding in the Device General SIPROTEC 5 devices offer great flexibility in the handling of functions. Functions can be individually loaded into the device. Additionally, it is possible to copy functions within a device or between devices. The necessary integration of functions in the device is illustrated by the following example.
Page 45 Basic Structure of the Function 2.1 Function Embedding in the Device EXAMPLE The selected application template DIS overhead line, grounded systems, 1 1/2 circuit-breaker layout comprises 3 function groups: • Protection function group Line 1 • Circuit-breaker function group QA 1 •...
Page 46 Basic Structure of the Function 2.1 Function Embedding in the Device Interface Between Function Group and Measuring Point The function groups receive the measurands of the current and voltage transformers from measuring points. For this, the function groups are connected to one or more measuring points. The number of measuring points and the assignment of function groups to the measuring points are preset by the selected application template in accordance with the specific application.
Page 47 Basic Structure of the Function 2.1 Function Embedding in the Device [scmscofg-180311-01.tif, 1, en_US] Figure 2-3 Connecting Measuring Points and Function Groups Interface Between Protection and Circuit-Breaker Function Groups The protection function group(s) is/are connected to one or several circuit-breaker function groups. This connection generally determines: •...
Page 48 Basic Structure of the Function 2.1 Function Embedding in the Device [scfgcols-220211-01.tif, 1, en_US] Figure 2-5 Connection of Protection Function Group with Circuit-Breaker Function Group Besides the general assignment of the protection function group(s) to the circuit-breaker function groups, you can also configure the interface for specific functionalities in detail.
Page 49 Basic Structure of the Function 2.1 Function Embedding in the Device [sclsinta-190214-01, 1, en_US] Figure 2-6 Project Tree in DIGSI 5 (Detail) • Double-click Circuit-breaker interaction (see Figure 2-6). • The window for detailed configuration of the interface between the protection function group and the Circuit-breaker function group(s) opens in the working area.
Page 50 Basic Structure of the Function 2.1 Function Embedding in the Device [scdetail-220211-01.tif, 1, en_US] Figure 2-7 Detail Configuration of the Interface Between the Protection Function Group and the Circuit- Breaker Function Group(s) In the detail configuration of the interface, you define: •...
Page 51: Adjustment Of Application Templates/Functional Scope
• Function settings Siemens recommends the Single-line configuration Editor to adjust the functional scope. Complete missing functionalities from the Global DIGSI 5 Library. Then, the default settings of the added func- tionality are active. You can copy within a device and between devices as well. Settings and routings are also copied when you copy functionalities.
Page 52 Order the additional function points from your local distributor or at http://www.energy.siemens.com. • Siemens will provide you with a signed license file for your device, either via e-mail or for downloading. • Use DIGSI 5 to load the signed license file into your device. The procedure is described in the Online Help of DIGSI 5.
Page 53: Function Control
Basic Structure of the Function 2.3 Function Control Function Control Function control is used for: • Functions that do not contain stages or function blocks • Stages within functions • Function blocks within functions NOTE Simplifying functions and function control will be discussed in the following. The description also applies to tripping stage control and function block control.
Page 54 Basic Structure of the Function 2.3 Function Control The state of the function resulting from the parameter Mode and the superordinate state is shown in the following table. Table 2-1 Resulting State of the Function (from Linkage of Parameter Mode and Superordinate State) Inputs State of the Function Parameter Mode (of the function)
Page 55 Basic Structure of the Function 2.3 Function Control Function State Explanation Test The function is set to test mode. This state supports the commissioning. All outgoing infor- mation from the function (indications and, if present, measured values) is provided with a test bit.
Page 56 Basic Structure of the Function 2.3 Function Control Not Active The indication Not active signals that a function is currently not working. The indication Not active is active in the following cases: • Function is disabled • The function is in the health state Alarm •...
Page 57: Text Structure And Reference Number For Settings And Indications
Basic Structure of the Function 2.4 Text Structure and Reference Number for Settings and Indications Text Structure and Reference Number for Settings and Indications Each parameter and each indication has a unique reference number within every SIPROTEC 5 device. The reference number gives you a clear reference, for example, between an indication entry in the buffer of the device and the corresponding description in the manual.
Page 58 Basic Structure of the Function 2.4 Text Structure and Reference Number for Settings and Indications • Stage: Definite time-overcurrent protection 2 2 instances, because 2 definite time-overcurrent protection stages exist in the Overcurrent 3ph function (here the 2nd instance as an example) This results in the following texts and numbers (including the instance numbers): Parameter: Number...
Page 59: Information Lists
Basic Structure of the Function 2.5 Information Lists Information Lists For the function groups, functions, and function blocks, settings and miscellaneous signals are defined that are shown in the settings and information lists. The information lists summarize the signals. The data type of the information may differ. Possible data types are ENS, ACD, ACT, SPS and MV, etc.
Page 60 SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 61: System Functions
System Functions Indications Measured-Value Acquisition Processing Quality Attributes Fault Recording Protection Communication Date and Time Synchronization User-Defined Objects Other Functions General Notes for Setting the Threshold Value of Protection Functions 3.10 Device Settings SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 62: Indications
System Functions 3.1 Indications Indications General 3.1.1 During operation, indications deliver information about operational states. These include: • Measured data • Power-system data • Device supervisions • Device functions • Function procedures during testing and commissioning of the device In addition, indications give an overview of important fault events after a failure in the system. All indications are furnished with a time stamp at the time of their occurrence.
Page 63 System Functions 3.1 Indications Figure 3-1 On-Site Display of an Indication List (Example: Operational Indications) Menu Path Main menu → Indications → Operational log Fault log Ground-fault log Setting changes User indications 1 User indications 2 Motor-starting indications Main Menu → Test & Diagnosis → Log → Device diagnosis Security indications Communication indications...
Page 64: Reading Indications From The Pc With Digsi 5
System Functions 3.1 Indications Reading Indications from the PC with DIGSI 5 3.1.3 Procedure Menu Path (Project) Project → Device → Process data → Log → Operational log Setting changes Fault log User indications 1 User indications 2 Motor-starting log Ground-fault log Online access →...
Page 65: Displaying Indications
System Functions 3.1 Indications Setting Relative Time Reference Reference the display of log entries, if needed, to the real time of a specific entry. In this way, you deter- ² mine a relative time for all other indications. The real-time stamps of events remain unaffected. Displaying Indications 3.1.4 Displayed indications in DIGSI 5 and on the on-site operation panel are supplemented with the following infor-...
Page 66 System Functions 3.1 Indications Indications in DIGSI 5 Information Device Display Information Log for parameter changes Time stamp (date and time), Time stamp (date and time), Relative time, Function structure, Entry number, Name, Function structure, Value Name, Value, Quality, Cause, Number Spontaneous indication window Time stamp (date and time),...
Page 67: Logs
Indication number Number of the indication that occurred in the device. This number increments continuously and is necessary for an analysis by Siemens. Indication Message text Function Structure Path of the signal with the signal name...
Page 68 System Functions 3.1 Indications Logging Setting-history log Setting changes User-defined log User-defined indication scope Security log Access with safety relevance Device-diagnosis log Error of the device (software, hardware) and the connection circuits Communication log Status of communication interfaces Motor-startup log Information on the motor startup Management of Logs Logs have a ring structure and are automatically managed.
Page 69: Operational Log
System Functions 3.1 Indications For non-configurable logs (for example, setting-history logs) scope and type of logged indications are described separately (see following chapter about logs). 3.1.5.2 Operational Log Operational indications are information that the device generates during operation. This includes information about: •...
Page 70: Fault Log
System Functions 3.1 Indications Reading on the Device via the On-Site Operation Panel • To reach the operational log via the main menu, use the navigation keys of the on-site operation panel. Main Menu → Indications → Operational log • You can navigate within the displayed indication list using the navigation keys (up/down) on the on-site operation panel.
Page 71: Ground-Fault Log
System Functions 3.1 Indications NOTE The definition of the fault is done through settings of the fault recording (see Device manual). Events are logged in the fault log even when fault recording is switched off. Apart from the recording of fault indications in the fault log, spontaneous display of fault indications of the last fault on the device display is also done.
Page 72 System Functions 3.1 Indications The following functions can start the logging of a ground fault with the raising ground-fault indication: • Directional sensitive ground-fault protection for deleted and isolated systems (67Ns) • Sensitive ground current protection with I0 (50Ns/51Ns) • Intermittent ground-fault protection The logging ends with the going ground-fault indication.
Page 73: User Log
System Functions 3.1 Indications Figure 3-8 Reading the Ground-Fault Log on the On-Site Operation Panel of the Device Deletability The ground-fault log of your SIPROTEC 5 device can be deleted. Read details about this in chapter 3.1.6 Saving and Deleting the Logs.
Page 74 System Functions 3.1 Indications Reading on the Device through the On-Site Operation Panel • To reach user-specific logs from the main menu, use the navigation keys of the on-site operation panel. Main Menu → Indications → User-defined log 1/2 • You can navigate within the displayed indication list using the navigation keys (up/down) on the on-site operation panel.
Page 75: Setting-History Log
System Functions 3.1 Indications [scdiu1u2-280415-01, 1, en_US] Figure 3-11 Indication Configuration in DIGSI 5 (Example: User-Defined Log U1/2) 3.1.5.6 Setting-History Log All individual setting changes and the downloaded files of entire parameter sets are recorded in the log for parameter changes. This enables you to determine setting changes made are associated with events logged (for example, faults).
Page 76 System Functions 3.1 Indications Reading on the Device through the On-Site Operation Panel • To reach the setting-history log from the main menu, use the navigation keys of the on-site operation panel. Main menu → Indications → Setting changes • You can navigate within the displayed indication list using the navigation keys (up/down) on the on-site operation panel.
Page 77: Communication Log
System Functions 3.1 Indications NOTE • The logged indications are preconfigured and cannot be changed! • The log, which is organized as a ring buffer, cannot be deleted by the user! • If you want to archive security-relevant information without loss of information, you must regularly read this log.
Page 78: Security Log
System Functions 3.1 Indications Figure 3-15 Reading the Communication Log on the On-Site Operation Panel of the Device Deletability The communication logs of your SIPROTEC 5 device can be deleted. Read details about this in chapter 3.1.6 Saving and Deleting the Logs.
Page 79: Device-Diagnosis Log
System Functions 3.1 Indications Reading on the Device through the On-Site Operation Panel • To access the security log from the main menu, use the navigation keys on the on-site operation panel. Main Menu → Test & Diagnosis → Logs → Security indications •...
Page 80: Saving And Deleting The Logs
System Functions 3.1 Indications [scdevdia-180816-01, 1, en_US] Figure 3-18 Reading the Device-Diagnosis Log with DIGSI 5 Reading on the Device through the On-Site Operation Panel in Normal Operation • To reach the diagnosis log from the main menu, use the navigation keys of the on-site operation panel. Main Menu →...
Page 81 System Functions 3.1 Indications NOTE Not all logs of your SIPROTEC 5 device can be deleted. These limitations apply especially to logs with rele- vance for security and after-sales (security log, device-diagnosis log, setting-history log). NOTE Upon deletion of the fault log, the associated fault records are also deleted. In addition, the meters for fault number and fault-record number are reset to 0.
Page 82: Spontaneous Indication Display In Digsi 5
System Functions 3.1 Indications • After being prompted, enter the password and confirm with Enter. • After being prompted, confirm the Deletion of all entries with Ok. Deleting Logs from the PC with DIGSI 5 • To reach the selected log of your SIPROTEC 5 device, use the project-tree window (for example, opera- tional log).
Page 83 System Functions 3.1 Indications • In the main window, all configured circuit breakers are displayed. A list of a maximum of 6 configurable display lines is offered for each circuit breaker. The activation of a spontaneous fault display occurs for each circuit breaker by selection via checkmark in the column Display.
Page 84: Stored Indications In The Siprotec 5 Device
System Functions 3.1 Indications Method 2: Acknowledgement via LED reset • An LED reset (device) causes the reset of all stored LEDs and binary output contacts of the device and also to the confirmation of all fault displays stored in the display. You can find more details on the topic of LED reset in chapter 3.1.9 Stored Indications in the SIPROTEC 5 Device...
Page 85: Resetting Stored Indications Of The Function Group
System Functions 3.1 Indications Routing Options LEDs Description (stored only with tripping) Routing option TL (tripping stored) is only possible for the switching object circuit breaker. The output is saved with protection tripping. The contact remains activated until acknowledged. Control commands are not affected. A control command is pending above the parameterized command period until feedback has been successfully received.
Page 86: Measured-Value Acquisition
System Functions 3.2 Measured-Value Acquisition Measured-Value Acquisition Basic Principle SIPROTEC 5 devices are equipped with a powerful measured-value acquisition function. In addition to a high sampling frequency, they have a high measurand resolution. This ensures a high degree of measuring accu- racy across a wide dynamic range.
Page 87 System Functions 3.2 Measured-Value Acquisition The 20 samplings per cycle will be made available to the algorithms processed in the function groups, in 2 variants: • Fixed (not resampled) • Resampled (frequency range from 10 Hz to 80 Hz) Depending on the algorithms (see function descriptions), the respective data flow is considered. A higher sampling frequency is used for selected methods of measurement.
Page 88: Processing Quality Attributes
System Functions 3.3 Processing Quality Attributes Processing Quality Attributes Overview 3.3.1 The IEC 61850 standard defines certain quality attributes for data objects (DO), the so-called Quality. The SIPROTEC 5 system automatically processes some of these quality attributes. In order to handle different appli- cations, you can influence certain quality attributes and also the values of the data objects on the basis of these quality attributes.
Page 89 System Functions 3.3 Processing Quality Attributes • OperatorBlocked using the values TRUE , FALSE The OperatorBlocked quality attribute indicates whether an object transferred via GOOSE message origi- nates from a device that is in a functional logoff state. When the sending device is switched off, the object is no longer being received and assumes the invalid state.
Page 90: Quality Processing/Affected By The User For Received Goose Values
System Functions 3.3 Processing Quality Attributes Influencing the Quality by the User You can influence the processing of data and their quality differently. In DIGSI 5, this is possible at the following 3 locations: • In the Information routing editor for external signals of GOOSE connections •...
Page 91 System Functions 3.3 Processing Quality Attributes [sc_LB_GOOSE_2, 1, en_US] Figure 3-26 Influence Option When Linking a DPC Type Data Object Depending on the selected data type of the object, various selection options are offered to you for the Safe state item in the Common settings section. At this point, you select the manually updated values that allow a safe operating state as soon as the data access via the communication path is disturbed.
Page 92 System Functions 3.3 Processing Quality Attributes [sc_LB_GOOSE_1, 1, en_US] Figure 3-27 Advanced Quality Attributes for GOOSE Later Binding With the following advanced quality attributes, you can filter the transmitted GOOSE indications and check and set their quality. The values that have been adapted, if necessary, are forwarded to the receiver. For the tests, you can select from the following setting options depending on the data type.
Page 93 System Functions 3.3 Processing Quality Attributes [sc_LB_GOOSE_3, 1, en_US] Figure 3-28 Value Definition of a Data Object of the SPS Type You can also forward the quality attributes unchanged. To do this, you must mark the Keep flag check box. Functional Logoff by Operator Blocked You have set the Operation mode to Device logoff = true in the transmitting device.
Page 94 System Functions 3.3 Processing Quality Attributes Data Substitute Values Depending on the data type, different data substitute values must be used. Data Type Possible Data Substitute Values ACD, ACT general 0 (False), 1 (True) (The directional information is always manually updated with unknown .
Page 95 System Functions 3.3 Processing Quality Attributes [sc_GOOSE values, 1, en_US] Figure 3-29 Influence Option When Linking a DPC Type Data Object The setting options work for the device receiving the data. Quality Attribute: Validity The validity values reserved and questionable are replaced at the receiving end by the invalid value. •...
Page 96: Quality Processing/Affected By The User In Cfc Charts
System Functions 3.3 Processing Quality Attributes Interaction of the Quality Attribute Validity and OperatorBlocked OperatorBlocked check box is not set and receipt of The OperatorBlocked attribute remains set and is OperatorBlocked = forwarded. TRUE If the Validity check box is set and the receipt of validity = invalid is set, the respective data object substitute value is used.
Page 97 System Functions 3.3 Processing Quality Attributes Quality Attribute: Validity If one invalid signal is received in the case of CFC input data, then all CFC output data will also be set to invalid if they originate from building blocks without explicit quality processing. In other words, the quality is not processed sequentially from building block to building block but the output data are set glob- ally.
Page 98 System Functions 3.3 Processing Quality Attributes Building Blocks Description OR_SPS The building blocks also process the supported quality attributes according to their logic. The following tables describe the logic using input values in connection with the quality attribute Validity. The input values are 0 or 1, the quality attribute Validity can have the AND_SPS value good (=g) or invalid (=i).
Page 99 System Functions 3.3 Processing Quality Attributes Building Blocks Description BUILD_ACD These building blocks merge data value and quality. The building-block output is generally used as a CFC output. BUILD_ACT Generally, the BUILD_Q building block is connected upstream from these building blocks. BUILD_BSC BUILD_DPS BUILD_ENS...
Page 100: Quality Processing/Affected By The User In Internal Device Functions
System Functions 3.3 Processing Quality Attributes the VALID output of the SPLIT_SPS building block with the data value of the input signal (AND gate). This way, you can set the value to a non-risk state with the valid input signals. In the example, the output of the CFC chart is set to the value FALSE when the input signal is invalid.
Page 101 System Functions 3.3 Processing Quality Attributes Routable Binary Input Signals (SPS Data Type) Figure 3-33 shows the possible sources for connecting a binary input signal. Depending on the source, different quality attributes can be set: • CFC chart: See description in chapter 3.3.3 Quality Processing/Affected by the User in CFC Charts •...
Page 102 System Functions 3.3 Processing Quality Attributes [sceinflu de, 1, en_US] Figure 3-34 Influence Options for a Binary Input Signal (SPS Input Signal) Quality Attribute: Validity The Validity attribute can have the values good or invalid (reserved and questionable were already replaced at the input end of the device by the value invalid ).
Page 103 System Functions 3.3 Processing Quality Attributes Quality Attribute: Test The input signal source is in a test state The data value of the source signal is ignored. You can select and the function to be processed is in between the following options: •...
Page 104: Fault Recording
System Functions 3.4 Fault Recording Fault Recording Overview of Functions 3.4.1 All SIPROTEC 5 devices have a fault memory in which fault recordings are kept securely. Fault recording docu- ments operations within the power system and the way in which protection devices respond to them. You can read out fault recordings from the device and analyze them afterwards using evaluation tools such as SIGRA.
Page 105 System Functions 3.4 Fault Recording [dwsigrar-070813-01, 1, en_US] Figure 3-35 Example of a Fault Recording With the Fault recording parameter, you specify the start criterion of the recording. You can set the following values: • with pickup: The fault recording records the complete fault until dropout. The resulting pickup signals of all function groups are taken into account.
Page 106 System Functions 3.4 Fault Recording which the pickup of a protection function also caused a tripping. With this setting, faults beyond the self- protection range will not lead to replacing fault recordings that have already been saved. Configuration of Signals to Be Recorded All analog inputs of the device that have been configured (currents and voltages) are recorded as sampled channels.
Page 107: Application And Setting Notes
System Functions 3.4 Fault Recording Name Type Description Control: Reset memory Delete all recording via the function key. The error numbers are reset. Control: Delete memory Delete all recording via the function key. The error numbers remain as is. Control: >External start Start recording by an external binary signal, for example, by the trip command of an external protection device.
Page 108 System Functions 3.4 Fault Recording Parameter: Storage • Recommended setting value (_:2761:131) Storage = always With the Storage parameter, you define the storage criterion for a fault recording that has already started. Parameter Value Description Each fault recording that has been started is saved. always If at least one protection function issues an operate indication during the with trip...
Page 109: Settings
System Functions 3.4 Fault Recording With the Sampl. freq. IEC61850 rec. parameter, you define the sampling frequency of the fault record that you want to download using the IEC 61850 communication protocol. Possible setting values are 8 kHz, 4 kHz, 2 kHz, and 1 kHz. You cannot set the Sampl.
Page 110 System Functions 3.4 Fault Recording Information Data Class Type (Type) Binary IO _:2761:300 Control:Start record _:2761:305 Control:Reset memory _:2761:306 Control:Clear memory _:2761:502 Control:>External start _:2761:503 Control:>Manual start _:2761:310 Control:Fault number _:2761:311 Control:Recording started _:2761:314 Control:Record made _:2761:327 Control:Tmax reduced _:2761:324 Control:Fault log is full SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 111: Protection Communication
System Functions 3.5 Protection Communication Protection Communication Overview 3.5.1 Protection communication includes all functionalities required to exchange data via the protection interface (PI). It manages one or a maximum of 2 protection interfaces. The Protection communication is generated with the configuration of the channels as a protocol. You can find detailed information in the section Protection interface in chapter 3.5.3.1 Overview of Func- tions.
Page 112: Protection Interface And Protection Topology
System Functions 3.5 Protection Communication Protection Interface and Protection Topology 3.5.3 3.5.3.1 Overview of Functions The Protection topology and protection interface function enables data exchange between the devices via synchronous serial point-to-point connections from 64 kBit/s to 2 MBit/s. These connections can be established directly via optical fibers or via other communication media, for example via dedicated lines or via communi- cation networks.
Page 113: Function Description
System Functions 3.5 Protection Communication 3.5.3.3 Function Description Topology and Type of Protection Communication The protection interfaces (PI) establish a direct point-to-point connection between devices via different communication media. Data can be transferred within the switchgear or between switchgears. Devices connected to one another with protection communication form a protection topology. Refer to Figure 3-38.
Page 114 The communication takes place via direct fiber-optic connections, via communication networks or via 2-wire copper conductors. Siemens recommends a direct fiber-optic connection, as this offers the highest transmis- sion rate of 2 MBit/s and is immune to failures in the communication route while offering the shortest trans- SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 115 System Functions 3.5 Protection Communication mission time. This also enables the transmission of a large amount of additional information on differential protection routes and the remote control of devices at the remote end with DIGSI 5. The distance to be bridged and the transmission paths available determine the settings of the protection inter- face.
Page 116 System Functions 3.5 Protection Communication Plug-In Modules Physical Connection 1 x optical serial, bi-directional via 1 optical fiber, ● 1550/1300 nm (Tx/Rx), simplex plug LC, 40 km via 9/125 μm singlemode optical fiber 2 x optical serial, bi-directional via 1 optical fiber, ●...
Page 117 System Functions 3.5 Protection Communication [dwmultim-070611-01.tif, 1, en_US] Figure 3-41 Connection over Short Distances, 1.5 km to 2 km via Multimode Optical Fiber [dwmultim-070611-02.tif, 1, en_US] Figure 3-42 Connection over Maximum 4 km via Multimode Optical Fiber [dwsingle-070611-03.tif, 1, en_US] Figure 3-43 Connection via Different Distances via Singlemode Optical Fiber NOTE...
Page 118 System Functions 3.5 Protection Communication [dwsingle-020513-04.tif, 1, en_US] Figure 3-44 Connection via Singlemode Optical Fiber [dwmultim-070611-05.tif, 1, en_US] Figure 3-45 Connection via Communication Network with a G703.1 Interface The connection to the multiplexer is established via a communication converter with a G703.1 interface (64 kBit/s) or X21 interface (64 kBit/s to 512 kBit/s).
Page 119 System Functions 3.5 Protection Communication [dwmulti7-070611-01.tif, 1, en_US] Figure 3-47 Connection via 2-Wire Copper Cables The connection to a communication converter with an integrated 5-kV isolation voltage is established with 128 kBit/s (KU-KU-128 setting in accordance with Table 3-12). A 20 kV isolation of the 2-wire connection is possible via an external 7XR9516 isolating transformer.
Page 120 System Functions 3.5 Protection Communication Supervision of the Communication The communication is continuously monitored by the devices. If a number of defective data telegrams, or no data telegrams at all, are received, this is regarded as a failure in the communication as soon as a failure time of 100 ms (default setting can be changed) is exceeded. A list of the measured values is shown in a window in DIGSI 5 (defective telegrams per minute/hour;...
Page 121 System Functions 3.5 Protection Communication Time Synchronization of the Line Differential Protection Measured Values with Millisecond Accuracy The measured values of the line differential protection for the various line ends are synchronized with each other with microsecond accuracy via the mechanisms of the protection interface. The protection interface displays this state with the RAISING indication Protection interface synchronized .
Page 122: Initialization And Configuration Of The Protection Interface In Digsi 5
System Functions 3.5 Protection Communication 3.5.3.4 Initialization and Configuration of the Protection Interface in DIGSI 5 If the device is provided with modules, proceed as follows: • Select the desired communication module in the rear view of the device. • Use the Communication protocols text box to select the protection interface.
Page 123: Device-Combination Settings
System Functions 3.5 Protection Communication If the module slot is not yet provided with modules, proceed as follows: • Select the desired communication module in the rear view of the device. • Select the module from the catalog and drag it to a channel. Thus is the channel configured with a module.
Page 124 System Functions 3.5 Protection Communication Changes in 1 channel are always visible on the other channel as well. All further parameters can be set sepa- rately for individual channels. Setting Device-Combination Settings • Default setting (_:5131:102) Address of device 1 = 101 •...
Page 125: Selecting The Connection
System Functions 3.5 Protection Communication If you wish to operate, for example, a 3-device protection communication as a 2-device protection communi- cation, you must set the Number of devices parameter = 2. If you expand the system later, change the Number of devices parameter to the number of devices actually present.
Page 126 Only if the Line differential protection function is instantiated, the Difference Tx and Rx time parameter is displayed. NOTE If the user employs a multiplexer with a C37.94 interface as a communication medium, Siemens recom- mends a setting value of 0.25 ms to 0.6 ms. Parameter: PPS Synchronization •...
Page 127 If you are using a second pulse from a GPS receiver, you must ensure that a loss of reception or reception disturbances do not generate a second pulse. The GPS receivers recommended by Siemens are set by default SIPROTEC 5, Overcurrent Protection, Manual...
Page 128: Routing Information In Digsi 5
In the event of problems, check the setting value for the second pulse. Siemens recommends the Meinberg 164 GPS receiver. Check the default setting for the second pulse using the GPSMON32 program. The program is available in the SIPROTEC download area.
Page 129 System Functions 3.5 Protection Communication [dwdatenl-100113-01.tif, 1, en_US] Figure 3-57 Data Bar Exchanged Between Devices The data bar is divided into 3 priorities, which also have different transmission rates and data volumes. The following basic principle applies for all messages: Only pure data contents are transmitted. The quality (for example, Valid ) is not automatically transmitted as well.
Page 130 System Functions 3.5 Protection Communication Table 3-14 Available Bits - Minimum Constellation Baud Rate 512/2048 kbit/s Priority 1 Priority 2 Priority 3 Type 1 48 bits 128 bits 384 bits Type 2 96 bits 200 bits 1024 bits Table 3-15 Requirement in Bits Signal Type Size in Bits...
Page 131 System Functions 3.5 Protection Communication Figure 3-58 Figure 3-61 show the routing for a communication topology of protection interface type 1. To transmit signals to other devices, these signals must be routed in the communication matrix under Transmit. Binary inputs 1 and 2 are single-point indications (SPS) and are routed to position 1 and position 2 of the transmission with the highest priority (priority 1).
Page 132 System Functions 3.5 Protection Communication [scrangzw-021210-01.tif, 1, en_US] Figure 3-60 Routing of Metered Values to the Protection Interface in Device 1 This device also receives information (in the matrix under Receive). This must have been routed as a target for other devices (see next figure).
Page 133 System Functions 3.5 Protection Communication [scbaspsr-021210-01.tif, 1, en_US] Figure 3-62 Routing of Single-Point Indications to be Sent to the Protection Interface in Device 2 The binary outputs 1 and 2 (Receive) in the 2nd device are connected to priority 1 signals 1 and 2 from the 1st device.
Page 134: Diagnostic Measured Values Of The Protection Interface
System Functions 3.5 Protection Communication [scbauszw-021210-01.tif, 1, en_US] Figure 3-65 Routing of Metered Values to the Protection Interface in Device 2 3.5.3.9 Diagnostic Measured Values of the Protection Interface The following diagnostic data is provided via the protection interfaces by the devices in the constellation: •...
Page 135 System Functions 3.5 Protection Communication NOTE You can use the following procedure to reset the measured values for the protection interface directly in the device: Device functions > x Device protection comm. > Protection interface y > Reset measured values. Output Signals of the Protection Interface Each individual protection interface provides the following indications for commissioning and diagnosing communication:...
Page 136 System Functions 3.5 Protection Communication Indication Description The output signal gives you information about the state of communication layers (_:5161:302) Status 3 and 4 (3: Network Layer, 4: Transport Layer). The following indications values of lay. 3 and 4 are possible: •...
Page 137 Note: If the signal is constantly routed, the operational log can overflow. Siemens recommends routing the signal only for clarification of faults.
Page 138: Diagnostic Data For The Protection Interface
System Functions 3.5 Protection Communication Measured Value Description Number of telegram failures within the last week (_:5161:337) Miss.tel/w Longest lasting telegram failure within the last day (_:5161:338) M. loss/d Longest lasting telegram failures within the last week (_:5161:339) M. loss/w NOTE You can reset the measured values of the protection interface directly in the device.
Page 139 System Functions 3.5 Protection Communication Channel Type Name Values Description - Diagnostic Information for Log PI Protection interfaces - log Build Date/time Date and time of the log version Diagnostic Data of the Protection-Interface Log in DIGSI 5 The following figures and tables describe the displays of the protection-interface log. [scdiamed-140912-01, 1, en_US] Figure 3-68 Diagnostic Data of the Protection-Interface Log - Media Status...
Page 140 System Functions 3.5 Protection Communication [scdiacom-140912-01, 1, en_US] Figure 3-69 Diagnostic Data of the Protection-Interface Log - HDLC (Log - Layer) Table 3-19 Description of Diagnostic Data of the Protection-Interface Log - HDLC (Log - Layer) Protection Interfaces - Log Name Values Description - HDLC Link...
Page 141 Sending telegrams, low frames (16 bit counter) priority, faulty HDLC Bridge Details Sub-nodes Sub-nodes Siemens-internal special diagnostic for fault search [scdiahdl-140912-01, 1, en_US] Figure 3-70 Diagnostic Data of the Protection-Interface Log - COM Interface (Internal COM Link Interface Between Module and Mainboard) SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 142: Settings
Sending telegrams, low frames (16 bit counter) priority, faulty COM interface Bridge Details Sub-nodes Sub-nodes Siemens-internal special diagnostic for fault search Table 3-21 Description of Diagnostic Data of some Setting Values of the Protection Interface Protection Interfaces - Log Name...
Page 143: Information List
System Functions 3.5 Protection Communication Addr. Parameter Setting Options Default Setting _:5131:106 Device combin.:Address 1 to 65534 of device 5 _:5131:107 Device combin.:Address 1 to 65534 of device 6 _:5131:101 Device combin.:Local 1 to 6 device is device • _:5131:122 Device combin.:Lowest 64 kBit/s 64 kBit/s...
Page 144 System Functions 3.5 Protection Communication Information Data Class Type (Type) _:5131:312 Device combin.:Device 1 available _:5131:313 Device combin.:Device 2 available _:5131:314 Device combin.:Device 3 available _:5131:315 Device combin.:Device 4 available _:5131:316 Device combin.:Device 5 available _:5131:317 Device combin.:Device 6 available Prot.
Page 145 System Functions 3.5 Protection Communication Information Data Class Type (Type) _:9181:301 Ext. Synchron.:PPS pulse loss _:9181:302 Ext. Synchron.:PPS pulse Meas.val.dev.1 _:1351:6811:300 Meas.val.dev.1:Dev.adr. _:1351:6811:301 Meas.val.dev.1:Line _:1351:6811:302 Meas.val.dev.1:Vph _:1351:6811:303 Meas.val.dev.1:Iph Meas.val.dev.2 _:1351:6841:300 Meas.val.dev.2:Dev.adr. _:1351:6841:301 Meas.val.dev.2:Line _:1351:6841:302 Meas.val.dev.2:Vph _:1351:6841:303 Meas.val.dev.2:Iph Meas.val.dev.3 _:1351:6871:300 Meas.val.dev.3:Dev.adr. _:1351:6871:301 Meas.val.dev.3:Line _:1351:6871:302...
Page 146: Date And Time Synchronization
System Functions 3.6 Date and Time Synchronization Date and Time Synchronization Overview of Functions 3.6.1 Timely recording of process data requires precise time synchronization of the devices. The integrated date/ time synchronization allows the exact chronological assignment of events to an internally managed device time that is used to time stamp events in logs, which are then transmitted to a substation automation tech- nology or transferred via the protection interface.
Page 147 System Functions 3.6 Date and Time Synchronization Configurable Time Sources: • 2 time sources can be taken into consideration with the SIPROTEC 5 devices. For each time source, the synchronization type may be selected based on the options provided. • Time source 1 takes precedence over Time source 2, that is, Time source 2 will be effective for the synchronization of the device time only if Time source 1 fails.
Page 148 System Functions 3.6 Date and Time Synchronization Indication Description Device: This indication signals a high difference between the internally managed time and the time of the clock Clock fail module that is not permissible. The pickup of the indi- cation can point to a defect in the clock module or to an unacceptable high drift of the system quartz crystal.
Page 149: Application And Setting Notes
System Functions 3.6 Date and Time Synchronization [sctimedg-220415, 1, en_US] Figure 3-71 Time Information in DIGSI For every time source, you see the following: • Last received time (with date) • Receipt time of the last received time telegram • Configured type of timer •...
Page 150 System Functions 3.6 Date and Time Synchronization Parameter Value Description Local time zone and daylight saving time are considered as time zone offsets to local GMT. Time format according to UTC (universal time) Parameter: Time source 1,Time source 2 • Default setting Time source 1 = none, Time source 2 = none With the Time source 1 and Time source 2 parameters, you can configure an external timer.
Page 151 System Functions 3.6 Date and Time Synchronization Parameter Value Description The time is synchronized via telegram with an appropriately configured IEC 60870-5-103 communication interface in accordance with the IEC 60870-5-103 protocol. Time zone time source 1 or Time zone time source 2 = local However, there are also T103 systems that send the UTC.
Page 152: Settings
System Functions 3.6 Date and Time Synchronization Selection Button Description Manual settings (local time zone and daylight saving This setting must be selected if you want to select the time regulation) local time zone and daylight saving time zone regula- tions of your SIPROTEC 5 device regardless of the PC settings.
Page 153: Information List
System Functions 3.6 Date and Time Synchronization Addr. Parameter Setting Options Default Setting • _:106 Time sync.:Time source port J • 2 port port F • port E • port P • port N • port G • _:107 Time sync.:Time source •...
Page 154: User-Defined Objects
System Functions 3.7 User-Defined Objects User-Defined Objects Overview 3.7.1 With help from user-defined function groups and user-defined functions you can group user-defined objects, for example user-defined function blocks. 2 user-defined function blocks are available (see following figure). [scudef_lib, 1, en_US] Figure 3-73 User-Defined Objects in the DIGSI 5 Library The user-defined function block allows you to add (see following figure) single-point indications, pickup indi-...
Page 155: Basic Data Types
System Functions 3.7 User-Defined Objects Basic Data Types 3.7.2 The following data types are available for user-defined objects in the DIGSI 5 library under the heading User- defined signals. Additionally, a folder for external signals is available (see chapter 3.7.5 External Signals).
Page 156 System Functions 3.7 User-Defined Objects [scspsfas-140613-01.tif, 1, en_US] Figure 3-76 Single-Point Indication SPS Unsaved (Example: 7KE85 Fault Recorder) Double-Point Indication (Type DPS: Double-Point Status) When using a double-point indication, the status of 2 binary inputs can be captured simultaneously and mapped in an indication with 4 possible conditions (ON, Intermediate position, OFF, Disturbed position).
Page 157 System Functions 3.7 User-Defined Objects EXAMPLE The output of the CFC block ADD_D can, for example, be connected with the data type INS. The result can be shown on the display of the device. State of an Enumeration Value (Type ENS) The data type ENS is used to create an enumerated value that represents a CFC result.
Page 158: Pulse- And Energy- Metered Values , Transformer Taps
System Functions 3.7 User-Defined Objects Pulse- and Energy- Metered Values , Transformer Taps 3.7.3 Pulse-Metered Values Pulse-metered values are available as data types BCR (Binary Counter Reading) in the DIGSI library under User- defined Functions. The functionality and the settings of the pulse-metered values can be found in chapter 10.8.1 Function Description of Pulse-Metered Values Transformer Taps...
Page 159 System Functions 3.7 User-Defined Objects [sc_LB_extsign, 1, en_US] Figure 3-77 External Signals NOTE Consider the chapter on GOOSE Later Binding in the DIGSI Online Help. User-defined signals exist as external signals and as preconfigured inputs that have been activated via the GOOSE column. SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 160: Other Functions
System Functions 3.8 Other Functions Other Functions Signal Filtering and Chatter Blocking for Input Signals 3.8.1 Input signals can be filtered to suppress brief changes at the binary input. Chatter blocking can be used to prevent continuously changing indications from clogging the event list. After an adjustable number of changes, the indication is blocked for a certain period.
Page 161 System Functions 3.8 Other Functions example. If you select the General software filter setting, the general settings for software filtering of spontaneous position changes and for position changes caused by a switching command apply. The settings for spontaneous position changes can then not be edited. A separate filtering for spontaneous position changes is activated with the Spontaneous software filter setting and you can edit the settings for this.
Page 162 System Functions 3.8 Other Functions [scparafl-291110-01.tif, 2, en_US] Figure 3-80 Chatter-Blocking Settings The chatter-blocking settings have the following meaning (see also Figure 3-81 Figure 3-82 in the exam- ples shown in the following): • No. permis.state changes This number specifies how often the state of a signal may toggle within the chatter-test time and the chatter-checking time.
Page 163 System Functions 3.8 Other Functions • Subsequent test time During this second test time, the number of times a signal changes its status is checked once again. The time begins when the Chatter idle time expires. If the number of status changes is within the permissible limits, the signal is released.
Page 164: Acquisition Blocking And Manual Updating
System Functions 3.8 Other Functions Example 2: Temporary Blocking The chatter-blocking settings are set as follows: • No. permis.state changes = 4 • No. of chatter tests = 2 After more than 4 state changes within the Initial test time, the input signal is set to the original state by the chatter blocking and the oscillatory quality is assigned.
Page 165 System Functions 3.8 Other Functions • Enter the confirmation ID. • Confirm the process with the softkey marked OK in the display. After entering the confirmation ID, the acquisition blocking function is switched on. [scerfass-310816-01, 1, en_US] Figure 3-83 Activating the Acquisition Blocking Manual updating of the switching device is possible from within the same menu.
Page 166 System Functions 3.8 Other Functions NOTE Setting acquisition blocking and the subsequent manual updating are also possible via the IEC 61850 system interface. You can also set the acquisition blocking via a binary input. If you want to put the feeder or the switching device in revision, you can set the acquisition blocking for an individual or several switching devices with an external toggle switch.
Page 167: Persistent Commands
System Functions 3.8 Other Functions Persistent Commands 3.8.3 In addition to the switching commands, which are issued as pulse commands, and stored for the standard switching devices (circuit breaker, disconnector switch), persistent commands are also possible. In this case, a distinction must be drawn between controllables with the Continuous output operating mode and a stored signal output that is immune to reset.
Page 168: Application And Setting Notes
System Functions 3.8 Other Functions NOTE If you need to remove a device temporarily from the plant, you must log off the device. Protection functions distributed to several devices operate in a healthy manner with the remaining devices only if you have logged off the device. You can log off the device as follows: •...
Page 169 System Functions 3.8 Other Functions The conditions for a successful logoff of the device result from the conditions for every activated protection function. Logoff of a Device from a Device Combination with Communication via the IEC 61850-8-1 (GOOSE) Protocol If devices are exchanging data via the IEC 61850-8-1 (GOOSE) protocol, for example, in the case of substation interlocking, you can set in the receiver device for each received data point the value of this data point when the transmitter device logs off.
Page 170: Information List
System Functions 3.8 Other Functions The indications are stored in the operational log. 3.8.4.3 Information List Information Data Class Type (Type) General _:507 General:>Device funct.logoff on _:508 General:>Dev. funct.logoff off _:319 General:Device logoff _:313 General:Logged off via BI _:314 General:Logged off via control _:315 General:Device logged off SIPROTEC 5, Overcurrent Protection, Manual...
Page 171: General Notes For Setting The Threshold Value Of Protection Functions
If parameters are selected it may happen that they are set only in percent in all 3 setting views. Recommendation for Setting Sequence When setting the protection function, Siemens recommends the following procedure: • First set the transformation ratios of the transformers. You can find these under Power-system data.
Page 172 System Functions 3.9 General Notes for Setting the Threshold Value of Protection Functions The following setting example shows how you can change the transformer ratio in DIGSI 5, and what impact this has on the settings in the setting views Primary and Secondary. The protection setting is observed in the example of the Overcurrent protection function.
Page 173 System Functions 3.9 General Notes for Setting the Threshold Value of Protection Functions [scpwandl_3, 1, en_US] Figure 3-94 Setting Sheet: Transformer Data In the function group Voltage/current 3-phase, you set the rated current and the rated voltage (see following figure). Rated current, rated voltage are the reference variables for the percent setting. [scui3phd, 1, en_US] Figure 3-95 Reference Data for Percentage Settings...
Page 174 System Functions 3.9 General Notes for Setting the Threshold Value of Protection Functions [scumzpri_5, 1, en_US] Figure 3-96 Example of the Threshold Value of the Definite Time-Overcurrent Protection (Edit Mode: Primary) When switching over to the percent view, the result should be the following value: 1500 A/1000 A ·...
Page 175 System Functions 3.9 General Notes for Setting the Threshold Value of Protection Functions [scumzpro_6, 1, en_US] Figure 3-97 Example of the Threshold Value of the Definite Time-Overcurrent Protection (Edit Mode: Percent) When switching over to the secondary view, the result should be the following value: 1500 A/(1000 A/1 A) = 1.5 A SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 176 System Functions 3.9 General Notes for Setting the Threshold Value of Protection Functions [scumzsek_7, 1, en_US] Figure 3-98 Example of the Threshold Value of the Definite Time-Overcurrent Protection (Edit Mode: Secondary) If you only want to work in the secondary view, DIGSI 5 supports you if the transformer ratio changes during the project phase.
Page 177 System Functions 3.9 General Notes for Setting the Threshold Value of Protection Functions [scfragew_8, 1, en_US] Figure 3-99 Query after Changing the Transformer Data (Setting View: Secondary) If you answer the question with Yes, then DIGSI 5 will recalculate the pickup values (threshold values) in the active secondary view.
Page 178: Changing The Transformation Ratios Of The Transformer On The Device
System Functions 3.9 General Notes for Setting the Threshold Value of Protection Functions [scsekneu_9, 1, en_US] Figure 3-100 Automatically Recalculated Secondary Values After Changes in the Transformer Data If you have already set the settings in the secondary view by including the new transformation ratio of the transformer in the calculation, then answer the question with No.
Page 179: 3.10 Device Settings
System Functions 3.10 Device Settings 3.10 Device Settings General Device Settings 3.10.1 3.10.1.1 Overview In Device settings in DIGSI 5, you find the following general settings. [scDeSeDe1-310715-01, 1, en_US] [scDeSeAl-310715-01, 2, en_US] SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 180: Application And Setting Notes
You can also permit, for example, a trip command to close an energized binary output for test purposes. Siemens recommends deactivating theTest support again after the test phase. 3.10.1.2 Application and Setting Notes The major portion of the settings is described in the chapters cited above.
Page 181: Settings
System Functions 3.10 Device Settings and the end (confirmation) is the time Reserv.time for com.prot.. Otherwise, the parameterization operation is canceled with a time-out and changes are rejected. This setting value is valid only for the device. Parameter: Block monitoring dir. •...
Page 182: Siprotec 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition
System Functions 3.10 Device Settings Addr. Parameter Setting Options Default Setting Spontan.indic. • _:139 General:Fault-display with pickup with pickup • with trip Test support • _:150 General:Activate device false • test mode • _:151 General:Oper.bin.outp. false • under test 3.10.1.4 Information List Information Data Class...
Page 183: Structure Of The Function
System Functions 3.10 Device Settings 3.10.2.2 Structure of the Function The function of the Settings group switching is a supervisory device function. Accordingly, the settings and indications of the settings group switching can be found in DIGSI 5 and at the on-site operation panel of the device, below the general device settings respectively.
Page 184: Application And Setting Notes
System Functions 3.10 Device Settings If you want to copy settings groups, select a source and target parameter group in DIGSI 5 in the device settings, and then start the copy process. The device settings can be found in the DIGSI 5 project tree under Project →...
Page 185: Information List
System Functions 3.10 Device Settings 3.10.2.6 Information List Information Data Class Type (Type) General _:500 General:>SG choice bit 1 _:501 General:>SG choice bit 2 _:502 General:>SG choice bit 3 _:300 General:Act. settings group 1 _:301 General:Act. settings group 2 _:302 General:Act.
Page 186 SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 187: Applications
Applications Overview Application Templates and Functional Scope for the Devices 7SJ82/7SJ85 SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 188: Overview
Applications 4.1 Overview Overview The Global DIGSI 5 library provides application templates for the applications of the devices. The application template • Supports the fast realization of complete protection solutions for applications • Contains the basic configuration for the use case •...
Page 189: Application Templates And Functional Scope For The Devices 7Sj82/7Sj85
Application Templates and Functional Scope for the Devices 7SJ82/7SJ85 Application templates are available in DIGSI 5 for the applications of the non-modular device 7SJ82 and the modular device 7SJ85. The application templates contain the basic configurations, required functions, and default settings.
Page 190 Applications 4.2 Application Templates and Functional Scope for the Devices 7SJ82/7SJ85 ANSI Function Abbr. Undervoltage protection, 1-phase, Vx< universal, Vx 27/Q Undervoltage-controlled reactive- power protection Reverse power protection -P< 32, 37 Power protection active/reactive power P<>, Q<> x Undercurrent protection I<...
Page 191 Applications 4.2 Application Templates and Functional Scope for the Devices 7SJ82/7SJ85 ANSI Function Abbr. Overvoltage protection, negative- V2> sequence system Overvoltage protection with negative- V2/V1> sequence voltage/positive-sequence voltage Overvoltage protection, zero-sequence V0> system Overvoltage protection, 3-phase or 1- Vx> phase, universal, Vx...
Page 192 Applications 4.2 Application Templates and Functional Scope for the Devices 7SJ82/7SJ85 ANSI Function Abbr. Rate of frequency change protection df/dt Vector-jump protection Lockout Capacitor bank differential protection Voltage differential protection ΔV Restricted ground-fault protection ΔIN Voltage controller Arc protection Prot...
Page 193 Applications 4.2 Application Templates and Functional Scope for the Devices 7SJ82/7SJ85 ANSI Function Abbr. Control Fault recording of analog and binary signals Monitoring and supervision Protection interface, serial Capacitor bank Circuit breaker Circuit breaker [control] Circuit breaker [status only] Disconnector...
Page 194 SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 195: Function-Group Types
Function-Group Types Function-Group Type Voltage/current 3-Phase Function-Group Type Voltage/current 1-Phase Function-Group Type Voltage 3-Phase Function-Group Type Capacitor Bank Function-Group Type Capacitor Bank Differential Protection Function-Group Type Analog Units Function-Group Type Circuit Breaker Process Monitor SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 196: Function-Group Type Voltage/Current 3-Phase
Function-Group Types 5.1 Function-Group Type Voltage/current 3-Phase Function-Group Type Voltage/current 3-Phase Overview 5.1.1 All functions for protection and supervision of a protected object or equipment allowing 3-phase current and voltage measurement can be used in the function group Voltage-current 3-phase. The function group also contains the operational measurement for the protected object or equipment (on this topic, see chapter 10 Measured Values, Energy Values, and Supervision of the Primary System).
Page 197 Function-Group Types 5.1 Function-Group Type Voltage/current 3-Phase The function group has interfaces with • Measuring points • Circuit-breaker function group Interface with Measuring Points The function group receives the required measured values via its interfaces with the measuring points. If you are using an application template, the function group is already connected to the necessary measuring points.
Page 198 Function-Group Types 5.1 Function-Group Type Voltage/current 3-Phase In the detail configuration of the interface, you define: • Which operate indications of the protection functions go into the generation of the trip command • Which protection functions start the automatic reclosing function •...
Page 199 Function-Group Types 5.1 Function-Group Type Voltage/current 3-Phase Measured Values Primary Secon- % Referenced to dary Frequency Rated frequency Active power Active power of the primary values total (total power) √3 · V · I rated rated Reactive power Mvar Reactive power of the primary values total (total power) √3 ·...
Page 200: Application And Setting Notes
Function-Group Types 5.1 Function-Group Type Voltage/current 3-Phase [lo_anrlin, 3, en_US] Figure 5-2 Creation of the Pickup Indication of the Voltage-Current 3-Phase Function Group The trip signals from the protection and supervision functions of the Voltage-current 3-phase function group always result in 3-pole tripping of the device. [loauslin-150211-01.tif, 3, en_US] Figure 5-3 Creation of the Operate Indication of the Voltage-Current 3-Phase Function Group...
Page 201: Write-Protected Settings
Function-Group Types 5.1 Function-Group Type Voltage/current 3-Phase If the device works with the IEC 61850 protocol, then you change only the setting value of the parameter via DIGSI 5 and not directly on the device. If you change the setting value directly on the device, then the IEC 61850 configuration of the metered values can be faulty.
Page 202: Information List
Function-Group Types 5.1 Function-Group Type Voltage/current 3-Phase Information List 5.1.6 Information Data Class Type (Type) General _:9451:52 General:Behavior _:9451:53 General:Health Group indicat. _:4501:55 Group indicat.:Pickup _:4501:57 Group indicat.:Operate Reset LED Group _:7381:500 Reset LED Group:>LED reset _:7381:320 Reset LED Group:LED have been reset Closure detec.
Page 203: Function-Group Type Voltage/Current 1-Phase
Function-Group Types 5.2 Function-Group Type Voltage/current 1-Phase Function-Group Type Voltage/current 1-Phase Overview 5.2.1 In the Voltage-current 1-phase function group, all functions can be used for protecting and for monitoring a protected object or equipment which allow a 1-phase current and voltage measurement or a zero-sequence voltage measurement via a 3-phase voltage measuring point.
Page 204 Function-Group Types 5.2 Function-Group Type Voltage/current 1-Phase [scVI1ph_V1ph, 1, en_US] Figure 5-5 Connecting Measuring Points to the Voltage-Current 1-Phase Function Group If you select the voltage type VN broken-delta for the 1-phase voltage measuring point in the measuring point routing (see the following figure), the device measures the residual voltage V at the broken-delta winding.
Page 205 Function-Group Types 5.2 Function-Group Type Voltage/current 1-Phase The following table shows the properties of the voltage input for the Voltage-current 1-phase function group depending on the connection types. Connection Type of the 3- Voltage Input Phase Voltage Measuring Point 3 ph-to-gnd voltages The zero-sequence voltage is calculated from the phase-to-ground voltages and used as a voltage input for all functions.
Page 206: Application And Setting Notes
Function-Group Types 5.2 Function-Group Type Voltage/current 1-Phase Operational Measured Values The operational measured values are not preconfigured in the Voltage-current 1-phase function group. You can instantiate them in the function group or delete them from the function group. You can find the opera- tional measured values in the DIGSI library, in the folder FG Voltage-current 1-phase under Measurements →...
Page 207: Write-Protected Settings
Function-Group Types 5.2 Function-Group Type Voltage/current 1-Phase Parameter: Rated current • Default setting (_:9421:101) Rated current = 1000 A The (_:9421:101) Rated current parameter is used to set the primary rated current of the protected object. The (_:9421:101) Rated current specified here is the reference value for the percentage-meas- ured values and setting values made in percentages.
Page 208: Information List
Function-Group Types 5.2 Function-Group Type Voltage/current 1-Phase Addr. Parameter Setting Options Default Setting Measurements • _:9421:150 General:P, Q sign not reversed not reversed • reversed Information List 5.2.6 Information Data Class Type (Type) General _:9421:52 General:Behavior _:9421:53 General:Health Group indicat. _:4501:55 Group indicat.:Pickup _:4501:57...
Page 209: Function-Group Type Voltage 3-Phase
Function-Group Types 5.3 Function-Group Type Voltage 3-Phase Function-Group Type Voltage 3-Phase Overview 5.3.1 In the Voltage 3-phase function group, all functions can be used for protecting and for monitoring a protected object or equipment which allows a 3-phase voltage measurement. The function group also contains the operational measurement for the protected object or equipment (on this topic, see chapter 10 Measured Values, Energy Values, and Supervision of the Primary System).
Page 210: Application And Setting Notes
Function-Group Types 5.3 Function-Group Type Voltage 3-Phase In this example, the pickup and operate indications of the protection functions are exchanged in the direction of the Circuit-breaker function group. You must connect the Voltage 3-phase function group with the Circuit-breaker function group. This assign- ment can be made in DIGSI only via Project tree →...
Page 211: Information List
Function-Group Types 5.3 Function-Group Type Voltage 3-Phase Information List 5.3.5 Information Data Class Type (Type) General _:9421:52 General:Behavior _:9421:53 General:Health Group indicat. _:4501:55 Group indicat.:Pickup _:4501:57 Group indicat.:Operate Reset LED FG _:4741:500 Reset LED Group:>LED reset _:4741:320 Reset LED Group:LED have been reset SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 212: Function-Group Type Capacitor Bank
You can find the Capacitor bank function group under 7SJ82/7SJ85 device types in the Global DIGSI 5 Library. The Capacitor bank function group contains all of the protection and supervision functions that you can use for this device type.
Page 213: Structure Of The Function Group
Function-Group Types 5.4 Function-Group Type Capacitor Bank Structure of the Function Group 5.4.2 The Capacitor bank function group always contains the following functionality: • Protected object/equipment data (function block General) • Operational measured values • Capacitor bank device status and blocking by discharging (function block General) •...
Page 214 Function-Group Types 5.4 Function-Group Type Capacitor Bank You can find more detailed information in Chapter 2. The Capacitor bank function group has the following 6 interfaces with the measuring points. The universal standard functions only work with the standard interfaces 3-phase current and/or 3-phase voltage; the other 4 interfaces are provided for the functions which are exclusively used for the capacitor banks.
Page 215 Function-Group Types 5.4 Function-Group Type Capacitor Bank [dwasscap-180713-01.tif, 2, en_US] Figure 5-15 An Example of Assignment of Measuring Points to the Capacitor-Bank Functions You can connect the Capacitor bank function group to the current and voltage measuring points via inter- faces.
Page 216 Function-Group Types 5.4 Function-Group Type Capacitor Bank [DwCapBank-180713-01, 4, en_US] Figure 5-17 Overview of the Protection Functions and Interface Assignment in the Capacitor Bank Function Group Interfaces with Circuit-Breaker Function Group All required data are exchanged between the protection function group and the Circuit-breaker function group via the interface with the Circuit-breaker function group.
Page 217 Function-Group Types 5.4 Function-Group Type Capacitor Bank NOTE For capacitor bank protection, the Automatic reclosing function is not applied in most cases. However, due to flexibility and standardization, the respective interface is offered. [scrconb1-180713-01.tif, 1, en_US] Figure 5-18 Connecting Capacitor Bank Function Group with Circuit-Breaker Function Group Besides the general assignment of the Capacitor bank function group to the Circuit-breaker function group, you can also configure the interface for certain functionalities in detail.
Page 218 Function-Group Types 5.4 Function-Group Type Capacitor Bank [Lo-CapZap-20140617-01, 1, en_US] Figure 5-20 Logic Diagram of Capacitor Bank Device Status and Blocking by Discharging The device can block the closing of the circuit breaker automatically when a capacitor bank discharges. The configuration is made with the parameter Blk.cls.cmd.dur.discharge.
Page 219 Function-Group Types 5.4 Function-Group Type Capacitor Bank Reset LED Group The Reset LED group function block allows you to reset only the stored LEDs of the functions contained in the respective function group, while stored LEDs activated from functions in other function groups remain active. For more information refer to chapter 3.1.10 Resetting Stored Indications of the Function Group Operational, Fundamental, Symmetrical Components Measurements...
Page 220 Function-Group Types 5.4 Function-Group Type Capacitor Bank Measured Values Primary Secondary % Referenced to Neutral-point phase current Rated operating current of the primary system Zero-sequence current Rated operating current of the primary seq:0 system Positive-sequence current Rated operating current of the primary seq:1 system Negative-sequence current...
Page 221: Application And Setting Notes
Function-Group Types 5.4 Function-Group Type Capacitor Bank [logepiin-230812-02.tif, 1, en_US] Figure 5-22 Generation of the Pickup Indication of the Capacitor Bank Function Group [logeopin-230812-02.tif, 1, en_US] Figure 5-23 Generation of the Operate Indication of the Capacitor Bank Function Group Application and Setting Notes 5.4.3 Interface to Circuit-Breaker Function Group The Capacitor bank protection function group is linked to one Circuit-breaker function group.
Page 222: Write-Protected Settings
Function-Group Types 5.4 Function-Group Type Capacitor Bank Depending on the user philosophy, the reference value could be the system rated voltage (bus voltage), or the capacitor rated voltage Parameter: Capacitor element type • Default setting (_:14641:106) Capacitor element type = fused With the parameter Capacitor element type, you set if the capacitor elements contain internal fuses or not.
Page 223: Settings
Function-Group Types 5.4 Function-Group Type Capacitor Bank Settings 5.4.5 Addr. Parameter Setting Options Default Setting Rated values _:14641:101 General:Capacitor refer- 1 A to 100000 A 1000 A ence curr. _:14641:102 General:Capacitor refer- 0.20 kV to 1200.00 kV 400.00 kV ence volt. Cap.bank data •...
Page 224: Function-Group Type Capacitor Bank Differential Protection
Function-Group Types 5.5 Function-Group Type Capacitor Bank Differential Protection Function-Group Type Capacitor Bank Differential Protection Function-Group Types 5.5.1 In the following graphic, you can see the structural association of the function-group types to the Capacitor bank differential protection. [dwfgueca-120214-01, 2, en_US] Figure 5-24 Function-Group Types Capacitor Bank Diff The following function-group types are summarized in the Global DIGSI 5 library: Motor diff...
Page 225: Function-Group Type Capacitor Bank Diff
Function-Group Types 5.5 Function-Group Type Capacitor Bank Differential Protection Capacitor Bank Diff 1 Side (2 to 3) Capacitor bank side 2 The individual function-group types are described in the following. 5.5.2 Function-Group Type Capacitor Bank Diff 5.5.2.1 Overview The Capacitor bank diff. function group contains the differential protection function and protection-function- relevant measured values.
Page 226: Structure Of The Function Group
Function-Group Types 5.5 Function-Group Type Capacitor Bank Differential Protection For more information about the embedding of the functions in the device, refer to chapter 2 Basic Structure of Function. For application templates of the various device types, refer to chapter Applications.
Page 227 Function-Group Types 5.5 Function-Group Type Capacitor Bank Differential Protection If an application template is used, the function groups are connected to each other because this link is abso- lutely essential to ensure proper operation. You can modify the connection in DIGSI 5 via the Function-group connections Editor.
Page 228: Information List
Function-Group Types 5.5 Function-Group Type Capacitor Bank Differential Protection [lo_geopi1-231013-01, 2, en_US] Figure 5-28 Generation of Operate Indication of the Capacitor Bank Diff. Function Group 5.5.2.3 Information List Information Data Class Type (Type) General _:91:52 General:Behavior _:91:53 General:Health Group indicat. _:4501:55 Group indicat.:Pickup _:4501:57...
Page 229: Structure Of The Function Group
Function-Group Types 5.5 Function-Group Type Capacitor Bank Differential Protection [scfgcasd-300414-01, 2, en_US] Figure 5-29 Capacitor Bank Side Function Group - Functional Scope For more information about the embedding of the functions in the device, refer to chapter 2 Basic Structure of Function.
Page 230 Function-Group Types 5.5 Function-Group Type Capacitor Bank Differential Protection [dw_fgcabsi-201114-01, 2, en_US] Figure 5-30 Structure of the Capacitor Bank Side Function Group The Capacitor bank side function group has interfaces to the following components: • Measuring points • Capacitor bank diff. function group •...
Page 231 Function-Group Types 5.5 Function-Group Type Capacitor Bank Differential Protection Interfaces to the Circuit-Breaker Function Group The interface with the Circuit-breaker function group is used to exchange all required data between the protection function group and the Circuit-breaker function group. The following data is required: •...
Page 232 Function-Group Types 5.5 Function-Group Type Capacitor Bank Differential Protection Operational Measured Values The operational measured values are always present in the Capacitor bank side function group and cannot be deleted. If a 3-phase voltage measuring point is connected, the following table shows the total scope. If only current is connected, only the first 3 lines apply.
Page 233 Function-Group Types 5.5 Function-Group Type Capacitor Bank Differential Protection NOTE With the P, Q sign parameter in the function block General, the sign of the following measured values of the respective function group can be inverted (see chapter 10.2 Structure of the Function Structure of the Function, section Inversion of Power-Related Measured and Statistical Values): •...
Page 234: Application And Setting Notes
Function-Group Types 5.5 Function-Group Type Capacitor Bank Differential Protection 5.5.3.3 Application and Setting Notes Interface to the Circuit-Breaker Function Group The Capacitor bank side function group is usually connected to 1 Circuit-breaker function group. The Circuit-breaker function group is assigned to the circuit breaker of the capacitor bank. Parameter: Rated apparent power •...
Page 235: Write-Protected Settings
Function-Group Types 5.5 Function-Group Type Capacitor Bank Differential Protection Phase-angle rota- 0° 30° 60° 90° 120° 150° 180° 210° 240° 270° 300° 330° tion Vector group numeral In the function group, the following information is displayed additionally in the setting sheet: •...
Page 236: Settings
Function-Group Types 5.5 Function-Group Type Capacitor Bank Differential Protection Addr. Parameter Range of Values Default Setting Side data • _:1781:14611:130 Side number not assigned Side 2 • Side 1 • Side 2 • Side 3 _:1781:14611:210 MI3ph1 usesMeasP with ID 0 to 100 _:1781:14611:215 CT mismatch M I-3ph 1...
Page 237: Function-Group Type Analog Units
Function-Group Types 5.6 Function-Group Type Analog Units Function-Group Type Analog Units Overview 5.6.1 The Analog units function group is used to map analog units and communicate with them. Analog units are external devices, such as RTD units, or analog plug-in modules, such as measuring-transducer modules. You will find the Analog units function group for many device types in the Global DIGSI 5 library.
Page 238 Function-Group Types 5.6 Function-Group Type Analog Units [dwstrthe-030615-01.vsd, 2, en_US] Figure 5-34 Structure of the Analog Unit Function Group Gray: Optionally Wired, optionally available White: Always wired, always available The Analog units function group has interfaces to protection function groups. The Analog units function group provides measured temperature values that come from an external RTD unit .
Page 239: 20-Ma Unit Ethernet
Function-Group Types 5.6 Function-Group Type Analog Units 20-mA Unit Ethernet 5.6.3 5.6.3.1 Overview The function 20-mA unit Ether.: • Communicates in series with a 20-mA unit via the Slave Unit Protocol (SUP) and records the values meas- ured by the 20-mA unit •...
Page 240: Communication With 20-Ma Unit Ethernet
Function-Group Types 5.6 Function-Group Type Analog Units 5.6.3.3 Communication with 20-mA Unit Ethernet Logic [lo20mtcp-150113-01.tif, 1, en_US] Figure 5-36 Logic of the Function 20-mA Unit Ethernet Communication with 20-mA Unit The function is used to communicate with a 20-mA unit connected via an Ethernet connection. When a connection of the function to an external 20-mA unit via an Ethernet interface has successfully been estab- lished, the 20-mA unit sends the measured values of all connected channels to the function 20-mA unit.
Page 241: Application And Setting Notes
The 7XV5674 20-mA unitis set with a web browser on the laptop computer via the latter's Ethernet interface. Set Modbus TCP as bus protocol/operating mode. You can find detailed notes on the settings in the 7XV5674 manual that accompanies the 20-mA unit. The documents are also available in the SIPROTEC download area http://www.energy.siemens.com. 5.6.3.5 20-mA Channel Logic [lo20mcha-160113-01.tif, 1, en_US]...
Page 242 Function-Group Types 5.6 Function-Group Type Analog Units If the setting Range active is set to test , the setting Transformation ratio is not displayed. If the setting Range active is set to false, the settings Upper limit, Transformation ratio upper limit, Lower limit and Transformation ratio are not displayed. Measured-Value Calculation The function 20-mA channel processes a single 20-mA current signal supplied by the 20-mA unit of the corre- sponding channel.
Page 243 Function-Group Types 5.6 Function-Group Type Analog Units If you activate the Range active setting, then 4 additional parameters Upper limit, Lower limit, Upper limit - Sensor, and Lower limit - Sensor appear. The parameters Upper limit and Lower limit indicate the range of the input current in mA. The setting Upper limit - Sensor is the calculated measured value if the input current corresponds to the value in the Upper limit setting.
Page 244: Application And Setting Notes
Function-Group Types 5.6 Function-Group Type Analog Units Table 5-11 Error Responses Error Description Status Error Status Health The input value lies outside the given limits Channel not connected 5.6.3.6 Application and Setting Notes Parameter: Unit • Default setting (_:13111:103) Unit = °C You use the setting Unit to specify which physical unit of measurement the measured values represent.
Page 245: Settings
Function-Group Types 5.6 Function-Group Type Analog Units 5.6.3.7 Settings Addr. Parameter Setting Options Default Setting General • _:2311:103 General:Port port E port J • port F • port J • port N • port P Channel 1 • _:13111:103 Channel 1:Unit •...
Page 246: Information List
Function-Group Types 5.6 Function-Group Type Analog Units Addr. Parameter Setting Options Default Setting • _:13111:107 Channel 1:Range active false • _:13111:104 Channel 1:Conversion 1 to 1000000 factor _:13111:105 Channel 1:Upper limit 0.00 mA to 20.00 mA 20.00 mA _:13111:109 Channel 1:Upper limit - -1000000 to 1000000 Sensor _:13111:106...
Page 247 Function-Group Types 5.6 Function-Group Type Analog Units A serial communication module optionally uses 2 channels. With the Channel number setting, you specify the channel number (1 or 2) used to connect the 20-mA unit to the device. The communication module inputs are labeled with the channel numbers.
Page 248: Settings
Function-Group Types 5.6 Function-Group Type Analog Units 5.6.4.3 Settings Addr. Parameter Setting Options Default Setting General • _:2311:103 General:Port port E port J • port F • port J • port N • port P _:2311:105 General:Channel number 1 to 2 _:2311:106 General:Slave address 1 to 247...
Page 249: Information List
Function-Group Types 5.6 Function-Group Type Analog Units Addr. Parameter Setting Options Default Setting • _:13111:108 Channel 1:Resolution • • 0.01 • 0.001 • _:13111:107 Channel 1:Range active false • _:13111:104 Channel 1:Conversion 1 to 1000000 factor _:13111:105 Channel 1:Upper limit 0.00 mA to 20.00 mA 20.00 mA _:13111:109...
Page 250 Function-Group Types 5.6 Function-Group Type Analog Units Adding a USART Module Add a USART-AB-1EL or a USART-AC-2EL USART module in DIGSI to the device. The USART module must be inserted at one of the plug-in positions for communication modules in the base module or in the CB202 expansion module (refer to the following figure).
Page 251 Function-Group Types 5.6 Function-Group Type Analog Units [scauser5-220114-01-DE, 1, en_US] Figure 5-45 Making the Communication Settings With the selection of the SUP protocol for the 20-mA unit DIGSI automatically adds the function group Analog units to your device configuration. You can now instantiate the function 20-mA unit serial 1 (see following figure).
Page 252: Integration Of A 20-Ma Unit Ethernet
Function-Group Types 5.6 Function-Group Type Analog Units [scauser7-220114-01-DE, 1, en_US] Figure 5-47 Setting the Port, Channel Number, and Device Address Finally, load the configuration in the device. 5.6.5.2 Integration of a 20-mA Unit Ethernet Device Configuration In DIGSI, insert an Ethernet module into the provided slot, thus, adding the module to the device configura- tion.
Page 253 Function-Group Types 5.6 Function-Group Type Analog Units [scautcp2-220114-01-DE, 1, en_US] Figure 5-49 Activation of the protocol This protocol is also available for Port J of the integrated Ethernet interface of the base module (refer to following figure). [scautcp3-220114-01-DE, 1, en_US] Figure 5-50 Selection of the Protocol With the selection of the SUP protocol for the 20-mA unit, DIGSI automatically adds the Analog units function...
Page 254: V/I-Measuring-Transducer Unit With Fast Inputs
Function-Group Types 5.6 Function-Group Type Analog Units [sc20tcp4-220114-01-DE, 1, en_US] Figure 5-51 Insertion of the Function 20-mA Unit Ether. 1 Now, set the port over which the SUP protocol runs. In addition, set the IP address of the 20-mA unit (refer to the following figure).
Page 255: Structure Of The Function
Function-Group Types 5.6 Function-Group Type Analog Units • Converts the measured current or voltage values into process values, for example, temperature, gas pres- sure, etc. • Provides the recorded process variables for further processing by the fault recorder, the CFC, and in GOOSE-applications for transmission via communication protocols, and for visualization The fast measuring-transducer inputs are located on the IO212 module with 8 inputs (optionally current or voltage inputs), and the IO210 module with 4 inputs (optionally current or voltage inputs).
Page 256: Application And Setting Notes
With the parameter Measuring window, you set the measuring window that is used to determine the arith- metic mean value from the sampled values. In case of slowly varying signals, Siemens recommends setting the top value to 100 ms. With this value, a new, current measured value is provided every 100 ms for further processing.
Page 257 Function-Group Types 5.6 Function-Group Type Analog Units Parameter: Range active • Default setting (_:107) Range active = false If you do not activate the Range active parameter, the function assumes a range of -20 mA to +20 mA or -10 V to +10 V. The setting of the range for the scaled value then assumes a usable range of -20 mA to +20 mA or -10 V to +10 V.
Page 258 Function-Group Types 5.6 Function-Group Type Analog Units [dw_measured-value-scaling, 1, en_US] Figure 5-55 Scaling Principle Setting Example 1: A measuring transducer transmitting a current signal of 4 mA to 20 mA is used as a transmitter. Currents well below 4 mA indicate a transmitter failure; currents around 0 mA indicate a broken wire. A sensor detecting a temperature is attached to the transmitter.
Page 259 Function-Group Types 5.6 Function-Group Type Analog Units [dw_measuring-transducer-characteristic, 1, en_US] Figure 5-56 Characteristic Curve of Setting Example 1 NOTE The hardware of the measuring transducer has been designed in such a way that measured values are transmitted and analyzed using the setting range (Upper limit orLower limit). Therefore, special applications are possible, if necessary.
Page 260: Settings
Function-Group Types 5.6 Function-Group Type Analog Units [dw_measuring-transducer-setting, 1, en_US] Figure 5-57 Parameter Settings and Representation of an Input Signal Greater than 10 V 5.6.6.5 Settings Addr. Parameter Setting Options Default Setting MT fast # • _:101 MT in #:TD input-signal Voltage input Current input •...
Page 261 Function-Group Types 5.6 Function-Group Type Analog Units Addr. Parameter Setting Options Default Setting • _:103 MT in #:Unit • ° • °C • °F • Ω • Ω/km • Ω/mi • • • • cos φ • cycles • • F/km •...
Page 262: Information List
Function-Group Types 5.6 Function-Group Type Analog Units Addr. Parameter Setting Options Default Setting _:110 MT in #:Lower limit - -1000000.00 to 1000000.00 1.00 Sensor 5.6.6.6 Information List Information Data Class Type (Type) MT in # _:302 MT in #:TD scale MV _:306 MT in #:TD scale SAV 5.6.7...
Page 263: Communication With An Rtd Unit
Function-Group Types 5.6 Function-Group Type Analog Units 5.6.7.3 Communication with an RTD Unit Logic [lortdtcp-311012-01.tif, 1, en_US] Figure 5-59 Logic of the RTD Unit Ether. Function Communication with an RTD Unit The function is used to communicate with an RTD box connected via an Ethernet connection. If the connec- tion of the function is successfully established to the external RTD box via the Ethernet interface, the RTD box transmits the temperatures of all connected sensors to the RTD box Ether.
Page 264: Application And Setting Notes
Function-Group Types 5.6 Function-Group Type Analog Units Error Description Status Health A communication module has not received any more Warning data from the RTD unit for 9 sec. Failure signal is set as soon as one of the sensor function blocks reports a failure. 5.6.7.4 Application and Setting Notes Parameter: Port...
Page 265: Temperature Sensor
Function-Group Types 5.6 Function-Group Type Analog Units 5.6.7.5 Temperature Sensor Logic [lotmpval-311012-01.tif, 1, en_US] Figure 5-60 Logic Diagram of the Temperature Sensor Function Block Measured Temperature Value The Temperature sensor function block processes one single measured temperature value delivered from the RTD unit for the assigned sensor.
Page 266: Settings
Function-Group Types 5.6 Function-Group Type Analog Units Parameter: Temperature unit To change the display and evaluation of measured temperature values from °C to °F, adapt the DIGSI user default settings accordingly. Proceed as follows: • In DIGSI select the menu item Extras --> Settings. •...
Page 267: Rtd Unit, Serial
Function-Group Types 5.6 Function-Group Type Analog Units Information Data Class Type (Type) Sensor 1 _:11611:52 Sensor 1:Health _:11611:60 Sensor 1:Failure _:11611:80 Sensor 1:TmpOut RTD Unit, Serial 5.6.8 5.6.8.1 Overview The RTD unit serial function: • Communicates with an external RTD unit serial via the Slave Unit Protocol (SUP) and records the meas- ured temperatures from the RTD unit •...
Page 268: Settings
Function-Group Types 5.6 Function-Group Type Analog Units 5.6.8.3 Settings Addr. Parameter Setting Options Default Setting General • _:2311:103 General:Port port F port J • port E • port P • port N • port J _:2311:105 General:Channel number 1 to 2 _:2311:106 General:Slave address 1 to 254...
Page 269: Information List
Function-Group Types 5.6 Function-Group Type Analog Units Addr. Parameter Setting Options Default Setting Sensor 11 • _:11611:102 Sensor 11:Sensor type Pt 100 Pt 100 • Ni 100 • Ni 120 Sensor 12 • _:11611:102 Sensor 12:Sensor type Pt 100 Pt 100 •...
Page 270: Communication With Rtd Unit
Function-Group Types 5.6 Function-Group Type Analog Units Information Data Class Type (Type) Sensor 9 _:11619:52 Sensor 9:Health _:11619:60 Sensor 9:Failure _:11619:80 Sensor 9:TmpOut Sensor 10 _:11611:52 Sensor 10:Health _:11611:60 Sensor 10:Failure _:11611:80 Sensor 10:TmpOut Sensor 11 _:11611:52 Sensor 11:Health _:11611:60 Sensor 11:Failure _:11611:80 Sensor 11:TmpOut...
Page 271 Function-Group Types 5.6 Function-Group Type Analog Units [scauser3-190214-01, 1, en_US] Figure 5-63 Insertion Position for a USART Module Selecting the SUP Protocol Select the Slave Unit Protocol (SUP). This protocol is responsible for the communication between the SIPROTEC 5 device and the RTD Unit. [scauser4-220114-01-DE, 1, en_US] Figure 5-64 Selecting the SUP Protocol...
Page 272 Function-Group Types 5.6 Function-Group Type Analog Units [scauser5-220114-01-DE, 1, en_US] Figure 5-65 Making the Communication Settings With the selection of the SUP protocol for the RTD box DIGSI automatically adds the function group Analog units to your device configuration. You can now instantiate the function RTD box serial 1 (refer to the following figure).
Page 273: Integration Of An Rtd-Unit Ethernet (Tr1200 Ip)
Function-Group Types 5.6 Function-Group Type Analog Units [scauser7-220114-01-DE, 1, en_US] Figure 5-67 Setting the Port, Channel Number, and Slave Address Finally, load the configuration in the device. 5.6.9.2 Integration of an RTD-Unit Ethernet (TR1200 IP) Device Configuration In the DIGSI, insert an Ethernet module into the provided slot, thus, adding the module to the device configu- ration.
Page 274 Function-Group Types 5.6 Function-Group Type Analog Units [scautcp2-220114-01-DE, 1, en_US] Figure 5-69 SUP Ethernet Protocol Activation This protocol is also available for Port J of the integrated Ethernet interface of the base module (refer to following figure). [scautcp3-220114-01-DE, 1, en_US] Figure 5-70 SUP Ethernet Protocol Activation (base module) With the selection of the SUP protocol for the RTD unit, DIGSI automatically adds the Analog units function...
Page 275: Temperature Simulation Without Sensors
Function-Group Types 5.6 Function-Group Type Analog Units [scauser6-190214-01, 1, en_US] Figure 5-71 Analog Unit Instance Now, set the port over which the SUP protocol runs. In addition, set the IP address of the RTD box (refer to the following figure). This address must be set with the same value in the RTD box. [scautcp5-220114-01-DE, 1, en_US] Figure 5-72 Setting the Port and IP Address...
Page 276: Function-Group Type Circuit Breaker
Function-Group Types 5.7 Function-Group Type Circuit Breaker Function-Group Type Circuit Breaker Overview 5.7.1 The Circuit-breaker function group combines all the user functions that relate to a circuit breaker. You will find the Circuit-breaker function group under each device type in the function library in DIGSI 5. The Circuit-breaker function group contains all of the protection, control, and supervision functions that you can use for this device type.
Page 277: Structure Of The Function Group
Function-Group Types 5.7 Function-Group Type Circuit Breaker The circuit breaker [status only] is used only for acquiring the circuit-breaker switch position. This type can be used to model switches that can only be read but not controlled by the SIPROTEC 5 device. The available functions are described in the chapters 6 Protection and Automation Functions 8 Control...
Page 278: Application And Setting Notes
Function-Group Types 5.7 Function-Group Type Circuit Breaker If an application template is used, the function group is connected to the measuring point of the 3-phase current because this connection is essential. It can be necessary to connect additional measuring points to the function group, depending on the nature of the user functions used.
Page 279: Settings
0.05 A for example. If no special requirements exist, Siemens recommends retaining the setting value of 0.10 A for secondary purposes.
Page 280: Information List
Function-Group Types 5.7 Function-Group Type Circuit Breaker Addr. Parameter Setting Options Default Setting Breaker settings _:2311:112 General:Current thresh. 1 A @ 100 Irated 0.030 A to 10.000 A 0.100 A CB open 5 A @ 100 Irated 0.15 A to 50.00 A 0.50 A 1 A @ 50 Irated 0.030 A to 10.000 A...
Page 281: Trip Logic
Function-Group Types 5.7 Function-Group Type Circuit Breaker Trip Logic 5.7.6 5.7.6.1 Function Description The Trip logic function block receives the group operate indication from the Protection function group or Protection function groups and forms the protection trip command that is transmitted to the Circuit-breaker function block.
Page 282: Application And Setting Notes
Function-Group Types 5.7 Function-Group Type Circuit Breaker • with I< & aux.contact For these criteria, the state of the circuit breaker is also taken into account as a further criterion in addi- tion to the dropout of the tripping function (operate indication is reset by command). You can select whether the state is determined by means of the current (with I<) or by means of the current in conjunction with the circuit-breaker auxiliary contacts (with I<...
Page 283: Circuit Breaker
Function-Group Types 5.7 Function-Group Type Circuit Breaker Circuit Breaker 5.7.7 5.7.7.1 Overview The Circuit-breaker function block represents the physical switch in the SIPROTEC 5 device. The basic tasks of this function block are the operation of the circuit breaker and the acquisition of the circuit- breaker auxiliary contacts and other circuit-breaker information.
Page 284: Acquisition Of Circuit-Breaker Auxiliary Contacts And Further Information
Function-Group Types 5.7 Function-Group Type Circuit Breaker Table 5-14 Description of the Output Signals Signal Description Routing Options • This signal executes all tripping and opening operations. Unlatched Trip/open • Only saved cmd. The Output time parameter affects the signal. in the event The signal is pending for the duration of this period, with the following of protec-...
Page 285: Definitive Tripping, Circuit-Breaker Tripping Alarm Suppression
Function-Group Types 5.7 Function-Group Type Circuit Breaker Signal Type Description Acquisition of the circuit-breaker position Position The position 3-pole circuit breaker open and/or the position 3-pole circuit breaker closed can be acquired by routing to 1 or 2 binary inputs. The signals must be routed to the binary input that is connected with the CB auxiliary contacts.
Page 286: Tripping And Opening Information
Function-Group Types 5.7 Function-Group Type Circuit Breaker tripping or if it is to be closed or opened via the control. The alarm is only to be issued in the event of final tripping. Depending on how the alarm is generated (for example, triggered by a fleeting contact of the circuit breaker), the Alarm suppression signal can be used to suppress the alarm.
Page 287: Application And Setting Notes
Control function block The operating principle of the auxiliary contacts is described in the individual functions. Siemens recommends capturing the Circuit breaker is open in 3 poles and Circuit breaker is closed in 3 poles information via auxiliary contacts. This is the optimal configuration for the SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 288 Function-Group Types 5.7 Function-Group Type Circuit Breaker control functionality. For purely protection applications, it is also enough to capture just one of the 2 circuit- breaker positions. [loauswer-230311-01.tif, 1, en_US] Figure 5-83 Recommended Analysis of the Circuit-Breaker Switch Position when Used as a Protection and Control Device The following diagram shows the recommended routing, in which H stands for active with voltage.
Page 289 Function-Group Types 5.7 Function-Group Type Circuit Breaker Parameter Value Description With this setting, the measured values are reported if the circuit breaker is always opened either via the control function or the trip command of a protection function. With this setting, the measured values are only reported if the circuit with trip breaker is opened via the trip command of a protection function.
Page 290: Settings
Function-Group Types 5.7 Function-Group Type Circuit Breaker 5.7.7.7 Settings Addr. Parameter Setting Options Default Setting Circuit break. _:101 Circuit break.:Output 0.02 s to 1800.00 s 0.10 s time • _:105 Circuit break.:Indicat. of with trip always • breaking values always 5.7.7.8 Information List Information...
Page 291: Detection Manual Closure (For Arec And Process Monitor)
Function-Group Types 5.7 Function-Group Type Circuit Breaker This information is needed in the following protection-related additional functions: • Trip logic (see 5.7.6.1 Function Description) • Detection of manual closing (see 5.7.9.1 Function Description) • Process monitor (Standard V/I) 5.8 Process Monitor) Its use is described in the respective chapters.
Page 292: Application And Setting Notes
Function-Group Types 5.7 Function-Group Type Circuit Breaker [lohand3p-101210-01.tif, 3, en_US] Figure 5-87 Logic for Manual Closure Detection External Manual Closure An external manual closure is communicated to the device via the input signal >Input. The input signal can also be connected directly to the control circuit of the circuit-breaker closing coil. For this reason, detection is suppressed in the event of a close command by the AREC function.
Page 293: Settings
In order to ensure independence from manual activation of the input signal, the detection function is extended for a defined length of time using the parameter Action time. Siemens recommends an action time of 300 ms. Parameter: CB open dropout delay •...
Page 294: Process Monitor
Function-Group Types 5.8 Process Monitor Process Monitor Overview of Functions 5.8.1 All function groups that have functions with dependencies on the state of the protected object contain a process monitor. The process monitor detects the current state of the protected object. Structure of the Function 5.8.2 The Process monitor function is used in the Standard V/I 3-phase protection function group.
Page 295: Current-Flow Criterion
Function-Group Types 5.8 Process Monitor [lopro3pt-171012-01.tif, 2, en_US] Figure 5-90 Logic Diagram of the Overall Function Process Monitor 5.8.3 Current-Flow Criterion [loproikr-011112-01.tif, 2, en_US] Figure 5-91 Logic Diagram of the Current-Flow Criterion Function Block The phase currents are provided via the interface to the protection function group. The I open signal of one phase is generated if one of the following conditions is met: •...
Page 296: Application And Setting Notes (Current-Flow Criterion)
If parasitic currents, for example, due to induction, are ruled out when the feeder is deactivated, set the Current thresh. CB open parameter sensitively. Siemens recommends a setting value of 0.100 A. Circuit-Breaker Condition for the Protected Object 5.8.5 Logic [loprolsz-140611-01.tif, 2, en_US]...
Page 297: Closure Detection
Function-Group Types 5.8 Process Monitor If the following 2 conditions are met, the CB pos. recogn. prot. obj. signal is in the Closed state: • At least one of the connected circuit breakers signals the Closed state internally. • The >Disconnector open input is not active. 5.8.6 Closure Detection The closure detection enables the immediate tripping of selected protection functions or protection stages...
Page 298: Cold-Load Pickup Detection (Optional)
Function-Group Types 5.8 Process Monitor Cold-Load Pickup Detection (Optional) 5.8.8 Logic [loprocls-180912-01.tif, 1, en_US] Figure 5-94 Logic Diagram of the Cold-Load Pickup Detection Function Block The Cold-load pickup detection function block detects that a specific time has been exceeded after deactiva- tion of the line or protected object.
Page 299: Application And Setting Notes (Cold-Load Pickup Detection)
Function-Group Types 5.8 Process Monitor If, for the time set in the Dropout delay curr.crit. parameter, the maximum phase current falls below the threshold value Dropout threshold current, the parameter set for the Cold-load pickup detection function block is also deactivated. As a result, if the load current is very low, the action time Dropout delay curr.crit.
Page 300: Settings
Function-Group Types 5.8 Process Monitor Settings 5.8.10 Addr. Parameter Setting Options Default Setting Cold-load PU • Cold-load PU:Mode • • test • _:101 Cold-load PU:Operating I open I open • mode CB and I open _:102 Cold-load PU:Dropout 1 A @ 100 Irated 0.030 A to 10.000 A 1.000 A threshold current 5 A @ 100 Irated 0.15 A to 50.00 A...
Page 301: Protection And Automation Functions
Protection and Automation Functions Power-System Data Group Indications of Overcurrent Protection Functions Overcurrent Protection, Phases Voltage-Dependent Overcurrent Protection, Phases Overcurrent Protection, Ground Directional Overcurrent Protection, Phases Directional Overcurrent Protection, Ground Inrush-Current Detection Instantaneous High-Current Tripping 6.10 Arc Protection 6.11 Instantaneous Tripping at Switch onto Fault 6.12 Overcurrent Protection, 1-Phase 6.13...
Page 302 Protection and Automation Functions 6.35 Rate of Frequency Change Protection 6.36 Vector-Jump Protection 6.37 Power Protection (P,Q), 3-Phase 6.38 Reverse-Power Protection 6.39 Overexcitation Protection 6.40 Undervoltage-Controlled Reactive-Power Protection 6.41 Circuit-Breaker Failure Protection 6.42 Circuit-Breaker Restrike Protection 6.43 Restricted Ground-Fault Protection 6.44 External Trip Initiation 3-Pole 6.45...
Page 303: Power-System Data
Protection and Automation Functions 6.1 Power-System Data Power-System Data Overview 6.1.1 The Power-system data are provided with each SIPROTEC 5 device and cannot be deleted. You will find them in DIGSI under Settings → Power-system data. Structure of the Power-System Data 6.1.2 The Power-system data contain the block General and the Measuring points of the device.
Page 304: Application And Setting Notes For Measuring Point Current 3-Phase (I-3Ph)
If possible, only the 3-phase measuring points shall be considered. Siemens recommends using the default setting. Note: If the parameter Tracking = active , the determined sampling frequency applies to all functions in the device not using fixed sampling rates.
Page 305 Parameter: Current range • Default setting 7SJ82 (_:8881:117) Current range = 50 x IR • Default setting 7SJ85 (_:8881:117) Current range = 100 x IR The Current range parameter allows you to set the dynamic range for the current input. Please retain the default setting for power-system protection applications.
Page 306: Application And Setting Notes For Measuring Point Current 1-Phase (I-1Ph)
Siemens recommends routing both measured values as fault-recording channel. Application and Setting Notes for Measuring Point Current 1-Phase (I-1ph) 6.1.5 If you insert a Measuring point I 1-ph in DIGSI 5, you must route a current to the measuring point under Name of the device →...
Page 307: Application And Setting Notes For Measuring Point Voltage 3-Phase (V-3Ph)
Protection and Automation Functions 6.1 Power-System Data Parameter: Term. 1,3,5,7 in dir. of obj. • Default setting (_:2311:116) Term. 1,3,5,7 in dir. of obj. = yes With the Term. 1,3,5,7 in dir. of obj. parameter, you define the direction of the current. If you set the parameter Term.
Page 308 Protection and Automation Functions 6.1 Power-System Data NOTE The measurement residual voltage V is converted to a zero-sequence voltage in the device as follows: N sec EXAMPLE 1: [dw_bsp1uwdl_anpassfaktor, 2, en_US] Figure 6-3 3-Phase Voltage Transformer: Connection = 3 Phase-to-Ground Voltage + VN If the connection type of the voltage transformer is 3 ph-to-gnd volt.
Page 309 Protection and Automation Functions 6.1 Power-System Data Broken-delta winding (for = 500 V rated sec example, grounding trans- The voltage input of the device is designed for a continuous operation, former in generator protection) using 230 V max. Therefore, the voltage on the broken-delta winding (500 V) is reduced to a 5:2 ratio, using an Ohmic divider.
Page 310 If possible, only the 3-phase measuring points shall be considered. Siemens recommends using the default setting. Note: If the parameter Tracking = active , the determined sampling frequency applies to all functions in the device not using fixed sampling rates.
Page 311: Application And Setting Notes For Measuring Point Voltage 1-Phase (V-1Ph)
Protection and Automation Functions 6.1 Power-System Data Application and Setting Notes for Measuring Point Voltage 1-Phase (V-1ph) 6.1.7 If you insert a Measuring point V 1-ph in DIGSI 5, you must route a voltage to the measuring point under Name of the device → Measuring-points routing → Voltage-measuring points. You can route the following voltages: •...
Page 312: Settings
Protection and Automation Functions 6.1 Power-System Data the device switches to another channel (etc.). Once switched to a current channel, the system automatically switches back to the voltage channel if a voltage channel is valid again. Parameter Value Description If the channels of the measuring point are not to be considered for deter- inactive mining the sampling frequency, please select the setting value inactive.
Page 313 Protection and Automation Functions 6.1 Power-System Data Addr. Parameter Setting Options Default Setting • _:8881:102 CT 3-phase:Rated secon- • dary current • _:8881:117 CT 3-phase:Current 1.6 x IR 100 x IR • range 100 x IR • 50 x IR •...
Page 314 Protection and Automation Functions 6.1 Power-System Data Addr. Parameter Setting Options Default Setting CT 2 _:3842:103 CT 2:Magnitude correc- 0.010 to 10.000 1.000 tion • _:3842:117 CT 2:Phase • • • • INsens • _:3842:116 CT 2:Sequence number 1 to 2147483647 2147483647 device CT 3...
Page 315 Protection and Automation Functions 6.1 Power-System Data Addr. Parameter Setting Options Default Setting Supv. ph.seq.I • _:2551:1 Supv. ph.seq.I:Mode • • test _:2551:6 Supv. ph.seq.I:Delay 0.00 s to 100.00 s 5.00 s supervision alarm Supv. sum I • _:2431:1 Supv. sum I:Mode •...
Page 316 Protection and Automation Functions 6.1 Power-System Data Addr. Parameter Setting Options Default Setting • _:3841:117 CT 1:Phase • • • • INsens • Measuring Point V-3ph Addr. Parameter Setting Options Default Setting General _:8911:101 VT 3-phase:Rated 0.200 kV to 1200.000 kV 400.000 kV primary voltage _:8911:102...
Page 317 Protection and Automation Functions 6.1 Power-System Data Addr. Parameter Setting Options Default Setting • _:3812:108 VT 2:Phase • • • V AB • V BC • V CA • • • VT 3 _:3813:103 VT 3:Magnitude correc- 0.010 to 10.000 1.000 tion •...
Page 318: Information List
Protection and Automation Functions 6.1 Power-System Data Addr. Parameter Setting Options Default Setting _:2461:3 Supv. sum V:Threshold 0.300 V to 170.000 V 25.000 V _:2461:6 Supv. sum V:Delay 0.00 s to 100.00 s 5.00 s supervision alarm VT miniatureCB _:2641:101 VT minia- 0.00 s to 0.03 s 0.00 s...
Page 319 Protection and Automation Functions 6.1 Power-System Data Information Data Class Type (Type) _:2311:321 General:Freq.out of oper.range _:2311:322 General:f sys _:2311:323 General:f track Measuring Point I-3ph Information Data Class Type (Type) General _:8881:319 CT 3-phase:Phases AB inverted _:8881:320 CT 3-phase:Phases BC inverted _:8881:321 CT 3-phase:Phases AC inverted CT 1...
Page 320 Protection and Automation Functions 6.1 Power-System Data Information Data Class Type (Type) _:2431:54 Supv. sum I:Inactive _:2431:52 Supv. sum I:Behavior _:2431:53 Supv. sum I:Health _:2431:71 Supv. sum I:Failure Supv.ADC sum I _:2401:82 Supv.ADC sum I:>Block function _:2401:54 Supv.ADC sum I:Inactive _:2401:52 Supv.ADC sum I:Behavior _:2401:53...
Page 321 Protection and Automation Functions 6.1 Power-System Data Information Data Class Type (Type) _:2581:53 Supv. ph.seq.V:Health _:2581:71 Supv. ph.seq.V:Failure Supv. sum V _:2461:82 Supv. sum V:>Block function _:2461:54 Supv. sum V:Inactive _:2461:52 Supv. sum V:Behavior _:2461:53 Supv. sum V:Health _:2461:71 Supv. sum V:Failure Definite-T 1 _:2641:500 VT miniatureCB:>Open...
Page 322: Group Indications Of Overcurrent Protection Functions
Protection and Automation Functions 6.2 Group Indications of Overcurrent Protection Functions Group Indications of Overcurrent Protection Functions Description 6.2.1 The function block Group indications of the overcurrent protection functions uses the pickup and operate indications of the following functions: • Overcurrent Protection, Phases •...
Page 323: Overcurrent Protection, Phases
Protection and Automation Functions 6.3 Overcurrent Protection, Phases Overcurrent Protection, Phases Overview of Functions 6.3.1 The Overcurrent protection, phases function (ANSI 50/51): • Detects short circuits in electrical equipment • Can be used as backup overcurrent protection in addition to the main protection 6.3.2 Structure of the Function The Overcurrent protection, phases function is used in protection function groups.
Page 324 Protection and Automation Functions 6.3 Overcurrent Protection, Phases [dw_ocp_ad with Filter.tif, 2, en_US] Figure 6-5 Structure/Embedding of the Function Overcurrent Protection, Phases – Advanced [dwocpbp1-210113-01.tif, 3, en_US] Figure 6-6 Structure/Embedding the Function Overcurrent Protection, Phases – Basic If the device-internal functions listed in the following are present in the device, these functions can influence the pickup values and tripping delays of the stages or block the stages.
Page 325: Filter For Rms Value Gain
Protection and Automation Functions 6.3 Overcurrent Protection, Phases Filter for RMS Value Gain 6.3.3 6.3.3.1 Description The function block Filter can be used to adapt the RMS value for 2 means: • To gain harmonics in a defined way. Higher harmonics can stress the protected object thermally more than lower harmonics.
Page 326: Application And Setting Notes
Protection and Automation Functions 6.3 Overcurrent Protection, Phases Values Description Primary Secondary % Referenced to Iph:C Gained RMS measured Parameter Rated current value of current C You can find the parameter Rated current in the FB General of function groups where the Overcurrent protection, phases –...
Page 327: Settings
Protection and Automation Functions 6.3 Overcurrent Protection, Phases 6.3.3.3 Settings Addr. Parameter Setting Options Default Setting Filter • Filter:Enable filter • Filter:h(0) -100.000 to 100.000 0.000 Filter:h(1) -100.000 to 100.000 0.000 Filter:h(2) -100.000 to 100.000 0.000 Filter:h(3) -100.000 to 100.000 0.000 Filter:h(4) -100.000 to 100.000...
Page 328: Stage With Definite-Time Characteristic Curve
Protection and Automation Functions 6.3 Overcurrent Protection, Phases Stage with Definite-Time Characteristic Curve 6.3.4 6.3.4.1 Description Logic of the Basic Stage [loocp3b1-280113-01.tif, 3, en_US] Figure 6-8 Logic Diagram of the Definite-Time Overcurrent Protection (Phases) – Basic SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 329 Protection and Automation Functions 6.3 Overcurrent Protection, Phases Logic of the Advanced Stage [lo_OCP_Adv_UMZ_StageControl, 1, en_US] Figure 6-9 Logic Diagram of the Stage Control SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 330 Protection and Automation Functions 6.3 Overcurrent Protection, Phases [loocp3p1-310511-01.tif, 4, en_US] Figure 6-10 Logic Diagram of the Definite-Time Overcurrent Protection (Phases) – Advanced Method of measurement (Basic and Advanced Stage) You use the Method of measurement parameter to define whether the stage uses the fundamental comp.
Page 331 Protection and Automation Functions 6.3 Overcurrent Protection, Phases If the function block Filter is configured and if you have enabled the filter, the gained RMS value is automati- cally used. NOTE When the function block Filter is applied, only one 3-phase current measuring point is allowed to be connected to the 3-phase current interface of the function group.
Page 332: Application And Setting Notes
Select this method of measurement if harmonics or transient current peaks fundamental comp. are to be suppressed. Siemens recommends using this method as the standard method. Select this method of measurement if you want the stage to take harmonics RMS value into account (for example, at capacitor banks).
Page 333 Set the Operate delay parameter to 0 or to a low value. Siemens recommends that the threshold values be determined with a system analysis. The following example illustrates the principle of grading with a current threshold on a long line.
Page 334 Protection and Automation Functions 6.3 Overcurrent Protection, Phases Ratio of zero-sequence impedance and positive-sequence impedance of the source impedance at the beginning of the line: Z Current transformer = 600 A/5 A Resulting in the following values for the line impedance Z and the source impedance Z [fo_OCP002_030311, 1, en_US] [fo_OCP003_030311, 1, en_US]...
Page 335: Settings
Default setting (_:661:101) Dropout delay = 0.00 s This parameter is not visible in the basic stage. Siemens recommends using the default setting 0 since the dropout of a protection stage must be done as fast as possible. You can use the Dropout delay parameter ≠ 0 to obtain a uniform dropout behavior if you use it together with an electromechanical relay.
Page 336 Protection and Automation Functions 6.3 Overcurrent Protection, Phases Addr. Parameter Setting Options Default Setting _:661:3 Definite-T 1:Threshold 1 A @ 100 Irated 0.030 A to 35.000 A 1.500 A 5 A @ 100 Irated 0.15 A to 175.00 A 7.50 A 1 A @ 50 Irated 0.030 A to 35.000 A 1.500 A...
Page 337 Protection and Automation Functions 6.3 Overcurrent Protection, Phases Addr. Parameter Setting Options Default Setting _:661:16 Definite-T 1:Threshold 1 A @ 100 Irated 0.030 A to 35.000 A 1.500 A 5 A @ 100 Irated 0.15 A to 175.00 A 7.50 A 1 A @ 50 Irated 0.030 A to 35.000 A 1.500 A...
Page 338: Information List
Protection and Automation Functions 6.3 Overcurrent Protection, Phases 6.3.4.4 Information List Information Data Class Type (Type) Group indicat. _:4501:55 Group indicat.:Pickup _:4501:57 Group indicat.:Operate Definite-T 1 _:661:81 Definite-T 1:>Block stage _:661:84 Definite-T 1:>Activ. dyn. settings _:661:500 Definite-T 1:>Block delay & op. _:661:54 Definite-T 1:Inactive _:661:52...
Page 339: Stage With Inverse-Time Characteristic Curve
Protection and Automation Functions 6.3 Overcurrent Protection, Phases Stage with Inverse-Time Characteristic Curve 6.3.5 6.3.5.1 Description Logic of the Basic Stage [loocp3b2-280113-01.tif, 2, en_US] Figure 6-13 Logic Diagram of the Inverse-Time Overcurrent Protection (Phases) – Basic SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 340 Protection and Automation Functions 6.3 Overcurrent Protection, Phases Logic of the Advanced Stage [lo_Stage Control, 1, en_US] Figure 6-14 Logic Diagram of the Stage Control [loocp3p2-310511-01.tif, 4, en_US] Figure 6-15 Logic Diagram of the Inverse-Time Overcurrent Protection (Phases) – Advanced SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 341 Protection and Automation Functions 6.3 Overcurrent Protection, Phases RMS-Value Selection (Advanced Stage) If RMS value is selected as the method of measurement, the protection function supports 2 kinds of RMS measurement. • Normal RMS value • Gained RMS value from the function block Filter If the function block Filter is configured and if you have enabled the filter, the gained RMS value is automati- cally used.
Page 342 Protection and Automation Functions 6.3 Overcurrent Protection, Phases Additional Time Delay (Advanced Stage) With the parameter Additional time delay, you define a definite-time delay in addition to the inverse- time delay. With this setting, the whole curve is shifted on the time axis by this additional definite time. Method of Measurement (Basic and Advanced Stage) You use the Method of measurement parameter to define whether the stage uses the fundamental comp.
Page 343: Application And Setting Notes
(standard method) or the calculated RMS value. Parameter Value Description Select this method of measurement if harmonics or transient current peaks fundamental comp. are to be suppressed. Siemens recommends using this method as the standard method. SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 344 0 s, this parameter has no effect on the inverse-time characteristic curve. This parameter is only required for time coordination in recloser schemes. For all other applications, Siemens recommends keeping the default setting of 0 s.
Page 345 Protection and Automation Functions 6.3 Overcurrent Protection, Phases EXAMPLE Overcurrent-protection stage: 110-kV overhead line, 150 mm cross-section Maximum transmittable power = 120 MVA Correspondingly = 630 A Current transformer = 600 A/5 A Settings in primary and secondary values result in the setting values: [foocp005-030311-01.tif, 2, en_US] Parameter: I0 elimination •...
Page 346: Settings
Protection and Automation Functions 6.3 Overcurrent Protection, Phases Parameter Value Description Select this setting if the device is coordinated with electromechanical disk emulation devices or other devices which perform a dropout after a disk emulation. Select this setting if the dropout is not to be performed after disk emulation instantaneous and an instantaneous dropout is desired instead.
Page 347 Protection and Automation Functions 6.3 Overcurrent Protection, Phases Addr. Parameter Setting Options Default Setting Dyn.s: AR off/n.rdy • _:691:28 Inverse-T 1:Effect. by AR • off/n.ready • _:691:35 Inverse-T 1:Stage • blocked Dyn.set: AR cycle 1 • _:691:29 Inverse-T 1:Effected by •...
Page 348: Information List
Protection and Automation Functions 6.3 Overcurrent Protection, Phases Addr. Parameter Setting Options Default Setting _:691:17 Inverse-T 1:Threshold 1 A @ 100 Irated 0.030 A to 35.000 A 1.500 A 5 A @ 100 Irated 0.15 A to 175.00 A 7.50 A 1 A @ 50 Irated 0.030 A to 35.000 A 1.500 A...
Page 349: Stage With User-Defined Characteristic Curve
Protection and Automation Functions 6.3 Overcurrent Protection, Phases Information Data Class Type (Type) _:691:57 Inverse-T 1:Operate 6.3.6 Stage with User-Defined Characteristic Curve 6.3.6.1 Description This stage is only available in the advanced function type. This stage is structured the same way as the Inverse-time overcurrent protection – advanced stage (see chapter 6.3.5.1 Description ).
Page 350: Application And Setting Notes
The setting depends on the characteristic curve you want to realize. Set the current value as a multiple of the threshold value. Siemens recommends that you set the Threshold parameter to 1.00 in order to obtain a simple relation. You can change the threshold value setting afterwards if you want to shift the characteristic curve.
Page 351: Settings
The setting depends on the characteristic curve you want to realize. Set the current value as a multiple of the threshold value. Siemens recommends that you set the Threshold parameter to 1.00 in order to obtain a simple relation. You can change the threshold value setting afterwards if you want to shift the characteristic curve.
Page 352 Protection and Automation Functions 6.3 Overcurrent Protection, Phases Addr. Parameter Setting Options Default Setting • _:27 User curve #:Blk. w. • inrush curr. detect. • User curve #:Method of fundamental comp. fundamental • measurement RMS value comp. • _:120 User curve #:I0 elimina- •...
Page 353 Protection and Automation Functions 6.3 Overcurrent Protection, Phases Addr. Parameter Setting Options Default Setting _:15 User curve #:Threshold 1 A @ 100 Irated 0.030 A to 35.000 A 1.500 A 5 A @ 100 Irated 0.15 A to 175.00 A 7.50 A 1 A @ 50 Irated 0.030 A to 35.000 A...
Page 354: Information List
Protection and Automation Functions 6.3 Overcurrent Protection, Phases Addr. Parameter Setting Options Default Setting _:19 User curve #:Threshold 1 A @ 100 Irated 0.030 A to 35.000 A 1.500 A 5 A @ 100 Irated 0.15 A to 175.00 A 7.50 A 1 A @ 50 Irated 0.030 A to 35.000 A...
Page 355: Application And Setting Notes
Protection and Automation Functions 6.3 Overcurrent Protection, Phases [loocp3pha-210812-01.vsd, 1, en_US] Figure 6-20 Part-Logic Diagram on the Influence of Inrush-Current Detection Exemplified by the 1st Defi- nite-Time Overcurrent Protection Stage 6.3.7.2 Application and Setting Notes Parameter: Blk. w. inrush curr. detect. •...
Page 356 Protection and Automation Functions 6.3 Overcurrent Protection, Phases Figure 6-21). Depending on other functions, the stage can also be blocked dynamically. This functionality is only available in function type Advanced. [loocp3dpa-030311-01.vsd, 2, en_US] Figure 6-21 Principle of the Dynamic Settings Exemplified by 1st Definite-Time Overcurrent Protection Stage If available in the device, the following functionalities can affect the overcurrent-protection stages: Functionalities...
Page 357 Protection and Automation Functions 6.3 Overcurrent Protection, Phases example, signal function x) becomes active and is to take effect, these settings become dynamic, that is, instantly active. This means that the setting assigned to the signal replaces the standard setting. If the signal becomes inactive, the standard settings apply again.
Page 358 Protection and Automation Functions 6.3 Overcurrent Protection, Phases Several AREC signals can affect the setting for the Threshold and Operate delay parameters of the protection stage and its blocking. • AREC is ready for reclosing 1 (= Automatic reclosing cycle 1) •...
Page 359: Application And Setting Notes (Advanced Stage)
Protection and Automation Functions 6.3 Overcurrent Protection, Phases 6.3.8.2 Application and Setting Notes (Advanced Stage) Parameter: Dynamic settings • Default setting (_:661:26) Dynamic settings = no Parameter Value Description The influence on the overcurrent-protection stage by device-internal or external functions is not necessary. If a device-internal function (automatic reclosing function or cold-load pickup detection) or an external function should affect the overcurrent- protection stage (such as change the setting of the threshold value or time...
Page 360: Voltage-Dependent Overcurrent Protection, Phases
Protection and Automation Functions 6.4 Voltage-Dependent Overcurrent Protection, Phases Voltage-Dependent Overcurrent Protection, Phases Overview of Functions 6.4.1 The Voltage-dependent overcurrent protection (ANSI 51V) function: • Detects short circuits affecting electric equipment • Can be used for special network conditions where the overcurrent pickup level should be decreased depending on the fault voltage •...
Page 361: Stage With Inverse-Time Overcurrent Protection, Voltage-Dependent
Protection and Automation Functions 6.4 Voltage-Dependent Overcurrent Protection, Phases Stage with Inverse-Time Overcurrent Protection, Voltage-Dependent 6.4.3 6.4.3.1 Description Logic of the Stage [lovoldep-210713-01.tif, 2, en_US] Figure 6-26 Logic Diagram of the Inverse-Time Overcurrent Protection, Voltage-Dependent Method of Measurement You use the Method of measurement parameter to define whether the stage uses the fundamental comp.
Page 362 Protection and Automation Functions 6.4 Voltage-Dependent Overcurrent Protection, Phases • Measurement of the fundamental comp.: This method of measurement processes the sampled current values and filters out the fundamental component numerically. • Measurement of the RMS value: This method of measurement determines the current amplitude from the sampled values according to the defining equation of the RMS value.
Page 363: Application And Setting Notes
Protection and Automation Functions 6.4 Voltage-Dependent Overcurrent Protection, Phases An integrating method of measurement totalizes the weighted time. The weighted time results from the char- acteristic curve. For this, the time that is associated with the present current value is determined from the characteristic curve.
Page 364 Select this method of measurement if harmonics or transient current peaks fundamental comp. are to be suppressed. Siemens recommends using this method as the standard method. Select this method of measurement if you want the stage to take harmonics RMS value into account (for example, at capacitor banks).
Page 365: Settings
Protection and Automation Functions 6.4 Voltage-Dependent Overcurrent Protection, Phases The setting value for the Time dial parameter is derived from the time-grading chart that has been prepared for the electrical power system. Where no time grading and therefore no displacement of the characteristic curve is required, leave the param- eter Time dial at 1 (default setting).
Page 366: Stage With Inverse-Time Overcurrent Protection, Voltage-Released
Protection and Automation Functions 6.4 Voltage-Dependent Overcurrent Protection, Phases Stage with Inverse-Time Overcurrent Protection, Voltage-Released 6.4.4 6.4.4.1 Description Logic of the Stage [lovolrel-210713-01.tif, 2, en_US] Figure 6-28 Logic Diagram of the Inverse-Time Overcurrent Protection, Voltage-Released This stage is structured in the same way as the Inverse-time overcurrent, voltage-dependent stage (see chapter 6.4.3.1 Description).
Page 367: Application And Setting Notes
The overcurrent-protection stage is not blocked when a measuring-voltage failure is detected. The overcurrent-protection stage is blocked when a measuring-voltage failure is detected. Siemens recommends using the default setting, as correct operation of the stage cannot be guaranteed if a measuring-voltage failure occurs.
Page 368: Settings
Protection and Automation Functions 6.4 Voltage-Dependent Overcurrent Protection, Phases 6.4.4.3 Settings Addr. Parameter Setting Options Default Setting V-release # • V-release #:Mode • • test • V-release #:Operate & • flt.rec. blocked • _:10 V-release #:Blk. by • meas.-volt. failure •...
Page 369: Stage With Definite-Time Overcurrent Protection, Undervoltage Seal-In
Protection and Automation Functions 6.4 Voltage-Dependent Overcurrent Protection, Phases Stage with Definite-Time Overcurrent Protection, Undervoltage Seal-In 6.4.5 6.4.5.1 Description Logic of the Stage [lo_Seal-in_20150215, 2, en_US] Figure 6-29 Logic Diagram of the Definite-Time Overcurrent Protection, Undervoltage Seal-in Undervoltage Seal-In In generators where the excitation voltage is derived from the machine terminals, the short-circuit current decreases quickly in the event of close-in faults (for example, in a generator or a generator-transformer range).
Page 370: Application And Setting Notes
• Default setting (_:16951:101) State of V-seal-in = off With the parameter State of V-seal-in, the seal-in functionality can be activated (switched on). Siemens recommends this setting if the excitation transformer is connected to the main lead of the generator.
Page 371: Settings
Protection and Automation Functions 6.4 Voltage-Dependent Overcurrent Protection, Phases Parameter: V-seal-in threshold • Default setting (_:16951:102) V-seal-in threshold = 46.2 V The V-seal-in threshold (positive-sequence voltage) is set to a value below the lowest phase-to-phase voltage admissible during an operation, for example 80 % of the rated voltage of a generator. The positive- sequence voltage is evaluated.
Page 372: Information List
Protection and Automation Functions 6.4 Voltage-Dependent Overcurrent Protection, Phases Addr. Parameter Setting Options Default Setting • _:16951:101 V-seal-in 1:State of V- • seal-in _:16951:102 V-seal-in 1:V-seal-in 0.300 V to 175.000 V 80.019 V threshold _:16951:104 V-seal-in 1:Duration of V- 0.10 s to 60.00 s 4.00 s seal-in time 6.4.5.4...
Page 373: Stage With Definite-Time Overcurrent Protection, Voltage-Released Undervoltage Seal-In
Protection and Automation Functions 6.4 Voltage-Dependent Overcurrent Protection, Phases Stage with Definite-Time Overcurrent Protection, Voltage-Released 6.4.6 Undervoltage Seal-In 6.4.6.1 Description Logic of the Stage [lo_Seal-in_Rel20150215, 2, en_US] Figure 6-30 Logic Diagram of the Definite-Time Overcurrent Protection, Voltage-Released Undervoltage Seal-in, Part 1 Signal 4 in the following figure refers to Figure 6-30.
Page 374: Application And Setting Notes
Protection and Automation Functions 6.4 Voltage-Dependent Overcurrent Protection, Phases [lo_Seal-in_Rel2, 1, en_US] Figure 6-31 Logic Diagram of the Definite-Time Overcurrent Protection, Voltage-Released Undervoltage Seal-in, Part 2 Voltage Release In addition to the current criterion with undervoltage seal-in, a voltage-released logic must be present to issue the indication Pickup .
Page 375 • Default setting (_:101) State of V-seal-in = off With the parameter State of V-seal-in, the seal-in functionality can be activated (switched on). Siemens recommends this setting if the excitation transformer is connected to the main lead of the generator.
Page 376: Settings
Protection and Automation Functions 6.4 Voltage-Dependent Overcurrent Protection, Phases Parameter: Duration of V-seal-in time • Default setting (_:104) Duration of V-seal-in time = 4.00 s The parameter Duration of V-seal-in time limits the pickup seal-in induced by an overcurrent or undervoltage.
Page 377: Information List
Protection and Automation Functions 6.4 Voltage-Dependent Overcurrent Protection, Phases 6.4.6.4 Information List Information Data Class Type (Type) Vseal-in+Vrel# _:81 Vseal-in+Vrel#:>Block stage _:500 Vseal-in+Vrel#:>Block V-seal-in _:52 Vseal-in+Vrel#:Behavior _:53 Vseal-in+Vrel#:Health _:54 Vseal-in+Vrel#:Inactive _:55 Vseal-in+Vrel#:Pickup _:300 Vseal-in+Vrel#:Pickup I>+V-seal-in _:301 Vseal-in+Vrel#:Voltage release _:56 Vseal-in+Vrel#:Operate delay expired _:57 Vseal-in+Vrel#:Operate SIPROTEC 5, Overcurrent Protection, Manual...
Page 378: Overcurrent Protection, Ground
Protection and Automation Functions 6.5 Overcurrent Protection, Ground Overcurrent Protection, Ground Overview of Functions 6.5.1 The Overcurrent protection, ground function (ANSI 50N/51N): • Detects short circuits in electrical equipment • Can be used as backup overcurrent protection in addition to the main protection 6.5.2 Structure of the Function The Overcurrent protection, ground function is used in protection function groups.
Page 379: General Functionality
Protection and Automation Functions 6.5 Overcurrent Protection, Ground [dwocpga2-060213-01.tif, 5, en_US] Figure 6-32 Structure/Embedding the Function Overcurrent Protection, Ground – Advanced [dwocpgb1-060213-01.tif, 4, en_US] Figure 6-33 Structure/Embedding the Function Overcurrent Protection, Ground – Basic If the following listed, device-internal functions are present in the device, these functions can influence the pickup values and tripping delays of the stages or block the stages.
Page 380: Application And Setting Notes
Protection and Automation Functions 6.5 Overcurrent Protection, Ground [loMasValue-201507-01.vsd, 1, en_US] Figure 6-34 Logic Diagram of Measured-Value Selection Both options are only available for the current-transformer connection types 3-phase + IN and 3-phase + IN-separate. For other connection types respectively, only one option is possible. If you select an option that is not allowed, an inconsistency message is given.
Page 381: Settings
Protection and Automation Functions 6.5 Overcurrent Protection, Ground The function operates with the measured ground current IN. This is the IN Measured recommended setting unless there is a specific reason to use the calculated zero-sequence current 3I0. The function operates with the calculated zero sequence current 3I0. This 3I0 Calculated setting option can be used when applying a redundant 50N/51N function for safety reasons.
Page 382: Stage With Definite-Time Characteristic Curve
Protection and Automation Functions 6.5 Overcurrent Protection, Ground Stage with Definite-Time Characteristic Curve 6.5.4 6.5.4.1 Description Logic of the Basic Stage [loocpgb1-060213-01.tif, 2, en_US] Figure 6-35 Logic Diagram of the Definite-Time Overcurrent Protection (Ground) – Basic SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 383 Protection and Automation Functions 6.5 Overcurrent Protection, Ground Logic of the Advanced Stage [loocpgn1-291112-01.tif, 2, en_US] Figure 6-36 Logic Diagram of the Definite-Time Overcurrent Protection (Ground) – Advanced Method of Measurement (Basic and Advanced Stage) You use the Method of measurement parameter to define whether the stage uses the fundamental comp.
Page 384: Application And Setting Notes
Select this method of measurement if harmonics or transient current peaks fundamental comp. are to be suppressed. Siemens recommends using this method as the standard method. Select this method of measurement if you want the stage to take harmonics RMS value into account (for example, at capacitor banks).
Page 385 Set the Operate delay parameter to 0 or to a low value. Siemens recommends that the threshold values be determined with a system analysis. The following example illustrates the principle of grading with a current threshold on a long line.
Page 386: Settings
Recommended setting value (_:751:101) Dropout delay = 0 This parameter is not visible in the basic stage. Siemens recommends using the default setting 0 since the dropout of a protection stage must be done as fast as possible. You can use the Dropout delay parameter ≠ 0 to obtain a uniform dropout behavior if you use it together with an electromechanical relay.
Page 387 Protection and Automation Functions 6.5 Overcurrent Protection, Ground Addr. Parameter Setting Options Default Setting _:751:4 Definite-T 1:Dropout 0.90 to 0.99 0.95 ratio _:751:101 Definite-T 1:Dropout 0.00 s to 60.00 s 0.00 s delay _:751:6 Definite-T 1:Operate 0.00 s to 60.00 s 0.30 s delay Dyn.s: AR off/n.rdy...
Page 388: Information List
Protection and Automation Functions 6.5 Overcurrent Protection, Ground Addr. Parameter Setting Options Default Setting _:751:22 Definite-T 1:Operate 0.00 s to 60.00 s 0.30 s delay Dyn.s: AR cycle>3 • _:751:32 Definite-T 1:Effected by • AR cycle gr. 3 • _:751:39 Definite-T 1:Stage •...
Page 389 Protection and Automation Functions 6.5 Overcurrent Protection, Ground Information Data Class Type (Type) Definite-T 1 _:751:81 Definite-T 1:>Block stage _:751:84 Definite-T 1:>Activ. dyn. settings _:751:500 Definite-T 1:>Block delay & op. _:751:54 Definite-T 1:Inactive _:751:52 Definite-T 1:Behavior _:751:53 Definite-T 1:Health _:751:60 Definite-T 1:Inrush blocks operate _:751:55 Definite-T 1:Pickup...
Page 390: Stage With Inverse-Time Characteristic Curve
Protection and Automation Functions 6.5 Overcurrent Protection, Ground Stage with Inverse-Time Characteristic Curve 6.5.5 6.5.5.1 Description Logic of the Basic Stage [lo_ocp_gr2, 4, en_US] Figure 6-37 Logic Diagram of the Inverse-Time Overcurrent Protection (Ground) – Basic SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 391 Protection and Automation Functions 6.5 Overcurrent Protection, Ground Logic of the Advanced Stage [loocpgn2-291112-01.tif, 3, en_US] Figure 6-38 Logic Diagram of the Inverse-Time Overcurrent Protection (Ground) – Advanced Pickup and Dropout Behaviors of the Inverse-Time Characteristic Curve According to IEC and ANSI (Basic and Advanced Stage) When the input variable exceeds the threshold value by a factor of 1.1, the inverse-time characteristic curve is processed.
Page 392 Protection and Automation Functions 6.5 Overcurrent Protection, Ground dropout according to characteristic curve (disk emulation) is the same as turning back a rotor disk. The weighted reduction of the time is initiated from 0.9 of the set threshold value. The characteristic curve and associated formulas are shown in the Technical Data. Minimum Time of the Curve (Advanced Stage) With the parameter Min.
Page 393: Application And Setting Notes
Select this method of measurement if harmonics or transient current peaks fundamental comp. are to be suppressed. Siemens recommends using this method as the standard method. Select this method of measurement if you want the stage to take harmonics RMS value into account (for example, at capacitor banks).
Page 394: Settings
0 s, this parameter has no effect on the inverse-time characteristic curve. This parameter is only required for time coordination in recloser schemes. For all other applications, Siemens recommends keeping the default setting of 0 s.
Page 395 Protection and Automation Functions 6.5 Overcurrent Protection, Ground Addr. Parameter Setting Options Default Setting • _:781:26 Inverse-T 1:Dynamic • settings • _:781:27 Inverse-T 1:Blk. w. inrush • curr. detect. • _:781:8 Inverse-T 1:Method of fundamental comp. fundamental • measurement RMS value comp.
Page 396 Protection and Automation Functions 6.5 Overcurrent Protection, Ground Addr. Parameter Setting Options Default Setting _:781:103 Inverse-T 1:Time dial 0.00 to 15.00 1.00 Dyn.set: AR cycle 3 • _:781:31 Inverse-T 1:Effected by • AR cycle 3 • _:781:38 Inverse-T 1:Stage • blocked _:781:16 Inverse-T 1:Threshold...
Page 397: Information List
Protection and Automation Functions 6.5 Overcurrent Protection, Ground Addr. Parameter Setting Options Default Setting _:781:107 Inverse-T 1:Time dial 0.00 to 15.00 1.00 Information List 6.5.5.4 Information Data Class Type (Type) Group indicat. _:4501:55 Group indicat.:Pickup _:4501:57 Group indicat.:Operate Inverse-T 1 _:781:81 Inverse-T 1:>Block stage _:781:500...
Page 398: Application And Setting Notes
Protection and Automation Functions 6.5 Overcurrent Protection, Ground [dwocpken-140611-02.tif, 2, en_US] Figure 6-40 Pickup Behavior and Dropout Behavior when Using a User-Defined Characteristic Curve NOTE The currents that are lower than the current value of the smallest characteristic-curve point do not extend the operate time.
Page 399 6.5 Overcurrent Protection, Ground Set the current value as a multiple of the threshold value. Siemens recommends that you set the Threshold parameter to 1.00 in order to obtain a simple relation. You can change the threshold value setting afterwards if you want to shift the characteristic curve.
Page 400: Settings
Protection and Automation Functions 6.5 Overcurrent Protection, Ground 6.5.6.3 Settings Addr. Parameter Setting Options Default Setting General • User curve #:Mode • • test • User curve #:Operate & • flt.rec. blocked • _:26 User curve #:Dynamic • settings • _:27 User curve #:Blk.
Page 401 Protection and Automation Functions 6.5 Overcurrent Protection, Ground Addr. Parameter Setting Options Default Setting Dyn.set: AR cycle 2 • _:30 User curve #:Effected by • AR cycle 2 • _:37 User curve #:Stage • blocked _:15 User curve #:Threshold 1 A @ 100 Irated 0.010 A to 35.000 A 1.200 A 5 A @ 100 Irated 0.05 A to 175.00 A 6.00 A...
Page 402: Information List
Protection and Automation Functions 6.5 Overcurrent Protection, Ground Addr. Parameter Setting Options Default Setting Dyn.set: bin.input • _:34 User curve #:Effected by • binary input • _:41 User curve #:Stage • blocked _:19 User curve #:Threshold 1 A @ 100 Irated 0.010 A to 35.000 A 1.200 A 5 A @ 100 Irated 0.05 A to 175.00 A 6.00 A...
Page 403: Application And Setting Notes
Protection and Automation Functions 6.5 Overcurrent Protection, Ground [loocpgrd-210812-01.tif, 1, en_US] Figure 6-41 Part-Logic Diagram on the Influence of Inrush-Current Detection Exemplified by the 1st Defi- nite-Time Overcurrent Protection Stage 6.5.7.2 Application and Setting Notes Parameter: Blk. w. inrush curr. detect. •...
Page 404 Protection and Automation Functions 6.5 Overcurrent Protection, Ground [loocpgnd-030311-01.vsd, 2, en_US] Figure 6-42 Principle of the Dynamic Settings in the Example of 1st Definite-Time Overcurrent Protection Stage If available in the device, the following functionalities can affect the overcurrent-protection stages: Functionalities Priority Automatic reclosing (AREC)
Page 405 Protection and Automation Functions 6.5 Overcurrent Protection, Ground Where several signals are active in parallel, the priority specified above shall apply. This means that a signal with priority 2 precedes that of priority 3. The settings assigned to signal 2 become active. The functionality of the dynamic settings can be disabled.
Page 406 Protection and Automation Functions 6.5 Overcurrent Protection, Ground Several AREC signals can affect the setting for the Threshold and the Operate delay of the protection stage and its blocking. • AREC is ready for reclosing 1 (= Automatic reclosing cycle 1) •...
Page 407: Application And Setting Notes (Advanced Stage)
Protection and Automation Functions 6.5 Overcurrent Protection, Ground 6.5.8.2 Application and Setting Notes (Advanced Stage) Binary Input Signal: Dynamic settings • Default setting (_:751:26) Dynamic settings = no Parameter Value Description The influence on the overcurrent-protection stage by device-internal or external functions is not necessary.
Page 408: Directional Overcurrent Protection, Phases
Protection and Automation Functions 6.6 Directional Overcurrent Protection, Phases Directional Overcurrent Protection, Phases Overview of Functions 6.6.1 The Directional overcurrent protection, phases function (ANSI 67): • Detects short circuits at electrical equipment • Can be used as backup overcurrent protection in addition to the main protection •...
Page 409 Protection and Automation Functions 6.6 Directional Overcurrent Protection, Phases [dwdiocan-050213-01.tif, 4, en_US] Figure 6-46 Structure/Embedding the Function Directional Overcurrent Protection, Phases – Advanced [dwdiocba-050213-01.tif, 5, en_US] Figure 6-47 Structure/Embedding the Function Directional Overcurrent Protection, Phases – Basic If the device-internal functions listed in the following are present in the device, these functions can influence the pickup values and tripping delays of the stages or block the stages.
Page 410: Stage Control
Protection and Automation Functions 6.6 Directional Overcurrent Protection, Phases Stage Control 6.6.3 6.6.3.1 Description Logic The following figure represents the stage control. It applies to all types of stages. [lodocpn2-291112-01.tif, 1, en_US] Figure 6-48 Stage-Control Logic Diagram Blocking of the Stage with Measuring-Voltage Failure (Basic and Advanced Stage) The stage can be blocked if a measuring-voltage failure occurs.
Page 411: Stage With Definite-Time Characteristic Curve
6.6 Directional Overcurrent Protection, Phases Parameter Value Description The directional overcurrent-protection stage is blocked. Siemens recom- mends that you retain the default setting, as correct direction determination cannot be guaranteed if a measuring-voltage failure occurs. The directional overcurrent-protection stage is not blocked.
Page 412 Protection and Automation Functions 6.6 Directional Overcurrent Protection, Phases Logic of the Advanced Stage [lodocp31-141013, 1, en_US] Figure 6-50 Logic Diagram of the Directional, Definite-Time Overcurrent Protection, Phases - Advanced Directional Mode (Basic and Advanced Stage) You use the Directional mode parameter to define whether the stage works in a forward or reverse direc- tion.
Page 413 Protection and Automation Functions 6.6 Directional Overcurrent Protection, Phases ments which can be used to determine the direction are available in the voltage memory, the basic stage generally picks up without direction determination, that is non-directionally. For the advanced stage, the response can be defined via the Non-directional pickup parameter.
Page 414: Application And Setting Notes
Select this method of measurement if harmonics or transient current peaks fundamental comp. are to be suppressed. Siemens recommends using this method as the standard method. Select this method of measurement if you want the stage to take harmonics RMS value into account (for example, at capacitor banks).
Page 415 Recommended setting value (_:8131:101) Dropout delay = 0 s This parameter is not visible in the basic stage. Siemens recommends using this setting value, since the dropout of a protection stage must be performed as fast as possible. SIPROTEC 5, Overcurrent Protection, Manual...
Page 416: Settings
Protection and Automation Functions 6.6 Directional Overcurrent Protection, Phases You can use the Dropout delay parameter ≠ 0 s to obtain a uniform dropout behavior if you use it together with an electromechanical relay. This is required for time grading. The dropout time of the electro- mechanical relay must be known for this purpose.
Page 417 Protection and Automation Functions 6.6 Directional Overcurrent Protection, Phases Addr. Parameter Setting Options Default Setting • _:8131:36 Definite-T 1:Stage • blocked _:8131:14 Definite-T 1:Threshold 1 A @ 100 Irated 0.030 A to 35.000 A 1.500 A 5 A @ 100 Irated 0.15 A to 175.00 A 7.50 A 1 A @ 50 Irated 0.030 A to 35.000 A...
Page 418: Information List
Protection and Automation Functions 6.6 Directional Overcurrent Protection, Phases Addr. Parameter Setting Options Default Setting Dyn.s: Cold load PU • _:8131:33 Definite-T 1:Effect. b. • cold-load pickup • _:8131:40 Definite-T 1:Stage • blocked _:8131:18 Definite-T 1:Threshold 1 A @ 100 Irated 0.030 A to 35.000 A 1.500 A 5 A @ 100 Irated 0.15 A to 175.00 A 7.50 A...
Page 419: Stage With Inverse-Time Characteristic Curve
Protection and Automation Functions 6.6 Directional Overcurrent Protection, Phases Information Data Class Type (Type) _:8131:65 Definite-T 1:Dyn.set. ARcycl.>3act _:8131:66 Definite-T 1:Dyn.set. CLP active _:8131:67 Definite-T 1:Dyn.set. BI active _:8131:68 Definite-T 1:Dyn. set. blks. pickup _:8131:55 Definite-T 1:Pickup _:8131:300 Definite-T 1:Direction _:8131:56 Definite-T 1:Operate delay expired _:8131:57...
Page 420 Protection and Automation Functions 6.6 Directional Overcurrent Protection, Phases Logic of the Advanced Stage [lodocp33-121013, 2, en_US] Figure 6-52 Logic Diagram of the Directional, Inverse-Time Overcurrent Protection, Phases - Advanced Directional Mode (Basic and Advanced Stage) You use the Directional mode parameter to define whether the stage works in a forward or reverse direc- tion.
Page 421 Protection and Automation Functions 6.6 Directional Overcurrent Protection, Phases generally picks up without direction determination, that is non-directionally. For the advanced stage, the response can be defined via the Non-directional pickup parameter. With the at volt.< & mem.empty setting, the function picks up in such a situation without direction determination. With the no setting, the function does not pick up.
Page 422: Application And Setting Notes
(standard method) or the calculated RMS value. Parameter Value Description Select this method of measurement if harmonics or transient current peaks fundamental comp. are to be suppressed. Siemens recommends using this method as the standard method. SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 423 CB trips. Siemens recommends using the default setting. Select this setting if determining of direction is required under all circum- stances, that is, even in the event of pickup on a 3-phase close-up fault.
Page 424 0 s, this parameter has no effect on the inverse-time characteristic curve. This parameter is only required for time coordination in recloser schemes. For all other applications, Siemens recommends keeping the default setting of 0 s.
Page 425: Settings
Protection and Automation Functions 6.6 Directional Overcurrent Protection, Phases 6.6.5.3 Settings Addr. Parameter Setting Options Default Setting General _:2311:102 General:Rotation angle -180 ° to 180 ° 45 ° of ref. volt. General • _:8341:1 Inverse-T 1:Mode • • test • _:8341:2 Inverse-T 1:Operate &...
Page 426 Protection and Automation Functions 6.6 Directional Overcurrent Protection, Phases Addr. Parameter Setting Options Default Setting Dyn.set: AR cycle 1 • _:8341:29 Inverse-T 1:Effected by • AR cycle 1 • _:8341:36 Inverse-T 1:Stage • blocked _:8341:14 Inverse-T 1:Threshold 1 A @ 100 Irated 0.030 A to 35.000 A 1.500 A 5 A @ 100 Irated 0.15 A to 175.00 A 7.50 A...
Page 427: Information List
Protection and Automation Functions 6.6 Directional Overcurrent Protection, Phases Addr. Parameter Setting Options Default Setting Dyn.s: Cold load PU • _:8341:33 Inverse-T 1:Effect. b. • cold-load pickup • _:8341:40 Inverse-T 1:Stage • blocked _:8341:18 Inverse-T 1:Threshold 1 A @ 100 Irated 0.030 A to 35.000 A 1.500 A 5 A @ 100 Irated 0.15 A to 175.00 A 7.50 A...
Page 428: Stage With User-Defined Characteristic Curve
Protection and Automation Functions 6.6 Directional Overcurrent Protection, Phases Information Data Class Type (Type) _:8161:67 Inverse-T 1:Dyn.set. BI active _:8161:68 Inverse-T 1:Dyn. set. blks. pickup _:8161:59 Inverse-T 1:Disk emulation running _:8161:55 Inverse-T 1:Pickup _:8161:300 Inverse-T 1:Direction _:8161:56 Inverse-T 1:Operate delay expired _:8161:57 Inverse-T 1:Operate 6.6.6...
Page 429: Application And Setting Notes
The setting depends on the characteristic curve you want to realize. Set the current value as a multiple of the threshold value. Siemens recommends that you set the Threshold parameter to 1.00 in order to obtain a simple relation. You can change the threshold value setting afterwards if you want to displace the characteristic curve.
Page 430: Settings
The setting depends on the characteristic curve you want to realize. Set the current value as a multiple of the threshold value. Siemens recommends that you set the Threshold parameter to 1.00 in order to obtain a simple relation. You can change the threshold value setting afterwards if you want to displace the characteristic curve.
Page 431 Protection and Automation Functions 6.6 Directional Overcurrent Protection, Phases Addr. Parameter Setting Options Default Setting • _:27 User curve #:Blk. w. • inrush curr. detect. User curve #:Threshold 1 A @ 100 Irated 0.030 A to 35.000 A 1.500 A 5 A @ 100 Irated 0.15 A to 175.00 A 7.50 A 1 A @ 50 Irated...
Page 432 Protection and Automation Functions 6.6 Directional Overcurrent Protection, Phases Addr. Parameter Setting Options Default Setting _:16 User curve #:Threshold 1 A @ 100 Irated 0.030 A to 35.000 A 1.500 A 5 A @ 100 Irated 0.15 A to 175.00 A 7.50 A 1 A @ 50 Irated 0.030 A to 35.000 A...
Page 433: Information List
Protection and Automation Functions 6.6 Directional Overcurrent Protection, Phases 6.6.6.4 Information List Information Data Class Type (Type) User curve # _:81 User curve #:>Block stage _:501 User curve #:>Release delay & op. _:84 User curve #:>Activ. dyn. settings _:500 User curve #:>Block delay & op. _:54 User curve #:Inactive _:52...
Page 434 Protection and Automation Functions 6.6 Directional Overcurrent Protection, Phases [dwdocp02-240611-01.tif, 1, en_US] Figure 6-55 Cross-Polarized Voltages for Direction Determination The following table shows how measurands are assigned for direction-determination purposes in the event of different types of fault. Table 6-3 Measurands for Direction Determining Threshold- Measuring Element...
Page 435 Protection and Automation Functions 6.6 Directional Overcurrent Protection, Phases current. Consequently, the result of direction determination is as reliable as possible. Figure 6-56 illustrates the relationship based on a 1-phase ground fault in phase A. The short-circuit current I lags the short-circuit voltage by the short-circuit angle φ...
Page 436: Application And Setting Notes
Protection and Automation Functions 6.6 Directional Overcurrent Protection, Phases 6.6.7.2 Application and Setting Notes Parameter: Rotation angle of ref. volt. • Default setting (_:2311:102) Rotation angle of ref. volt.= 45 The directional characteristic, that is, the position of the forward and reverse ranges, is set with the Rota- tion angle of ref.
Page 437: Influence Of Other Functions Via Dynamic Settings
Protection and Automation Functions 6.6 Directional Overcurrent Protection, Phases Influence of Other Functions via Dynamic Settings 6.6.8 The influence of these functions via dynamic settings is described in chapter 6.3.8.1 Description and chapter 6.3.8.2 Application and Setting Notes (Advanced Stage) Application Notes for Parallel Lines and Cable Runs with Infeed at Both Ends 6.6.9 Parallel Lines or Transformers...
Page 438: Application Notes For Directional Comparison Protection
Protection and Automation Functions 6.6 Directional Overcurrent Protection, Phases Legend for Figure 6-59 Stage ▶: Directional stage, forward direction set Stage: Non-directional stage Grading time Application Notes for Directional Comparison Protection 6.6.10 The direction determination of directional overcurrent protection can be used to implement directional comparison protection for cable runs with infeed at both ends.
Page 439 Protection and Automation Functions 6.6 Directional Overcurrent Protection, Phases contrast with the blocking procedure, overfunction is not possible if communication is lost. Therefore, a loss of communication is not critical where this procedure is concerned, although it must be detected and indicated. Directional comparison protection can also be implemented as a blocking procedure.
Page 440: Directional Overcurrent Protection, Ground
Protection and Automation Functions 6.7 Directional Overcurrent Protection, Ground Directional Overcurrent Protection, Ground Overview of Functions 6.7.1 The Directional overcurrent protection, ground function (ANSI 67N): • Detects short circuits to ground affecting electric equipment • Ensures selective ground-fault detection for parallel lines or transformers with infeed at one end •...
Page 441 Protection and Automation Functions 6.7 Directional Overcurrent Protection, Ground [dwrdirad-300913, 3, en_US] Figure 6-61 Structure/Embedding of the Function Directional Overcurrent Protection, Ground – Advanced [dwrdirba-300913, 2, en_US] Figure 6-62 Structure/Embedding of the Function Directional Overcurrent Protection, Ground – Basic If the following listed device-internal functions are present in the device, these functions can influence the pickup values and operate delays of the stages or block the stages.
Page 442: General Functionality
Protection and Automation Functions 6.7 Directional Overcurrent Protection, Ground General Functionality 6.7.3 6.7.3.1 Measured-Value Selection Logic The function provides the option to select between the values IN measured or 3I0 calculated. [loMasValue-201505-01.vsd, 1, en_US] Figure 6-63 Logic Diagram of Measured-Value Selection Both options are only available for the current-transformer connection types 3-phase + IN and 3-phase + IN-separate.
Page 443: Direction Determination
Protection and Automation Functions 6.7 Directional Overcurrent Protection, Ground 6.7.3.2 Direction Determination Logic of Direction Determination The following figure represents the logic of the direction determination. It applies to all types of stages. [lodirdet-280812-01.tif, 1, en_US] Figure 6-64 Logic Diagram of Direction Determination Measurand for the Direction Determination With the parameter Polarization with you define whether the direction determination is calculated with the zero-sequence components 3I0 and V0 or with the negative-sequence components I2 and V2, which are...
Page 444 Protection and Automation Functions 6.7 Directional Overcurrent Protection, Ground into account, the reference voltage V0 can be rotated through an adjustable angle (parameter Rotation angle of ref. volt. ). This moves the vector of the rotated reference voltage close to the vector of the short-circuit current -3I0.
Page 445: Application And Setting Notes
Protection and Automation Functions 6.7 Directional Overcurrent Protection, Ground [dwforrev-281013, 2, en_US] Figure 6-67 Forward/Reverse Characteristic of the Directional Overcurrent Protection, Ground Function Direction Determination with Negative-Sequence Values The method works in the same way as for zero-sequence values. Instead of 3I0 and V0, the negative-sequence values I2 and V2 are used for determining the direction.
Page 446 Maximum operational measured value of zero-sequence voltage V0 = 0.5 Vsec Min. voltage V0 or V2 = 1.5 ⋅ 0.5 V = 0.75 Vsec If you have no information about maximum operational unbalance, Siemens recommends using the default setting. Parameter: Rotation angle of ref. volt. / Forward section +/- •...
Page 447: Settings
Description Select zero sequence to determine the direction via the zero-sequence zero sequence components V0 and 3I0. Siemens recommends using the zero-sequence components for the direction determination. Select negative sequence to determine the direction via the negative- negative sequence sequence components V2 and I2.
Page 448: Information List
Protection and Automation Functions 6.7 Directional Overcurrent Protection, Ground 6.7.3.5 Information List Information Data Class Type (Type) General _:2311:501 General:>Test of direction _:2311:352 General:Test direction _:2311:351 General:Phi(I,V) Stage Control 6.7.4 6.7.4.1 Description Logic The following figure represents the stage control. It applies to all types of stages. [lostacon-240812-01.tif, 1, en_US] Figure 6-68 Logic Diagram of the Stage Control...
Page 449 Parameter Value Description The directional overcurrent-protection stage is blocked when a measuring- voltage failure is detected. Siemens recommends using the default setting, as correct direction determination cannot be guaranteed if a measuring- voltage failure occurs. The directional overcurrent-protection stage is not blocked when a meas- uring-voltage failure is detected.
Page 450: Stage With Definite-Time Characteristic Curve
Protection and Automation Functions 6.7 Directional Overcurrent Protection, Ground Stage with Definite-Time Characteristic Curve 6.7.5 6.7.5.1 Description Logic of the Basic Stage [lodirovb-280812-02.tif, 1, en_US] Figure 6-69 Logic Diagram of the Directional Definite-Time Overcurrent Protection, Ground – Basic SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 451 Protection and Automation Functions 6.7 Directional Overcurrent Protection, Ground Logic of the Advanced Stage [lodirova-280812-02.tif, 1, en_US] Figure 6-70 Logic Diagram of the Directional Definite-Time Overcurrent Protection, Ground – Advanced Measurand (Basic and Advanced Stage) The function uses the zero-sequence current (3I0) as a criterion for the ground fault. Depending on the parameter setting connection type of the Measuring point I-3ph, the zero-sequence current is measured or calculated.
Page 452 Protection and Automation Functions 6.7 Directional Overcurrent Protection, Ground Table 6-7 Threshold Setting Range Connection Type of the Ground Current CT Terminal Type Threshold Setting Range Measuring Point (Secondary) I-3ph 3-phase Calculated 4 * Protection 0.030 A to 35.000 A 3 * Protection, 1* sensitive 0.030 A to 35.000 A 4 * Measurement...
Page 453: Application And Setting Notes
Select this method of measurement if harmonics or transient current peaks fundamental comp. are to be suppressed. Siemens recommends using this method as the standard method. Select this method of measurement if you want the stage to take harmonics RMS value into account (for example, at capacitor banks).
Page 454 Protection and Automation Functions 6.7 Directional Overcurrent Protection, Ground Parameter: Directional comparison, Release via input signal • Default setting (_:4861:104) Directional comparison = no • Default setting (_:4861:106) Release via input signal= no The parameters Directional comparison and Release via input signal are not visible for the basic stage.
Page 455: Settings
Recommended setting value (_:4861:101) Dropout delay = 0 s This parameter is not visible for the basic stage. Siemens recommends using the dropout delay of 0 s, since the dropout of a protection stage must be performed as fast as possible.
Page 456 Protection and Automation Functions 6.7 Directional Overcurrent Protection, Ground Addr. Parameter Setting Options Default Setting • _:4861:8 Definite-T 1:Method of fundamental comp. fundamental • measurement RMS value comp. • _:4861:104 Definite-T 1:Directional • comparison • _:4861:106 Definite-T 1:Release via • input signal •...
Page 457 Protection and Automation Functions 6.7 Directional Overcurrent Protection, Ground Addr. Parameter Setting Options Default Setting _:4861:15 Definite-T 1:Threshold 1 A @ 100 Irated 0.030 A to 35.000 A 1.200 A 5 A @ 100 Irated 0.15 A to 175.00 A 6.00 A 1 A @ 50 Irated 0.030 A to 35.000 A...
Page 458: Information List
Protection and Automation Functions 6.7 Directional Overcurrent Protection, Ground Addr. Parameter Setting Options Default Setting Dyn.set: bin.input • _:4861:34 Definite-T 1:Effected by • binary input • _:4861:41 Definite-T 1:Stage • blocked _:4861:19 Definite-T 1:Threshold 1 A @ 100 Irated 0.030 A to 35.000 A 1.200 A 5 A @ 100 Irated 0.15 A to 175.00 A 6.00 A...
Page 459: Stage With Inverse-Time Characteristic Curve
Protection and Automation Functions 6.7 Directional Overcurrent Protection, Ground Stage with Inverse-Time Characteristic Curve 6.7.6 6.7.6.1 Description Logic of the Basic Stage [lodiinvb-280812-02.tif, 2, en_US] Figure 6-71 Logic Diagram of the Directional Inverse-Time Overcurrent Protection, Ground – Basic SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 460 Protection and Automation Functions 6.7 Directional Overcurrent Protection, Ground Logic of the Advanced Stage [lodiinva-280812-02.tif, 2, en_US] Figure 6-72 Logic Diagram of the Directional Inverse-Time Overcurrent Protection, Ground – Advanced Measurand (Basic and Advanced Stage) The function uses the zero-sequence current (3I0) as a criterion for the ground fault. Depending on the parameter setting connection type of the Measuring point I-3ph, the zero-sequence current is measured or calculated.
Page 461 Protection and Automation Functions 6.7 Directional Overcurrent Protection, Ground Table 6-8 Threshold Setting Range Connection Type of the Ground Current CT Terminal Type Threshold Setting Range Measuring Point I-3ph (Secondary) 3-phase Calculated 4 * Protection 0.030 A to 35.000 A 3 * Protection, 1* sensitive 0.030 A to 35.000 A 4 * Measurement...
Page 462 Protection and Automation Functions 6.7 Directional Overcurrent Protection, Ground [DwMinTime_20140708-01.vsd, 1, en_US] Figure 6-73 Minimum Operating Time of the Curve Additional Time Delay (Advanced Stage) With the parameter Additional time delay, you define a definite-time delay in addition to the inverse- time delay.
Page 463: Application And Setting Notes
Select this method of measurement if harmonics or transient current peaks fundamental comp. are to be suppressed. Siemens recommends using this method as the standard method. Select this method of measurement if you want the stage to take harmonics RMS value into account (for example, at capacitor banks).
Page 464 Protection and Automation Functions 6.7 Directional Overcurrent Protection, Ground Parameter Value Description If the Directional comparison parameter is set to yes, the Release via input signal parameter, the Direction output signal, and the >Release delay & op. input signal become avail- able.
Page 465 0 s, this parameter has no effect on the inverse-time characteristic curve. This parameter is only required for time coordination in recloser schemes. For all other applications, Siemens recommends keeping the default setting of 0 s.
Page 466: Settings
Protection and Automation Functions 6.7 Directional Overcurrent Protection, Ground Where no time grading and therefore no displacement of the characteristic curve is required, leave the Time dial parameter at 1 (default setting). Parameter: Reset • Default setting (_:4891:131) Reset = disk emulation You can use the Reset parameter setting to define whether the stage decreases according to the dropout characteristic curve (in accordance with the behavior of a disk emulation = rotor disk) or instantaneously.
Page 467 Protection and Automation Functions 6.7 Directional Overcurrent Protection, Ground Addr. Parameter Setting Options Default Setting Dyn.s: AR off/n.rdy • _:4891:28 Inverse-T 1:Effect. by AR • off/n.ready • _:4891:35 Inverse-T 1:Stage • blocked Dyn.set: AR cycle 1 • _:4891:29 Inverse-T 1:Effected by •...
Page 468: Information List
Protection and Automation Functions 6.7 Directional Overcurrent Protection, Ground Addr. Parameter Setting Options Default Setting _:4891:17 Inverse-T 1:Threshold 1 A @ 100 Irated 0.030 A to 35.000 A 1.200 A 5 A @ 100 Irated 0.15 A to 175.00 A 6.00 A 1 A @ 50 Irated 0.030 A to 35.000 A...
Page 469 Protection and Automation Functions 6.7 Directional Overcurrent Protection, Ground Information Data Class Type (Type) _:4891:66 Inverse-T 1:Dyn.set. CLP active _:4891:67 Inverse-T 1:Dyn.set. BI active _:4891:68 Inverse-T 1:Dyn. set. blks. pickup _:4891:59 Inverse-T 1:Disk emulation running _:4891:55 Inverse-T 1:Pickup _:4891:300 Inverse-T 1:Direction _:4891:56 Inverse-T 1:Operate delay expired _:4891:57...
Page 470: Stage With Inverse-Time Overcurrent Protection With Logarithmic-Inverse Char- Acteristic Curve
Protection and Automation Functions 6.7 Directional Overcurrent Protection, Ground Stage with Inverse-Time Overcurrent Protection with Logarithmic-Inverse 6.7.7 Characteristic Curve 6.7.7.1 Description Logic of the Stage [lodiloin-280812-02.tif, 2, en_US] Figure 6-74 Logic Diagram of the Directional Logarithmic Inverse-Time Overcurrent Protection, Ground Apart from the operate curve, this type of stage is identical to the Inverse-time overcurrent protection –...
Page 471 Protection and Automation Functions 6.7 Directional Overcurrent Protection, Ground Operate Curve If the function picks up, the logarithmic inverse-time characteristic curve is processed. A time value T calculated for every input value exceeding 95 % of the pickup value. An integrator accumulates the value 1/ .
Page 472: Application And Setting Notes
Protection and Automation Functions 6.7 Directional Overcurrent Protection, Ground 6.7.7.2 Application and Setting Notes Apart from the operate curve, this type of stage is identical to the ground-fault protection type with inverse- time delay according to IEC and ANSI (advanced function type) (see chapter 6.7.6.1 Description).
Page 473: Settings
Protection and Automation Functions 6.7 Directional Overcurrent Protection, Ground Siemens recommends setting this time to 0 s so that it has no effect. Settings 6.7.7.3 Addr. Parameter Setting Options Default Setting General • Log.-inv.-T #:Mode • • test • Log.-inv.-T #:Operate &...
Page 474 Protection and Automation Functions 6.7 Directional Overcurrent Protection, Ground Addr. Parameter Setting Options Default Setting _:14 Log.-inv.-T #:Threshold 1 A @ 100 Irated 0.030 A to 35.000 A 1.200 A 5 A @ 100 Irated 0.15 A to 175.00 A 6.00 A 1 A @ 50 Irated 0.030 A to 35.000 A...
Page 475: Information List
Protection and Automation Functions 6.7 Directional Overcurrent Protection, Ground Addr. Parameter Setting Options Default Setting _:18 Log.-inv.-T #:Threshold 1 A @ 100 Irated 0.030 A to 35.000 A 1.200 A 5 A @ 100 Irated 0.15 A to 175.00 A 6.00 A 1 A @ 50 Irated 0.030 A to 35.000 A...
Page 476: Stage With Knee-Point Characteristic Curve
Protection and Automation Functions 6.7 Directional Overcurrent Protection, Ground Stage with Knee-Point Characteristic Curve 6.7.8 6.7.8.1 Description Logic of the Stage [lodilokn-280812-02.tif, 3, en_US] Figure 6-76 Logic Diagram of the Directional Logarithmic Inverse Time with Knee-Point Overcurrent Protec- tion, Ground Apart from the operate curve, this type of stage is almost identical to the Inverse-time overcurrent protec- tion –...
Page 477: Application And Setting Notes
Protection and Automation Functions 6.7 Directional Overcurrent Protection, Ground Operate Curve If the function picks up, the logarithmic inverse-time characteristic curve is processed. A time value T calculated for every input value exceeding 95 % of the threshold value. An integrator accumulates the value .
Page 478: Settings
Protection and Automation Functions 6.7 Directional Overcurrent Protection, Ground Parameter: Time dial • Default setting (_:6) Time dial = 0.2 You can use the Time dial parameter to displace the operate curve in the time direction. General information cannot be provided. Define the value corresponding to the application. Parameter: Knee-point •...
Page 479: Information List
Protection and Automation Functions 6.7 Directional Overcurrent Protection, Ground Addr. Parameter Setting Options Default Setting Log.inv.T KP #:Threshold 1 A @ 100 Irated 0.030 A to 35.000 A 1.200 A 5 A @ 100 Irated 0.15 A to 175.00 A 6.00 A 1 A @ 50 Irated 0.030 A to 35.000 A...
Page 480: Stage With User-Defined Characteristic Curve
Protection and Automation Functions 6.7 Directional Overcurrent Protection, Ground Stage with User-Defined Characteristic Curve 6.7.9 6.7.9.1 Description Logic of the Stage [lodirusr-280812-02.tif, 1, en_US] Figure 6-78 Logic Diagram of the Directional User-Defined Characteristic Curve Overcurrent Protection, Ground This stage is structured in the same way as the Inverse-time overcurrent protection – advanced stage (see chapter 6.7.6.1 Description).
Page 481: Application And Setting Notes
Protection and Automation Functions 6.7 Directional Overcurrent Protection, Ground User-Defined Characteristic Curve With the directional, user-defined characteristic curve, you can define the operate curve point by point using up to 30 value pairs of current and time. The device uses linear interpolation to calculate the characteristic curve from these values.
Page 482: Settings
The setting follows the characteristic curve you want to realize. Set the current value as a multiple of the threshold value. Siemens recommends that you set the Threshold parameter to 1.00 in order to obtain a simple relation. You can change the threshold setting afterwards if you want to displace the characteristic curve.
Page 483 Protection and Automation Functions 6.7 Directional Overcurrent Protection, Ground Addr. Parameter Setting Options Default Setting • User curve #:Operate & • flt.rec. blocked • _:113 User curve #:Directional forward forward • mode reverse • User curve #:Method of fundamental comp. fundamental •...
Page 484 Protection and Automation Functions 6.7 Directional Overcurrent Protection, Ground Addr. Parameter Setting Options Default Setting _:15 User curve #:Threshold 1 A @ 100 Irated 0.030 A to 35.000 A 1.200 A 5 A @ 100 Irated 0.15 A to 175.00 A 6.00 A 1 A @ 50 Irated 0.030 A to 35.000 A...
Page 485: Information List
Protection and Automation Functions 6.7 Directional Overcurrent Protection, Ground Addr. Parameter Setting Options Default Setting _:19 User curve #:Threshold 1 A @ 100 Irated 0.030 A to 35.000 A 1.200 A 5 A @ 100 Irated 0.15 A to 175.00 A 6.00 A 1 A @ 50 Irated 0.030 A to 35.000 A...
Page 486: Inrush-Current Detection
Protection and Automation Functions 6.8 Inrush-Current Detection Inrush-Current Detection Overview of Functions 6.8.1 The function Inrush-current detection • Recognizes an inrush process on transformers • Generates a blocking signal for protection functions that protect the transformer (protected object) or for protection functions that are affected in undesirable ways when transformers are switched on •...
Page 487 Protection and Automation Functions 6.8 Inrush-Current Detection [loinru02-100611-01.tif, 2, en_US] Figure 6-81 Basic Structure of the Inrush-Current Detection Harmonic Analysis For this method of measurement, the content of the 2nd harmonic and the fundamental component (1st harmonic) are determined for each of the phase currents I , and I and the quotient I 2nd harm...
Page 488 Protection and Automation Functions 6.8 Inrush-Current Detection [loinru10-040912-01.tif, 1, en_US] Figure 6-82 Logic of the Harmonic Analysis Function (T = 1 Period) CWA Method (Current Wave Shape Analysis) The CWA method executes a wave shape analysis of the phase currents IA, IB, and IC. If all 3 phase currents show flat areas at the same point in time, the inrush-current detection signal will be issued.
Page 489 Protection and Automation Functions 6.8 Inrush-Current Detection [loinru05-240211-01.tif, 1, en_US] Figure 6-84 Logic of the CWA-Method Function (T = 1 Period) Logic of the Inrush-Current Detection The following logic diagram shows the link of the 2 methods of measurement Harmonic Analysis and CWA method.
Page 490: Application And Setting Notes
Protection and Automation Functions 6.8 Inrush-Current Detection [loinru12-060912-01.tif, 1, en_US] Figure 6-85 Logic Diagram of the Inrush-Current Detection Application and Setting Notes 6.8.4 Parameter: Operat.-range limit Imax • Recommended setting value (_:106) Operat.-range limit Imax = 7.5 A With the parameter Operat.-range limit Imax, you can specify at which current the inrush-current detection is blocked internally.
Page 491: Settings
Harmonic analysis process activated. Harmonic analysis process deactivated. NOTE Make sure that at least one process is activated. Siemens recommends retaining the advised setting values. Parameter: 2nd harmonic content • Recommended setting value (_:102) 2nd harmonic content = 15 % With the parameter 2nd harmonic content, you can specify the pickup value of the harmonic anal- ysis function.
Page 492: Information List
Protection and Automation Functions 6.8 Inrush-Current Detection Addr. Parameter Setting Options Default Setting _:106 Inrush detect.:Operat.- 1 A @ 100 Irated 0.030 A to 35.000 A 7.500 A range limit Imax 5 A @ 100 Irated 0.15 A to 175.00 A 37.50 A 1 A @ 50 Irated 0.030 A to 35.000 A...
Page 493: Instantaneous High-Current Tripping
Protection and Automation Functions 6.9 Instantaneous High-Current Tripping Instantaneous High-Current Tripping Overview of Functions 6.9.1 The Instantaneous high-current tripping function has the following tasks: • Instantaneous tripping when switching onto an existing fault, for example, if a grounding switch is closed.
Page 494: Standard Release Procedure
Protection and Automation Functions 6.9 Instantaneous High-Current Tripping Standard Release Procedure 6.9.3 Logic [lohlore3-160611-01.tif, 2, en_US] Figure 6-87 Logic Diagram of Instantaneous High-Current Tripping with Standard Release Method Activation Using the Activation parameter, you set the conditions under which the stage is released. •...
Page 495: Application And Setting Notes
Protection and Automation Functions 6.9 Instantaneous High-Current Tripping The stage is released only if the binary input signal >release is active. Method of Measurement, Threshold Value The stage works with 2 different methods of measurement. • Measurement of the fundamental component: This method of measurement processes the sampled current values and filters out the fundamental component numerically.
Page 496: Release Procedure Via Protection Interface
Protection and Automation Functions 6.9 Instantaneous High-Current Tripping The maximum 3-phase short-circuit current I" flowing through is (at a source voltage of 1.1 V [foglchik-170309-01.tif, 1, en_US] With a safety margin of 10 %, the following setting value results: [foglnste-170309-01.tif, 1, en_US] If short-circuit currents exceed 1496 A (primary) or 12.5 A (secondary), there is a short circuit on the line to be protected.
Page 497 Protection and Automation Functions 6.9 Instantaneous High-Current Tripping Logic [lohinre3-160611-01.tif, 1, en_US] Figure 6-88 Logic Diagram of Instantaneous High-Current Tripping with Release Procedure via Protection Interface Release If one of the following conditions is fulfilled, the stage is released (the internal Release signal is present) (for further information, see chapter 5.8 Process Monitor):...
Page 498: Application And Setting Notes
Protection and Automation Functions 6.9 Instantaneous High-Current Tripping • Measurement of the fundamental component: This method of measurement processes the sampled current values and filters out the fundamental component numerically. A DC component is thus eliminated. The RMS value of the fundamental compo- nent is compared with the set threshold.
Page 499 Protection and Automation Functions 6.9 Instantaneous High-Current Tripping Information Data Class Type (Type) _:4501:57 Group indicat.:Operate Standard 1 _:3901:500 Standard 1:>release _:3901:81 Standard 1:>Block stage _:3901:54 Standard 1:Inactive _:3901:52 Standard 1:Behavior _:3901:53 Standard 1:Health _:3901:300 Standard 1:Rel. by CB switch on _:3901:55 Standard 1:Pickup _:3901:57...
Page 500: Arc Protection
Protection and Automation Functions 6.10 Arc Protection 6.10 Arc Protection Overview of Function 6.10.1 The function Arc protection: • Detects arcs in air-insulated switchgear parts without delay and in a fail-safe way • Limits system damage through instantaneous high-speed tripping •...
Page 501: Function Description
Protection and Automation Functions 6.10 Arc Protection Function Description 6.10.3 General Logic of the Function Block [lo_fb0_arcprot, 2, en_US] Figure 6-90 General Logic Diagram of the Function Block SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 502 Protection and Automation Functions 6.10 Arc Protection Logic of the Stage [lo_stage_arcprotection, 1, en_US] Figure 6-91 Logic Diagram of the Stage TheArc protection function uses a locally connected optical arc sensor or an external trip initiation by other devices in order to detect arcs. NOTE Install the arc sensors inside the switchgear in such a way that they are not hidden behind other system components!
Page 503: Application And Setting Notes - General Settings
Protection and Automation Functions 6.10 Arc Protection Method of Measurement, Current-Flow Criterion The current-flow criterion works with 2 different methods of measurement. • Measurement of the fundamental component: This method of measurement processes the sampled current values and filters out the fundamental component numerically.
Page 504: Application And Setting Notes For The Stage
If you select this setting option, the parameter Threshold light is custom visible. Siemens recommends the default setting values point sensor or line sensor. This allows arcs to be detected reliably regardless of diffused light. Parameter: Threshold light •...
Page 505: Settings
If the sensors even pick up in case of a switching arc of the circuit breaker, set the Threshold light parameter to a higher value. Siemens recommends the default settings for point or line sensors. Set the parameter Threshold light manually only if you have special default settings for light sensitivity.
Page 506: Information List
Protection and Automation Functions 6.10 Arc Protection Addr. Parameter Setting Options Default Setting Stage 2 • _:14552:1 Stage 2:Mode • • test • _:14552:2 Stage 2:Operate & • flt.rec. blocked • _:14552:9 Stage 2:External trip • initiation current • light •...
Page 507 Protection and Automation Functions 6.10 Arc Protection Information Data Class Type (Type) _:14551:54 Stage 1:Inactive _:14551:52 Stage 1:Behavior _:14551:53 Stage 1:Health _:14551:318 Stage 1:Fault arc counter _:14551:58 Stage 1:Arc detected _:14551:301 Stage 1:Light detected _:14551:55 Stage 1:Pickup _:14551:57 Stage 1:Operate Stage 2 _:14552:81 Stage 2:>Block stage...
Page 508: Application Example For Arc Protection With Point Sensors In Operating Mode: Light Only
Protection and Automation Functions 6.10 Arc Protection Application Example for Arc Protection with Point Sensors in Operating Mode: 6.10.8 Light Only 6.10.8.1 Description Overview The example describes the Arc protection function in a medium-voltage switchgear with one infeed and 2 feeders. The Arc protection function operates with the Operating mode = light only. The following items are considered in the example below: •...
Page 509: Application And Setting Notes
Protection and Automation Functions 6.10 Arc Protection • The optical point sensors in the cable-connection compartment of the feeders detect arcs in this compart- ment. Install one optical point sensor in the cable-connection compartment of the feeders and connect it to the protection device of the feeder.
Page 510: Application Example For Arc Protection With Point Sensors In Operating Mode: Light And Current
Protection and Automation Functions 6.10 Arc Protection The parameters in block General are not relevant since the Operating mode = light only. Setting Notes for the Protection Device in the Infeed The Arc protection function operates with 5 stages. Set the parameters of the stages as follows: •...
Page 511 Protection and Automation Functions 6.10 Arc Protection [dw_light-and-current, 2, en_US] Figure 6-93 Layout and Connection of the Optical Point Sensors (Operating Mode = Current and Light) For this example, the following is assumed: • The current-flow criterion offers additional security to prevent unwanted tripping caused by sudden light influences.
Page 512: Application And Setting Notes
Protection and Automation Functions 6.10 Arc Protection NOTE This application example requires the connection of several optical point sensors to a single protection device. It must be considered that the number of arc-protection modules that are connected to the device depends on the hardware configuration of the device.
Page 513 Protection and Automation Functions 6.10 Arc Protection The following items are considered in the example below: • Positioning the optical point sensors in the switchgear • Connecting the optical point sensors to the protection devices in the feeders and the infeed •...
Page 514: Application And Setting Notes
Protection and Automation Functions 6.10 Arc Protection NOTE If the Arc protection function operates via the External trip initiation, only 3 optical point sensors are required per feeder protection device in order to detect the arcs (only one arc-protection module). The number of GOOSE messages is not limited.
Page 515 Protection and Automation Functions 6.10 Arc Protection • Parameter: Operate & flt.rec. blocked = no • Parameter: Channel = Setting Notes for the Protection Device in Feeder 2 The Arc protection function operates with 3 stages. Stage 1 and 2 (supervision of busbar compartment and circuit-breaker compartment): Set the parameters of the stages as follows: •...
Page 516: Application Example For Arc Protection With A Line Sensor In Operating Mode: Light And Current
Protection and Automation Functions 6.10 Arc Protection • Parameter: Sensor = point sensor • Parameter: External trip initiation = no Stage 3 (cable-connection compartment supervision): • Parameter: Operate & flt.rec. blocked = yes If an arc is detected in the cable-connection compartment of the infeed (light-gray point sensors in Figure 6-94), a pickup indication is generated immediately.
Page 517 Protection and Automation Functions 6.10 Arc Protection [dw_Liniensensor, 1, en_US] Figure 6-95 Layout and Connection of the Optical Line Sensors (Operating Mode = Current and Light) For this example, the following is assumed: • The current-flow criterion offers additional protection to prevent unwanted tripping caused by the sudden effects of light.
Page 518: Application And Setting Notes
Protection and Automation Functions 6.10 Arc Protection 6.10.11.2 Application and Setting Notes Setting Notes for the Protection Device in the Infeed The Arc protection function operates with 1 stage. Set the parameters of the stage as follows: • Parameter: Operating mode = current and light •...
Page 519: Instantaneous Tripping At Switch Onto Fault
Protection and Automation Functions 6.11 Instantaneous Tripping at Switch onto Fault 6.11 Instantaneous Tripping at Switch onto Fault Overview of Functions 6.11.1 The Instantaneous tripping at switch onto fault function serves for immediate tripping when switching onto a fault. The function does not have its own measurement and must be linked to another protection function with the pickup (measurement).
Page 520: Stage Description
Protection and Automation Functions 6.11 Instantaneous Tripping at Switch onto Fault Stage Description 6.11.3 Logic of the Stage [logisotf-170312-01.tif, 1, en_US] Figure 6-97 Logic Diagram of the Stage Instantaneous Tripping at Switch onto Fault Connection of the Stage The stage is intended to initiate instantaneous tripping when switching onto a fault. To do this, the stage must be connected to one or more pickups from protection functions or protection stages, for example, to pickup of an overcurrent-protection stage.
Page 521: Settings
Protection and Automation Functions 6.11 Instantaneous Tripping at Switch onto Fault The Configuration parameter is used to define with which pickup of a protection function or protection stage the Instantaneous tripping at switch onto fault function responds. Normally, the pickups of protection functions and stages with high fault current are selected: •...
Page 522: Overcurrent Protection, 1-Phase
Protection and Automation Functions 6.12 Overcurrent Protection, 1-Phase 6.12 Overcurrent Protection, 1-Phase Function Overview 6.12.1 The Overcurrent protection, 1-phase function (ANSI 50N/51N): • Detects and monitors the current measured in a transformer neutral point grounding • Can operate as sensitive tank leakage protection •...
Page 523 Protection and Automation Functions 6.12 Overcurrent Protection, 1-Phase [dwocp1pa-280113-01.tif, 3, en_US] Figure 6-98 Structure/Embedding the Function Overcurrent Protection, 1-Phase – Advanced [dwocp1pb-310113-01.tif, 3, en_US] Figure 6-99 Structure/Embedding the Function Overcurrent Protection, 1-Phase – Basic If the device is equipped with the Inrush-current detection function, you can stabilize the stages against issuing of the operate indication due to transformer inrush-currents.
Page 524: Stage With Definite-Time Characteristic Curve
Protection and Automation Functions 6.12 Overcurrent Protection, 1-Phase Stage with Definite-Time Characteristic Curve 6.12.3 6.12.3.1 Description Logic of a Stage [loinvocp-270612-01.tif, 1, en_US] Figure 6-100 Logic Diagram of the Definite-Time Overcurrent Protection, 1-Phase Method of measurement You use the Method of measurement parameter to define whether the stage uses the fundamental comp.
Page 525: Application And Setting Notes
Select this method of measurement if harmonics or transient current peaks fundamental comp. are to be suppressed. Siemens recommends using this method as the standard method. Select this method of measurement if you want the stage to take harmonics RMS value into account (for example, at capacitor banks).
Page 526: Settings
Protection and Automation Functions 6.12 Overcurrent Protection, 1-Phase 6.12.3.3 Settings Addr. Parameter Setting Options Default Setting Definite-T 1 • _:12661:1 Definite-T 1:Mode • • test • _:12661:2 Definite-T 1:Operate & • flt.rec. blocked • _:12661:27 Definite-T 1:Blk. w. • inrush curr. detect. •...
Page 527: Stage With Inverse-Time Characteristic Curve
Protection and Automation Functions 6.12 Overcurrent Protection, 1-Phase Stage with Inverse-Time Characteristic Curve 6.12.4 6.12.4.1 Description Logic of the Stage [lodefocp-270612-01.tif, 1, en_US] Figure 6-101 Logic Diagram of the Inverse-Time Overcurrent Protection (1-Phase) Pickup and Dropout Behaviors of the Inverse-Time Characteristic Curve According to IEC and ANSI When the input variable exceeds the threshold value by a factor of 1.1, the inverse-time characteristic curve is processed.
Page 528: Application And Setting Notes
(standard method) or the calculated RMS value. Parameter Value Description Select this method of measurement if harmonics or transient current peaks fundamental comp. are to be suppressed. Siemens recommends using this method as the standard method. SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 529: Settings
Protection and Automation Functions 6.12 Overcurrent Protection, 1-Phase Parameter Value Description Select this method of measurement if you want the stage to take harmonics RMS value into account (for example, at capacitor banks). Consider that aperiodic DC components present in the secondary circuit are measured and can cause an overfunction.
Page 530: Information List
Protection and Automation Functions 6.12 Overcurrent Protection, 1-Phase Addr. Parameter Setting Options Default Setting • _:12691:8 Inverse-T 1:Method of fundamental comp. fundamental • measurement RMS value comp. _:12691:3 Inverse-T 1:Threshold 1 A @ 100 Irated 0.030 A to 35.000 A 1.200 A 5 A @ 100 Irated 0.15 A to 175.00 A 6.00 A...
Page 531: Application And Setting Notes
The setting depends on the characteristic curve you want to realize. Set the current value as a multiple of the threshold value. Siemens recommends that you set the Threshold parameter to 1.00 in order to obtain a simple relation. You can change the threshold value setting afterwards if you want to displace the characteristic curve.
Page 532: Settings
The setting depends on the characteristic curve you want to realize. Set the current value as a multiple of the threshold value. Siemens recommends that you set the Threshold parameter to 1.00 in order to obtain a simple relation. You can change the threshold value setting afterwards if you want to displace the characteristic curve.
Page 533: Information List
Protection and Automation Functions 6.12 Overcurrent Protection, 1-Phase Addr. Parameter Setting Options Default Setting User curve #:Threshold 1 A @ 100 Irated 0.030 A to 35.000 A 1.200 A 5 A @ 100 Irated 0.15 A to 175.00 A 6.00 A 1 A @ 50 Irated 0.030 A to 35.000 A 1.200 A...
Page 534: Application And Setting Notes
Protection and Automation Functions 6.12 Overcurrent Protection, 1-Phase [loocp1hs-280113-01.tif, 2, en_US] Figure 6-103 Logic Diagram of the Fast Stage, 1-Phase Method of Measurement, Pickup and Dropout Behaviors of the Fast Stage This stage evaluates the unfiltered measurands. Thus, very short response times are possible. When the abso- lute values of 2 consecutive sampled values of the last half period exceed the Threshold, the stage picks up.
Page 535: Settings
Protection and Automation Functions 6.12 Overcurrent Protection, 1-Phase 6.12.6.3 Settings Addr. Parameter Setting Options Default Setting Fast stage # • Fast stage #:Mode • • test • Fast stage #:Operate & • flt.rec. blocked Fast stage #:Threshold 1 A @ 100 Irated 0.030 A to 35.000 A 10.000 A 5 A @ 100 Irated 0.15 A to 175.00 A 50.00 A...
Page 536 Protection and Automation Functions 6.12 Overcurrent Protection, 1-Phase [dwhimpef-310113-01.tif, 2, en_US] Figure 6-104 Restricted Ground-Fault Protection According to the High-Impedance Principle Function of the High-Impedance Principle The high-impedance principle is explained using the example of a grounded transformer winding. In normal state, no residual currents flow, that is, in the transformer neutral point I = 0 and in the phases = 0.
Page 537: Application And Setting Notes
Protection and Automation Functions 6.12 Overcurrent Protection, 1-Phase High-Impedance Restricted Ground-Fault Protection with a SIPROTEC 5 Device Use the I4 measuring input of the SIPROTEC 5 device for the high-impedance restricted ground-fault protec- tion. This input for this application is to be executed as a sensitive measuring input. Since this is a current input, the current is detected by this resistor instead of the voltage at the resistor R.
Page 538 Protection and Automation Functions 6.12 Overcurrent Protection, 1-Phase Secondary rated current of the current transformer rated Rated overcurrent factor Rated current, rated power, and overcurrent factor are found on the name plate of the transformer. EXAMPLE Current transformer with the following data on the name plate: 800/5; 5P10; 30 VA You can read the following transformer data with this data: = 5 A (out of 800/5) rated...
Page 539 Protection and Automation Functions 6.12 Overcurrent Protection, 1-Phase [dwvebhdi-310113-01.tif, 2, en_US] Figure 6-107 Simplified Connection Diagram of a Layout for High-Impedance Restricted Ground-Fault Protection The voltage at R is, then, · (2R A further assumption is that the pickup value of the SIPROTEC 5 device corresponds to half of the knee-point voltage of the current transformers.
Page 540 Protection and Automation Functions 6.12 Overcurrent Protection, 1-Phase [foberecr-310113-01.tif, 1, en_US] EXAMPLE For the 5 A transformer as above Desired pickup value I = 0.1 A (corresponds to 16 A primary) pick [fober5aw-310113-01.tif, 1, en_US] For the 1 A transformer as above Desired pickup value I = 0.05 A (corresponds to 40 A primary) pick...
Page 541: Application Example: Tank Leakage Protection
Even with unfavorable wiring, the maximum occurring voltage peaks do not exceed 2 kV for safety reasons. When for performance reasons, several varistors must be connected in parallel, give preference to types with flat characteristic curves, in order to avoid an unbalanced load. Siemens therefore recommends the following types by METROSIL: 600A/S1/S256 (k = 450, β...
Page 542: Application And Setting Notes
Protection and Automation Functions 6.12 Overcurrent Protection, 1-Phase [dwprkess-310113-01.tif, 2, en_US] Figure 6-109 Tank-Control Principle 6.12.8.2 Application and Setting Notes A prerequisite for the application of tank protection is the availability of a sensitive input transformer at device input I4. If you connect Measuring point I 1-ph with the function group Voltage-current 1-phase, the function Over- current protection, 1-phase works with the 1-phase current connected to input I4.
Page 543: Non-Directional Intermittent Ground-Fault Protection
Protection and Automation Functions 6.13 Non-Directional Intermittent Ground-Fault Protection 6.13 Non-Directional Intermittent Ground-Fault Protection Overview of Functions 6.13.1 A typical characteristic of intermittent ground faults is that they often extinguish automatically and strike again after some time. The fault duration can last between a few milliseconds and many seconds. Thus, such faults are not detected at all or not selectively by the ordinary overcurrent protection.
Page 544: Stage Description
Protection and Automation Functions 6.13 Non-Directional Intermittent Ground-Fault Protection Stage Description 6.13.3 Logic [LoIntnon, 1, en_US] Figure 6-111 Logic of the Non-Directional Intermittent Ground-Fault Protection Measured Value 3I0 The intermittent ground-fault current 3I0 can either be measured via the standard ground-current input IN or via the sensitive ground-current input I .
Page 545 Protection and Automation Functions 6.13 Non-Directional Intermittent Ground-Fault Protection Table 6-9 Threshold Setting Range with Different Connection Types Connection Type of Current Threshold 3I0/IN CT Terminal Type Threshold Setting the Measuring Point Range I-3ph (Secondary) 3-phase 4 x Protection 0.030 A to 35.000 A Calculated 3I0 3 x Protection, 1 x sensitive 0.030 A to 35.000 A 4 x Measurement...
Page 546 Protection and Automation Functions 6.13 Non-Directional Intermittent Ground-Fault Protection Defined time for extending the Pickup signal ext. Number of Pickups The stage counts the number of Pickup signals during the intermittent ground fault. With the operate of the stage this number is logged via the information No.
Page 547 Protection and Automation Functions 6.13 Non-Directional Intermittent Ground-Fault Protection the signals of these functions after detection of an intermittent ground fault (signal Intermittent gnd.flt. ). The special mechanism is applied for the following listed functions and other functions are not influenced: •...
Page 548: Application And Setting Notes
Protection and Automation Functions 6.13 Non-Directional Intermittent Ground-Fault Protection Information Target Processing of Signal Status Changes Communication interface IEC 61850-8-1 Client/Server Special buffering mechanism IEC 60870-5-103/104 DNP V3.0 Protection interface Pass through IEC 61850-8-1 GOOSE Pass through Pass through LEDs Pass through Binary output Pass through...
Page 549: Settings
Protection and Automation Functions 6.13 Non-Directional Intermittent Ground-Fault Protection Parameter: Sum of extended PU times • Default setting (_:11341:103) Sum of extended PU times = 20 s With the Sum of extended PU times parameter, you set the threshold value for the integrator. If the integration reaches Sum of extended PU times, the stage operates if the pickup state is present.
Page 550: Information List
Protection and Automation Functions 6.13 Non-Directional Intermittent Ground-Fault Protection Addr. Parameter Setting Options Default Setting _:11341:3 Stage 1:Threshold 1 A @ 100 Irated 0.030 A to 35.000 A 1.000 A 5 A @ 100 Irated 0.15 A to 175.00 A 5.00 A 1 A @ 50 Irated 0.030 A to 35.000 A...
Page 551: Directional Intermittent Ground-Fault Protection
Protection and Automation Functions 6.14 Directional Intermittent Ground-Fault Protection 6.14 Directional Intermittent Ground-Fault Protection Overview of Functions 6.14.1 The function Directional intermittent ground-fault protection: • Detects the intermittent ground faults in grounded, compensated, or isolated cable systems selectively • Can be operated in 2 different modes: –...
Page 552: Stage Description
Protection and Automation Functions 6.14 Directional Intermittent Ground-Fault Protection Stage Description 6.14.3 Overview [LoOverview, 1, en_US] Figure 6-115 Logic of the Directional Intermittent Ground-Fault Protection Blocking of the Stage with Measuring-Voltage Failure The stage can be blocked if a measuring-voltage failure occurs. In the event of blocking, the picked up stage will be reset.
Page 553 Protection and Automation Functions 6.14 Directional Intermittent Ground-Fault Protection Logic for Direction Determination and Pulse Counting [LoIntdir1, 2, en_US] Figure 6-116 Logic Diagram of Direction Determination and Pulse Counting The input signal 3 is from Figure 6-117. Measurement Values for Direction Determination The function Directional intermittent ground-fault protection uses the zero-sequence active energy to determine the direction of the ground-current pulse.
Page 554 Protection and Automation Functions 6.14 Directional Intermittent Ground-Fault Protection Direction Determination and Pulse Counting When the RMS value of 3I0 exceeds the set threshold value (signal no. 3 in Figure 6-116), the direction deter- mination process is started and is continuously carried out until the function resets. At first, the current pulse (current peak) detection takes place.
Page 555 Protection and Automation Functions 6.14 Directional Intermittent Ground-Fault Protection Pickup, Operate, and Reset logic for the Counter Mode [LoIntdir2, 3, en_US] Figure 6-117 Pickup, Operate, and Reset Logic in Operating Mode Counter The internal signal 4 is from Figure 6-116. SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 556 Protection and Automation Functions 6.14 Directional Intermittent Ground-Fault Protection Pickup, Operate, and Reset logic for the Integrator and Counter Mode [LoIntdir3, 4, en_US] Figure 6-118 Pickup, Operate, and Reset Logic in Operating Mode Integrator and Counter The internal signal 4 and 5 are from Figure 6-116.
Page 557 Protection and Automation Functions 6.14 Directional Intermittent Ground-Fault Protection Intermittent Ground-Fault Indication The stage counts the 3I0 pulses. If the sum of forward pulse counts, reverse counts, and directional undefined counts is equal to or greater than No.of pulses for interm.GF, the signal Intermittent gnd.flt.
Page 558: Application And Setting Notes
Protection and Automation Functions 6.14 Directional Intermittent Ground-Fault Protection Fault Log and Fault Recording You can select between the ground-fault log without fault recording or the normal fault log with fault recording. If you set the parameter Operate & flt.rec. blocked to yes, the operate of the stage and fault recording are blocked and the information automatically appears in the ground-fault log.
Page 559 Default setting (_:16291:104) No.of pulses for interm.GF = 3 With the parameter No.of pulses for interm.GF, you set the total number of pulse counts (forward, reverse and non-dir. pulses) at which the ground fault is considered to be intermittent. Siemens recommends using the default setting.
Page 560: Settings
Consider that a permanent intermittent ground fault will cause many current pulses. If no time-grading considerations are required, Siemens recommends using a value in the range of 10 to 20. The integrator and the counter are the determining operate...
Page 561: Information List
Protection and Automation Functions 6.14 Directional Intermittent Ground-Fault Protection Addr. Parameter Setting Options Default Setting • _:16291:102 Stage 1:Pickup mode with 3I0> with 3I0> • with direction • _:16291:103 Stage 1:Operating mode Counter Counter • Integrator and counter _:16291:3 Stage 1:Threshold 1 A @ 100 Irated 0.030 A to 35.000 A 1.000 A 5 A @ 100 Irated 0.15 A to 175.00 A...
Page 562: Sensitive Ground-Fault Detection
Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection 6.15 Sensitive Ground-Fault Detection Overview of Functions 6.15.1 2 functions are available for ground-fault detection: a directional one and a non-directional one. The Directional sensitive ground-fault detection (ANSI 67Ns) serves: • For directional detection of permanent ground faults in isolated or resonant-grounded systems •...
Page 563 Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection [DwStrGFP-250113-01, 5, en_US] Figure 6-119 Structure/Embedding of the Directional Function in Protection Function Groups Non-Directional Sensitive Ground-Fault Detection The Non-directional sensitive ground-fault detection function can be used in protection function groups that only make the zero-sequence system (3I0) available. The function comes factory-set with a non-direc- tional 3I0>...
Page 564: General Functionality
Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection [DwSGFPu4-230113-01, 4, en_US] Figure 6-120 Structure/Embedding of the Non-Directional Function in Protection Function Groups General Functionality 6.15.3 6.15.3.1 Description Logic [LoGFPger-280113-01, 6, en_US] Figure 6-121 Logic Diagram of the Cross-Stage Functionality of the Directional Function SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 565 Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection [logfpnon-261012-01.tif, 4, en_US] Figure 6-122 Logic Diagram of the Cross-Stage Functionality of the Non-Directional Function Operational Measured Value φ(I,V) The function block calculates the angle between IN and V0 and makes the angle available as function meas- ured value Phi(I,V) .
Page 566 Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection [dwerdwdl-110512-01.tif, 1, en_US] Figure 6-124 Correction of the Transmission Characteristic Curve of a Core Balance Current Transformer Ground-Fault Indication, Stabilization at Intermittent Ground Fault The indication Ground fault indicates the ground fault and manages the ground-fault log (see Ground- Fault Log, Page 566).
Page 567: Application And Setting Notes
Indication: Ground fault To indicate the ground fault and its direction via the protocol, Siemens recommends using the indication 2311:302) Ground fault . The indication contains the direction information, independent of the parame- terized working direction of a stage. And this indication is also stabilized against a flood of indications in case of an intermittent ground fault.
Page 568: Informationen
Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection Addr. Parameter Setting Options Default Setting _:2311:103 General:Core balance 1 A @ 100 Irated 0.030 A to 35.000 A 0.050 A CT- current 1 5 A @ 100 Irated 0.15 A to 175.00 A 0.25 A 1 A @ 50 Irated 0.030 A to 35.000 A...
Page 569 Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection [logfp3i0f-280314-01, 4, en_US] Figure 6-126 Logic Diagram of the Directional 3I0 Stage with Cos φ or Sin φ Measurement Measured Value V0, Method of Measurement The device can measure the residual voltage at the broken-delta winding. The measured voltage VN is converted to a value with reference to the zero-sequence voltage V0.
Page 570 Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection Depending on the setting of the Connection type parameter of the measuring point I-3ph as well as the current terminal block used, the following different linearity and settings ranges result in addition to the common application: Connection Type of Current Threshold 3I0/IN...
Page 571 Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection [dwcosphi-171012-01.tif, 3, en_US] Figure 6-127 Direction-Characteristic Curve with Cos φ Measurement The zero-sequence voltage V0 is basically the reference value for the real axis. The axis of symmetry of the direction-characteristic curve coincides with the 3I0reactive axis for this example. For the direction determina- tion, basically the portion of the current vertical to the set direction-characteristic curve (= axis of symmetry) is decisive (3I0 dir.).
Page 572 Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection [dwphicor-171012-01.tif, 2, en_US] Figure 6-128 Turning the Direction-Characteristic Curves with Cos φ Measurement with Angle Correction If you set the Dir. measuring method parameter to sin φ and the φ correction parameter to 0, the symmetry axis of the direction-characteristic curve coincides with the 3I0active axis and the V0 axis.
Page 573 Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection [dwsinphi-011112-01.tif, 4, en_US] Figure 6-129 Direction-Characteristic Curve with Sin φ Measurement Blocking the Stage via Binary Input Signal You can block the stage externally or internally via the binary input signal >Block stage . In the event of blocking, the picked up stage will be reset.
Page 574: Application And Setting Notes
With the Blk. w. inrush curr. detect.parameter, you specify whether the operate is blocked during detection of an inrush current. Siemens recommends disabling the blocking. The fundamental component of the zero-sequence voltage is a reliable criterion for the ground fault and remains unaffected by an enabling procedure.
Page 575 Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection Parameter: Dir. measuring method, φ correction, Min.polar.3I0> for dir.det., 3I0> threshold value • Default setting (_:12601:109) Dir. measuring method = cos φ • Default setting (_:12601:107) φ correction = 0.0° • Default setting (_:12601:102) Min.polar.3I0> for dir.det. = 0.030 A •...
Page 576: Settings
With the α1 reduction dir. area and α2 reduction dir. area parameters, you specify the angle for the limitation of the direction range. Siemens recommends using the default setting of 2°. In an arc-suppression-coil-ground system in feeders with a very large reactive current, it can be practical to set a somewhat larger angle α1 to avoid a false pickup based on transformer and algorithm tolerances.
Page 577: Information List
Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection Addr. Parameter Setting Options Default Setting • _:12601:110 3I0> cos/sinφ1:Blk. after • fault extinction • _:12601:108 3I0> cos/sinφ1:Direc- forward forward • tional mode reverse • _:12601:109 3I0> cos/sinφ1:Dir. cos φ cos φ •...
Page 578: Directional Transient Ground-Fault Stage
Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection Directional Transient Ground-Fault Stage 6.15.5 6.15.5.1 Description Overview Ground faults occurring in arc-suppression-coil-ground systems often extinguish a short time after the igni- tion, mostly within a few milliseconds. Such transient occurrences are called transient ground faults. In order to detect the ground-fault direction, based on these transient occurrences, a special method of measurement is required that can also capture high frequencies.
Page 579 Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection Logic of the Transient Ground-Fault Functionality [lowisfut-240113-01.tif, 7, en_US] Figure 6-131 Logic Diagram of the Directional Transient Ground-Fault Stage Measured Values, Method of Measurement The zero-sequence values of zero-sequence voltage and zero-sequence current are measured directly or calcu- lated from the phase variables.
Page 580 Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection Determining the Time of the Ground-Fault Ignition The algorithm uses the evaluation of the instantaneous values of the zero-sequence voltage to verify continu- ously whether a ground fault occurred. This takes place regardless of whether the set threshold value for V0 is exceeded.
Page 581 Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection The following mechanisms are applied: • For reporting the direction result, the fundamental-component value of the zero-sequence voltage must exceed the V0> threshold value in a time slot of 100 ms after the ground-fault ignition. This effec- tively suppresses wrong indications as a result of switching operations.
Page 582: Application And Setting Notes
>Open of the function block Voltage-transformer circuit breaker is linked with the voltage-transformer circuit breaker. Parameter Value Description The protection stage is blocked (= default setting). Siemens recommends using the default setting. The protection stage is not blocked. SIPROTEC 5, Overcurrent Protection, Manual...
Page 583 The reason for an overfunction is a slower attenuation in the zero-sequence system following the fault extinction. Siemens recommends keeping this default setting if the stage is used for tripping. To protect against intermittent ground faults, the stage uses the parameter Dropout delay to delay a dropout due to fault extinction.
Page 584: Settings
0 sec Maximum operational V0 = 2.887 V ⋅ 1.2 = 3.464V In most cases, the operational zero-sequence voltages are smaller than 2.500 V. Siemens recommends using the default value of 3.000 V. Parameter: 3I0> threshold value • Default setting (_:13021:104) 3I0> threshold value = 0.030 A The setting is significant only for optional trip logic for switching off permanent ground faults.
Page 585: Information List
Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection Addr. Parameter Setting Options Default Setting • _:13021:10 Trans.Gnd.flt1:Blk. by • meas.-volt. failure • _:13021:107 Trans.Gnd.flt1:Blk. after • fault extinction • _:13021:108 Trans.Gnd.flt1:Operate • functionality • _:13021:106 Trans.Gnd.flt1:Direc- forward forward • tional mode reverse _:13021:103 Trans.Gnd.flt1:V0>...
Page 586: Directional 3I0 Stage With Φ(V0,3I0) Measurement
The current peaks show a clear ohmic component. With these parameters, you can limit the direction characteristic and ensure a reliable direction result. Siemens recommends setting both parameters to 10°. • Parameter: (_:12601:110) Blk. after fault extinction To make possible a continuous and immediate detection of the current peaks, you must switch off the blocking after fault suppression.
Page 587 Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection [lo_dir sens GFP 3I0 phi VI, 5, en_US] Figure 6-134 Logic Diagram of the Directional 3I0 Stage with φ (V0,3I0) Measurement Measured Value V0, Method of Measurement The device can measure the residual voltage at the broken-delta winding. The measured voltage is converted to a value with reference to the zero-sequence voltage V0.
Page 588 Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection Ground-Fault Detection, Pickup If the absolute value of the ground current 3I0 vector exceeds the threshold value 3I0> threshold value and the absolute value of the zero-sequence voltage V0 vector exceeds the threshold value Min. V0> for dir.
Page 589: Application And Setting Notes
>open of the function block Voltage-transformer circuit breaker is connected to the voltage-transformer circuit breaker. Parameter Value Description The protection stage is blocked (= default setting). Siemens recommends using the default setting. The protection stage is not blocked. Parameter: Blk. w. inrush curr. detect.
Page 590 Dir. determination delay parameter to achieve steady-state measurands. The dura- tion of the transient cycle is determined from the system conditions and the respective fault characteristics. If you have no knowledge of a suitable time delay, Siemens recommends keeping the default setting. Parameter: Operate delay •...
Page 591: Settings
Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection The Operate delay parameter determines the time during which the pickup conditions must be met to issue the operate indication. The operate indication is issued when this time expires. 6.15.7.3 Settings Addr. Parameter Setting Options Default Setting...
Page 592: Directional Y0 Stage With G0 Or B0 Measurement
Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection Directional Y0 Stage with G0 or B0 Measurement 6.15.8 6.15.8.1 Description [LoY0G0B0-300713-01, 5, en_US] Figure 6-136 Logic Diagram of the Directional Y0 Stage with G0 or B0 Measurement Measured Value V0, Method of Measurement The device can measure the residual voltage at the broken-delta winding.
Page 593 Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection The method of measurement processes the sampled voltage values and filters out the fundamental compo- nent numerically. Measured Value 3I0, Method of Measurement The function usually evaluates the ground current 3I0 sensitively measured via a core balance current trans- former.
Page 594 Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection The zero-sequence voltage V0 is generally the reference value for the real axis and is identical to the G0 axis. The axis of symmetry of the direction-characteristic curve coincides with the B0 (reactive) axis for this example.
Page 595 Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection [DwSiCoY0-011112-01, 1, en_US] Figure 6-139 Direction-Characteristic Curve for the B0 Measurement Blocking the Stage via Binary Input Signal You can block the stage externally or internally via the binary input signal >Block stage . In the event of blocking, the picked up stage will be reset.
Page 596: Application And Setting Notes
With the Blk. w. inrush curr. detect. parameter, you specify whether the operate is blocked during detection of an inrush current. Siemens recommends disabling the blocking. The fundamental component of the zero-sequence voltage is a reliable criterion for the ground fault and remains untouched by an enabling procedure.
Page 597 Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection These parameters are used to define the direction characteristic of the stage. The direction characteristic to use is dependent on the neutral-point treatment of the system. Note that, for the direction determination, basically only the component of the admittance perpendicular to the set direction-characteristic curve is decisive, see chapter 6.15.8.1 Description.
Page 598 Recommended setting value (_:106) α2 reduction dir. area = 2° With the α1 reduction dir. area and α2 reduction dir. area parameters, you specify the angle for the limitation of the direction range. Siemens recommends using the default setting of 2°. SIPROTEC 5, Overcurrent Protection, Manual...
Page 599: Settings
Dir. determination delay parameter to achieve steady-state measurands. The duration of the transient cycle is determined from the system conditions and the respective fault charac- teristics. If you have no knowledge of a suitable time delay, Siemens recommends keeping the default setting. Parameter: Operate delay •...
Page 600: Information List
Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection Addr. Parameter Setting Options Default Setting _:101 Y0> G0/B0 #:3I0> 1 A @ 100 Irated 0.030 A to 35.000 A 0.030 A release thresh. value 5 A @ 100 Irated 0.15 A to 175.00 A 0.15 A 1 A @ 50 Irated 0.030 A to 35.000 A...
Page 601 Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection Logic [lo_sensGFP V0 dir harmonic, 1, en_US] Figure 6-140 Logic Diagram of the Directional Stage with Phasor Measurement of a Harmonic SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 602 Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection [lo_start condition and dir. determ, 1, en_US] Figure 6-141 Logic Diagram of the Start Conditions and of the Direction Determination Measured Values, Methods of Measurement The device can measure the residual voltage at the broken-delta winding. The measured voltage is converted to a value with reference to the zero-sequence voltage V0.
Page 603 Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection To carry out the direction determination, the following condition must also be met in addition to the preceding 2 conditions: The zero-sequence harmonic voltage V0harm. must exceed the threshold which is 0.02 % of the secondary rated voltage of the voltage transformer.
Page 604 Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection Stabilization Counter To determine a reliable direction result, the function uses a stabilization counter. For indicating a direction result, the determined direction must be stable for 4 successive measuring cycles. The cycle time is 10 ms. Direction-Result Extension With the timer Dir.-result extension, you can extend the last determined direction result if the condi- tions for a further direction determination are no longer met.
Page 605: Application And Setting Notes
This parameter needs to be set according to the experience from the specific network. This requires the anal- ysis of permanent ground faults from the network. If such information is unavailable, Siemens recommends a rather low setting in the area of 5 mA to 10 mA secondary.
Page 606 >Open of the function block Voltage-transformer circuit breaker is connected to the voltage-transformer circuit breaker. Parameter Value Description The protection stage is blocked (= default setting). Siemens recommends using the default setting. The protection stage is not blocked. SIPROTEC 5, Overcurrent Protection, Manual...
Page 607: Settings
Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection 6.15.9.3 Settings Addr. Parameter Setting Options Default Setting V0>dir.harm.# • V0>dir.harm.#:Mode • • test • V0>dir.harm.#:Operate • & flt.rec. blocked • _:10 V0>dir.harm.#:Blk. by • meas.-volt. failure • _:106 V0>dir.harm.#:Direc- non-directional forward •...
Page 608: Non-Directional V0 Stage With Zero-Sequence Voltage/Residual Voltage
Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection Information Data Class Type (Type) _:306 V0>dir.harm.#:3I0 harm. 6.15.10 Non-Directional V0 Stage with Zero-Sequence Voltage/Residual Voltage 6.15.10.1 Description Logic [lo_gfps v0, 4, en_US] Figure 6-143 Logic Diagram of the Non-Directional V0 Stage with Zero-Sequence Voltage/Residual Voltage SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 609: Application And Setting Notes
Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection Measured Value, Method of Measurement The device can measure the residual voltage at the broken-delta winding. The measured voltage VN is converted to a value with reference to the zero-sequence voltage V0. If the residual voltage is not available to the device as a measurand, the zero-sequence voltage V0 is calculated from the measured phase-to-ground voltages V , and V...
Page 610 20 V and 40 V. A higher sensitivity (= lower threshold value) can be necessary for high fault resistances. • Siemens recommends setting a more sensitive (smaller) value in grounded systems. This value must be higher than the maximum residual voltage anticipated during operation caused by system unbalances.
Page 611 = 100 V, the value has to be set to 70 rated V, for example. Siemens recommends using the default setting V> healthy ph-to-gnd volt. = 70 V. Operation as Supervision Function If you want the stage to have a reporting effect only, the generation of the operate indication and fault logging can be disabled via the Operate &...
Page 612: Settings
Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection 6.15.10.3 Settings Addr. Parameter Setting Options Default Setting V0> 1 • _:12391:1 V0> 1:Mode • • test • _:12391:2 V0> 1:Operate & flt.rec. • blocked • _:12391:10 V0> 1:Blk. by meas.-volt. • failure •...
Page 613 Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection Logic [lo_sensitive ground-current protection 3I0, 2, en_US] Figure 6-144 Logic Diagram of the Non-Directional 3I0 Stage Measured Value 3I0 The function usually evaluates the sensitively measured ground current 3I0 via a core balance current trans- former.
Page 614: Application And Setting Notes
Select this method of measurement if harmonics or transient current peaks fundamental comp. are to be suppressed. Siemens recommends using this method as the standard method. Select this method of measurement if you want the stage to take harmonics RMS value into account (for example, at capacitor banks).
Page 615: Settings
Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection With the parameter Pickup delay you set whether pickup of the stage is to be delayed or not. If the tran- sient cycle of the ground fault occurrence should not be evaluated, set a delay of 100 ms, for example. Parameter: Operate delay •...
Page 616 Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection Logic [logfpsy0-240614-01.vsd, 2, en_US] Figure 6-145 Logic Diagram of the Non-Directional Y0 Stage Measured Value V0, Method of Measurement The device can measure the residual voltage at the broken-delta winding. The measured voltage VN is converted to a value with reference to the zero-sequence voltage V0.
Page 617 Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection Measured Value 3I0, Method of Measurement The function usually evaluates the sensitively measured ground current 3I0 via a core balance current trans- former. Since the linearity range of the sensitive measuring input ends at approx. 1.6 A, for larger secondary ground currents, the function switches to the 3I0 current calculated from the phase currents.
Page 618: Application And Setting Notes
Parameter Value Description The protection stage is blocked (= default setting). Siemens recommends using the default setting. The protection stage is not blocked. Parameter: Blk. w. inrush curr. detect. • Default setting (_:27) Blk. w. inrush curr. detect. = no With the Blk.
Page 619: Settings
Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection Parameter: Pickup delay • Default setting (_:103) Pickup delay = 0.00 s With the parameter Pickup delay, you set whether pickup of the stage is to be delayed or not. If the tran- sient cycle of the ground fault occurrence should not be evaluated, set a delay of 100 ms, for example.
Page 620 Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection The following figure shows a simplified network that applies the pulse-pattern detection method. The pulse pattern in the ground current 3I0 is generated by switching on and off a capacitor in parallel to the arc-suppression coil: •...
Page 621 Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection [dw_pulse pattern in overcompensation network, 1, en_US] Figure 6-147 Current Pulse Pattern in the Overcompensated System For the faulty feeder, the current pulse pattern is as follows: • When the clocking pulse is on, the capacitor is switched on, the zero-sequence current 3I0 in the faulty feeder is reduced, and the corresponding current pulse pattern is off.
Page 622 Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection Logic [lo_sensGFP pulse detection, 1, en_US] Figure 6-148 Logic Diagram of the Pulse-Pattern Detection Stage Measured Value V0, Method of Measurement The device can measure the residual voltage at the broken-delta winding. The measured voltage VN is converted to a value with reference to the zero-sequence voltage V0.
Page 623 Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection The method of measurement processes the sampled current values and filters out the fundamental compo- nent numerically. Depending on the connection type of the measuring point as well as the current terminal blocks used, different linearity and setting ranges result.
Page 624: Application And Setting Notes
Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection Dropout Delay Switching on the capacitor usually causes 3I0 to decrease in the faulty feeder. This must not cause the stage to drop out. For that reason, a dropout delay is active for the sum of the Pulse-on duration and Pulse-off duration values.
Page 625 Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection EXAMPLE Clocking device: Set pulse-on duration for the clocking device 1.00 s Max. tolerance pulse-on duration of the clocking device 70 ms Set pulse-off duration for the clocking device 1.50 s Max. tolerance pulse-off duration of the clocking device 110 ms Larger tolerance of both 110 ms...
Page 626 Then the setting of the 3I0 delta pulse off-on parameter is calculated as follows: [fo_delta calculate, 1, en_US] If the network information for the setting calculation is not available, Siemens recommends using the default setting of 10 %. Parameter: No. of pulses for operate, Monitoring time(in pulses) •...
Page 627: Settings
Protection and Automation Functions 6.15 Sensitive Ground-Fault Detection 6.15.13.3 Settings Addr. Parameter Setting Options Default Setting Pulse detect.# • Pulse detect.#:Mode • • test • Pulse detect.#:Operate & • flt.rec. blocked _:102 Pulse detect.#:V0> 0.300 V to 200.000 V 30.000 V threshold value _:101 Pulse detect.#:3I0>...
Page 628: Undercurrent Protection
Protection and Automation Functions 6.16 Undercurrent Protection 6.16 Undercurrent Protection Overview of Functions 6.16.1 The Undercurrent protection function (ANSI 37): • Detects the going current in a feeder after the opening of the infeed circuit breaker • Detects the loss of loads •...
Page 629: Stage Description
Protection and Automation Functions 6.16 Undercurrent Protection Stage Description 6.16.3 Logic of the Stage [loundcur-200713-01.tif, 1, en_US] Figure 6-151 Logic Diagram of the Undercurrent Protection Method of Measurement You use the Method of measurement parameter to define whether the stage uses the fundamental comp.
Page 630: Application And Setting Notes
(standard method) or the calculated RMS value. Parameter Value Description Select this method of measurement if harmonics or transient current peaks fundamental comp. are to be suppressed. Siemens recommends using this method as the standard method. SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 631: Settings
Protection and Automation Functions 6.16 Undercurrent Protection Parameter Value Description Select this method of measurement if you want the stage to take harmonics RMS value into account (for example, at capacitor banks). Consider that aperiodic DC components present in the secondary circuit are measured and can cause an overfunction.
Page 632: Information List
Protection and Automation Functions 6.16 Undercurrent Protection Information List 6.16.6 Information Data Class Type (Type) Group indicat. _:4501:55 Group indicat.:Pickup _:4501:57 Group indicat.:Operate Stage 1 _:13051:81 Stage 1:>Block stage _:13051:54 Stage 1:Inactive _:13051:52 Stage 1:Behavior _:13051:53 Stage 1:Health _:13051:55 Stage 1:Pickup _:13051:56 Stage 1:Operate delay expired _:13051:57...
Page 633: Negative-Sequence Protection
Protection and Automation Functions 6.17 Negative-Sequence Protection 6.17 Negative-Sequence Protection Overview of Functions 6.17.1 The function Negative-sequence protection (ANSI 46): • Detects 1-phase or 2-phase short circuits in the electrical power system with clearly increased sensitivity compared to the classical overcurrent protection •...
Page 634: General Functionality
Protection and Automation Functions 6.17 Negative-Sequence Protection General Functionality 6.17.3 6.17.3.1 Description Logic The following figure represents the logic of the general functionality which applies across all configured stages. It contains: • Selection of the reference value • Current-release criterion [lo_General Functionality.vsd, 1, en_US] Figure 6-153 Logic Diagram of the General Functionality...
Page 635 Protection and Automation Functions 6.17 Negative-Sequence Protection Parameter Value Description The negative-sequence current is referred to the rated current of the rated, obj protected object. This is a preferred normalization for electrical machines, because the permissible limiting values are indicated exclusively referred to the machine rated current.
Page 636: Stage With Definite-Time Characteristic Curve
Protection and Automation Functions 6.17 Negative-Sequence Protection Stage with Definite-Time Characteristic Curve 6.17.4 6.17.4.1 Stage Description Logic of a Stage [logiknsp-070312-01.tif, 2, en_US] Figure 6-154 Logic Diagram of the Stage Negative-Sequence Protection with Definite-Time Characteristic Curve Method of Measurement The fundamental phasors are calculated from the 3-phase phase currents. Based on this, the negative- sequence system and the positive-sequence system are calculated.
Page 637: Application And Setting Notes
Protection and Automation Functions 6.17 Negative-Sequence Protection corresponding indication. If the blocking drops out and the threshold value of the stage is still exceeded, the tripping delay (time delay) is started. After that time, the stage operates. 6.17.4.2 Application and Setting Notes Parameter: Threshold •...
Page 638: Information List
Protection and Automation Functions 6.17 Negative-Sequence Protection Addr. Parameter Setting Options Default Setting • _:1981:104 Definite-T 1:Blk. w. • inrush curr. detect. _:1981:101 Definite-T 1:Dropout 0.00 s to 60.00 s 0.00 s delay _:1981:6 Definite-T 1:Operate 0.00 s to 60.00 s 1.50 s delay Definite-T 2...
Page 639: Stage With Inverse-Time Characteristic Curve
Protection and Automation Functions 6.17 Negative-Sequence Protection Stage with Inverse-Time Characteristic Curve 6.17.5 6.17.5.1 Description Logic of a Stage [lo_NSP_Inverse, 1, en_US] Figure 6-155 Logic Diagram of the Negative-Sequence Protection with Inverse-Time Characteristic Curve Method of Measurement The fundamental phasors are calculated from the 3-phase phase currents. Based on this, the negative- sequence system and the positive-sequence system are calculated.
Page 640: Application And Settings Notes
Protection and Automation Functions 6.17 Negative-Sequence Protection parameters. You can select between instantaneous dropout (totalized time is deleted) or dropout according to the characteristic curve (reduction of totalized time depending on the characteristic curve). The dropout according to characteristic curve (disk emulation) is the same as turning back a rotor disk. The weighted reduction of the time is initiated from 0.9 of the set threshold value.
Page 641: Settings
Protection and Automation Functions 6.17 Negative-Sequence Protection With the parameter Blk. w. inrush curr. detect., the stage can be stabilized against tripping on transformer-inrush currents. If transformers are parts of the protection zones, set this parameter to yes. Settings 6.17.5.3 Addr.
Page 642: Directional Negative-Sequence Protection
Protection and Automation Functions 6.18 Directional Negative-Sequence Protection 6.18 Directional Negative-Sequence Protection Overview of Functions 6.18.1 The function Directional negative-sequence protection with current-independent time delay (ANSI 46) serves as the backup short-circuit protection for unbalanced faults. With the negative-sequence system, various supervision and protection tasks can be realized, for example: •...
Page 643 Protection and Automation Functions 6.18 Directional Negative-Sequence Protection [lostensp-070611-01.tif, 1, en_US] Figure 6-157 Stage Control of the Directional Negative-Sequence System Protection In addition to the generally valid stage control, the stage is blocked in the event of a measuring voltage failure, provided the stage is working directionally.
Page 644 Protection and Automation Functions 6.18 Directional Negative-Sequence Protection Logic of the Stage [lonspdir-300112-01.tif, 1, en_US] Figure 6-158 Logic Diagram of the Function Directional Negative-Sequence System Protection with Current- Independen Time Delay Measurand The negative-sequence current I2 is used as a measurand. From the 3-phase currents, the fundamental phasors are determined via a 1-cycle filter and, corresponding with the definition equation of the symmetrical components, the negative-sequence system is calculated from this.
Page 645 Protection and Automation Functions 6.18 Directional Negative-Sequence Protection Functioning The stage picks up if the negative-sequence system current exceeds the set threshold value and the parame- terized direction agrees with the measured direction. The pickup drops out if the negative-sequence system current falls below 95 % of the set threshold.
Page 646 Protection and Automation Functions 6.18 Directional Negative-Sequence Protection [dwphasor-140212-01.tif, 1, en_US] Figure 6-160 Phasor Diagram for Direction Determination with Negative-Sequence System Values If the device determines a fault in the voltage-transformer secondary circuit (through the binary input voltage transformer circuit-breaker dropout or through measuring-voltage failure detec- tion), direction determination will be disabled and every directionally set stage will be blocked.
Page 647: Application And Setting Notes For Direction Determination
With the parameters Angle forward α and Angle forward β, you can change the location of the direc- tional characteristic curve. Siemens recommends using the defaults, because the function with these settings reliably determines the direction. Parameter: Minimum Negative-Sequence System Variables V2 and I2 •...
Page 648 Protection and Automation Functions 6.18 Directional Negative-Sequence Protection Parameter Value Description Select these settings if the stage is only to work in a forward direction (in direc- forward tion of the line). Select this setting if the level is only to work in the reverse direction (in the reverse direction of the busbar).
Page 649: Settings
Description. The threshold value increases as the phase currents increase. You can change the stabilization factor (= gradient) via the Stabiliz. w. phase current parameter. Siemens recommends a default setting of 10 % under normal operations. Parameter: Threshold • Default setting (_:8101:3) Threshold = 1.5 A Define the pickup value corresponding to the application.
Page 650: Information List
Protection and Automation Functions 6.18 Directional Negative-Sequence Protection Addr. Parameter Setting Options Default Setting • _:8101:114 Definite-T 1:Directional non-directional forward • mode forward • reverse _:8101:111 Definite-T 1:Stabiliz. w. 0 % to 30 % 10 % phase current _:8101:3 Definite-T 1:Threshold 1 A @ 100 Irated 0.030 A to 35.000 A 1.500 A 5 A @ 100 Irated 0.15 A to 175.00 A...
Page 651: Thermal Overload Protection, 3-Phase - Advanced
Protection and Automation Functions 6.19 Thermal Overload Protection, 3-Phase - Advanced 6.19 Thermal Overload Protection, 3-Phase - Advanced Overview of Functions 6.19.1 The Thermal overload protection, 3-phase – advanced function (ANSI 49) is used to: • Protect the equipment (motors, generators, transformers, capacitors, overhead lines, and cables) against thermal overloads •...
Page 652: Application And Setting Notes
Protection and Automation Functions 6.19 Thermal Overload Protection, 3-Phase - Advanced Logic [lo_TOLP_FilterStage, 1, en_US] Figure 6-163 Logic Diagram of the Function Block Filter The FIR filter gains the 8-kHz sampled values according to the set filter coefficients. Afterwards the RMS value is calculated.
Page 653: Settings
Protection and Automation Functions 6.19 Thermal Overload Protection, 3-Phase - Advanced With the parameter Enable filter, you set whether the Filter is enabled. Parameter Value Description If gained RMS values should be used in one of the protection stages, set parameter Enable filter = yes.
Page 654: Information List
Protection and Automation Functions 6.19 Thermal Overload Protection, 3-Phase - Advanced 6.19.3.4 Information List Information Data Class Type (Type) Filter _:301 Filter:Iph:A _:302 Filter:Iph:B _:303 Filter:Iph:C Stage with Thermal Overload Protection, 3-Phase - Advanced 6.19.4 6.19.4.1 Description Logic [lo_TOLP_withFilterstage, 2, en_US] Figure 6-164 Logic Diagram of the Thermal Overload Protection, 3-Phase - Advanced Stage SIPROTEC 5, Overcurrent Protection, Manual...
Page 655 Protection and Automation Functions 6.19 Thermal Overload Protection, 3-Phase - Advanced [lo_Stage Control, 1, en_US] Figure 6-165 Logic Diagram of the Stage Control RMS-Value Selection The protection function supports 2 kinds of RMS measurement: • Normal RMS value • Gained RMS value from the function block Filter The gained RMS value is automatically used if the function block Filter is configured and the filter has been enabled.
Page 656 Protection and Automation Functions 6.19 Thermal Overload Protection, 3-Phase - Advanced This factor indicates the maximum continuous permissible phase current. The factor refers to the rated current of the protected object (k = I rated, obj Rated current of the protected object rated, obj At the same time, I is the rated current of the assigned protected object side:...
Page 657 Protection and Automation Functions 6.19 Thermal Overload Protection, 3-Phase - Advanced Operate Curve If the ambient temperature is not measured and set to 40°C, you can get the operate curve as following: [foauslos-211010-01.tif, 1, en_US] Operate time τ Time constant Measured load current Preload current preload...
Page 658 Protection and Automation Functions 6.19 Thermal Overload Protection, 3-Phase - Advanced Dropout of Tripping Once the thermal memory has fallen below the setting value of the Dropout threshold operate , the trip command is canceled upon tripping. In contrast, the current-warning threshold and the thermal warning threshold are reduced at a fixed dropout threshold (see Technical Data).
Page 659: Application And Setting Notes
Protection and Automation Functions 6.19 Thermal Overload Protection, 3-Phase - Advanced 6.19.4.2 Application and Setting Notes Parameter: Threshold current warning • Default setting (_:101) Threshold current warning = 1.000 A at I = 1 A rated Set the threshold to the maximum permissible continuous current (I ).
Page 660 Protection and Automation Functions 6.19 Thermal Overload Protection, 3-Phase - Advanced In the case of cables, the permissible continuous current depends on the cross-section, insulation material, design type, and the manner in which the cables have been laid. In the case of overhead lines, an overload of 10 % is permissible.
Page 661 Protection and Automation Functions 6.19 Thermal Overload Protection, 3-Phase - Advanced Parameter: Imax thermal • Default setting (_:107) Imax thermal = 2.5 A at I = 1 A rated The Imax thermal parameter allows you to set the threshold current for the Behav. at I> Imax therm.
Page 662: Settings
No temperature sensor for measuring the ambient temperature is connected. • The temperature measurement is faulty and the last measured temperature value is less than the Default temperature. Siemens recommends using the default setting. Parameter: Minimal temperature • Default setting (_:117) Minimal temperature = -20°C If the measured ambient temperature drops below the set value, the set value is assumed as the ambient temperature.
Page 663: Information List
Protection and Automation Functions 6.19 Thermal Overload Protection, 3-Phase - Advanced Addr. Parameter Setting Options Default Setting _:101 49 Th.overl. #:Threshold 1 A @ 100 Irated 0.030 A to 35.000 A 1.000 A current warning 5 A @ 100 Irated 0.15 A to 175.00 A 5.00 A 1 A @ 50 Irated 0.030 A to 35.000 A...
Page 664 Protection and Automation Functions 6.19 Thermal Overload Protection, 3-Phase - Advanced Information Data Class Type (Type) _:54 49 Th.overl. #:Inactive _:52 49 Th.overl. #:Behavior _:53 49 Th.overl. #:Health _:301 49 Th.overl. #:Current warning _:302 49 Th.overl. #:Thermal warning _:303 49 Th.overl. #:Block close _:55 49 Th.overl.
Page 665: Thermal Overload Protection, User-Defined Characteristic Curve
Protection and Automation Functions 6.20 Thermal Overload Protection, User-Defined Characteristic Curve 6.20 Thermal Overload Protection, User-Defined Characteristic Curve Overview of Functions 6.20.1 The Thermal overload protection, user-defined characteristic curve function (ANSI 49) is used to: • Protect the equipment (motors, generators, and transformers) against thermal overloads •...
Page 666: Function Description
Protection and Automation Functions 6.20 Thermal Overload Protection, User-Defined Characteristic Curve Function Description 6.20.3 Logic [lo_TOLP_UserCurve_stage, 1, en_US] Figure 6-168 Logic Diagram of the Thermal Overload Protection, User-Defined Characteristic Curve Function The (_:101) Rated current parameter is from the protected object. The (_:104) Rated primary current parameter is from the used current transformer.
Page 667 Protection and Automation Functions 6.20 Thermal Overload Protection, User-Defined Characteristic Curve body model so that deviations can occur. The following figure shows an example of a predefined overload characteristic curve and 2 standard characteristic curves based on the single-body model. [dw_TOLP_UserCurve_characteristic, 1, en_US] Figure 6-169 User-Defined Characteristic Curve with Replica of Standard Characteristics...
Page 668 Protection and Automation Functions 6.20 Thermal Overload Protection, User-Defined Characteristic Curve Thermal Replica The protection function calculates the overtemperature from the phase currents on the basis of a thermal single-body model according to the thermal differential equation with [fo_TOLP_diffgl, 1, en_US] With the following standardization: [fo_TOLP_normie, 1, en_US] Θ...
Page 669 Protection and Automation Functions 6.20 Thermal Overload Protection, User-Defined Characteristic Curve The analysis of the RMS values of the currents over a broad frequency band also includes the harmonic components. These harmonic components contribute to the temperature rise of the equipment. Current Influence The thermal replica based on the single-body model applies only with limitations to high overcurrent situa- tions (short circuits, motor startup currents).
Page 670: Application And Setting Notes
Protection and Automation Functions 6.20 Thermal Overload Protection, User-Defined Characteristic Curve Functional Measured Values Values Description Primary Secondary % Referenced to (_:601:305) Time until trip Expected time until tripping (_:601:304) Time until close Time until close release (_:601:306) Overload phase A Thermal measured values of Tripping temperature the phases...
Page 671 Protection and Automation Functions 6.20 Thermal Overload Protection, User-Defined Characteristic Curve Parameter: Emerg. start T overtravel • Default setting (_:112) Emerg. start T overtravel = 300 s The Emerg. start T overtravel parameter is used to set the time for which blocking of the tripping has to remain active after an outgoing binary input signal >Emergency start.
Page 672 Protection and Automation Functions 6.20 Thermal Overload Protection, User-Defined Characteristic Curve Parameter: Cool-down factor Tau • Default value (_:108) Cool-down factor Tau = 7.0 If the current becomes lower than the setting value of the Imin cooling parameter, you can set the Cool- down factor Tau parameter to calculate the internal cooling time constant.
Page 673: Settings
Protection and Automation Functions 6.20 Thermal Overload Protection, User-Defined Characteristic Curve [dw_TOLP_Predefined curve, 1, en_US] Figure 6-171 Example of the User-Defined Characteristic Curve Settings 6.20.5 Addr. Parameter Setting Options Default Setting General • User charact.#:Mode • • test • User charact.#:Operate •...
Page 674: Information List
Protection and Automation Functions 6.20 Thermal Overload Protection, User-Defined Characteristic Curve Addr. Parameter Setting Options Default Setting _:107 User charact.#:Imin 1 A @ 100 Irated 0.000 A to 10.000 A 0.500 A cooling 5 A @ 100 Irated 0.00 A to 50.00 A 2.50 A 1 A @ 50 Irated 0.000 A to 10.000 A...
Page 675 Protection and Automation Functions 6.20 Thermal Overload Protection, User-Defined Characteristic Curve Information Data Class Type (Type) _:312 User charact.#:Equival. current phs C _:313 User charact.#:Equival. current max. SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 676: Thermal Overload Protection, 1-Phase
Protection and Automation Functions 6.21 Thermal Overload Protection, 1-Phase 6.21 Thermal Overload Protection, 1-Phase Overview of Functions 6.21.1 The Thermal overload protection 1-phase function (ANSI 49) is used to: • Protect the equipment (reactors or resistors in the neutral point of a transformer) from thermal overload Structure of the Function 6.21.2 The Thermal overload protection 1-phase function is used in 1-phase protection function groups with...
Page 677: Function Description
Protection and Automation Functions 6.21 Thermal Overload Protection, 1-Phase Function Description 6.21.3 Logic [lotolp1p-250713-01.tif, 2, en_US] Figure 6-173 Logic Diagram of the Thermal Overload Protection Function Thermal Replica The protection function calculates the overtemperature from the current flowing in the protected object (for example, reactor or resistance in the transformer neutral point) on the basis of a thermal single-body model according to the thermal differential equation with [fodiffgl-310510-01.tif, 2, en_US]...
Page 678 Protection and Automation Functions 6.21 Thermal Overload Protection, 1-Phase With the following standardization: [fonormie-310510-01.tif, 2, en_US] Θ Current overtemperature, in relation to the final temperature at a maximum permissible current k I rated, obj Θ Standardized ambient temperature, where ϑ describes the coupled ambient temperature.
Page 679 Protection and Automation Functions 6.21 Thermal Overload Protection, 1-Phase The current overtemperature can be obtained from the operational measured values. It is shown in percent. An indication of 100 % means that the thermal threshold has been reached. The analysis of the RMS value of the current over a broad frequency band also includes the harmonic compo- nents.
Page 680: Application And Setting Notes
Protection and Automation Functions 6.21 Thermal Overload Protection, 1-Phase Resetting the Thermal Map You can reset the thermal memory via the binary input indication >Reset thermal replica. The thermal memory will then have a 0 value. A reparameterization will also lead to resetting the thermal memory. Blocking the Function Blocking will cause a picked up function to be reset.
Page 681 The thermally permissible continuous current for the protected object is known from relevant tables or from the specifications of the manufacturer! Siemens recommends using the default value as it is a typical value for many applications. Parameter: Thermal time constant •...
Page 682 Protection and Automation Functions 6.21 Thermal Overload Protection, 1-Phase [dwtime-dependent-110815-01.vsd, 1, en_US] Parameter: Imax thermal • Recommended setting value (_:107) Imax thermal= 2.5 A for l = 1 A rated The Imax thermal parameter allows you to set the threshold current for the Behav. at I> Imax therm.
Page 683 Protection and Automation Functions 6.21 Thermal Overload Protection, 1-Phase [fo_ueb_for_Irated, 3, en_US] EXAMPLE: Temperature class B for continuous operation: permissible overtemperature = 80 K From this, a temperature for I of 120 °C (80 K + 40 °C) can be derived when using a measuring element for rated the measurement.
Page 684: Settings
A temperature sensor for measuring the ambient temperature is not connected. • The temperature measurement is interrupted and the measured temperature value is less than the Default temperature. Siemens recommends using the default setting. Parameter: Minimal temperature • Default setting (_:117) Minimal temperature = -20°C If the measured ambient temperature drops below the preset value, the set value will be assumed as the ambient temperature.
Page 685: Information List
Protection and Automation Functions 6.21 Thermal Overload Protection, 1-Phase Addr. Parameter Setting Options Default Setting _:117 49 Th.overl. #:Minimal -55°C to 40°C -20°C temperature _:44 49 Th.overl. #:Tempera- Setting options depend on ture sensor configuration Information List 6.21.6 Information Data Class Type (Type) 49 Th.overl.
Page 686: Unbalanced-Load Protection
Protection and Automation Functions 6.22 Unbalanced-Load Protection 6.22 Unbalanced-Load Protection Overview of Functions 6.22.1 The Unbalanced-load protection function detects unbalanced loads or line interruptions of electrical machines (generators and motors). Unbalanced loads create a counter-rotating magnetic field at double frequency in the rotor. The skin effect leads to local overheating on the surface of the rotor bars in the transi- tion between the slot wedges and the winding bundles.
Page 687: Function Description
Protection and Automation Functions 6.22 Unbalanced-Load Protection Function Description 6.22.3 Logic of the Stage [lounbala-090812-03.tif, 1, en_US] Figure 6-176 Logic Diagram of the Unbalanced-Load Protection Function Method of Measurement The stage uses the negative-sequence current I as a measurand. The negative-sequence current is calculated from the measured 3-phase currents according to the defining equation of symmetrical components.
Page 688 Protection and Automation Functions 6.22 Unbalanced-Load Protection [forbanl1-030812-02.tif, 1, en_US] With: Permissible time of the negative-sequence current I2Perm Unbalanced-load factor of the machine (parameter Unbalanced load factor K) Actual unbalanced-load current as a per unit value(negative-sequence current/rated rated,machine current of the machine) [dwunbalo-230913, 2, en_US] Figure 6-177 Operate Curve of the Unbalanced-Load Protection...
Page 689: Application And Setting Notes
Protection and Automation Functions 6.22 Unbalanced-Load Protection Cooling Time Thermal Replica The thermal replica starts to cool down as soon as the negative-sequence current I is lower than Max. continuously perm. I2. The thermal replica decreases according to the parameter Cooling time therm.replica.
Page 690 % is selected in the example. To avoid issuing the Warning indication too fast, Siemens recommends a longer delay. Setting the param- eter Warning delay in the range of 10 s to 20 s is practicable. 15 s is selected in the example.
Page 691: Settings
Protection and Automation Functions 6.22 Unbalanced-Load Protection EXAMPLE [forbala2-290812-02.tif, 1, en_US] Max. continuously perm. I = 10.0 % (corresponds to 0.1) Unbalanced load factor K = 15 s Cooling time therm. replica = 1500 s 6.22.5 Settings Addr. Parameter Setting Options Default Setting Therm.
Page 692: Overvoltage Protection With 3-Phase Voltage
Protection and Automation Functions 6.23 Overvoltage Protection with 3-Phase Voltage 6.23 Overvoltage Protection with 3-Phase Voltage Overview of Functions 6.23.1 The function Overvoltage protection with 3-phase voltage (ANSI 59) is used to: • Monitor the permissible voltage range • Protect equipment (for example, plant components, machines, etc.) against damages caused by over- voltage •...
Page 693: Stage With Definite-Time Characteristic Curve
Protection and Automation Functions 6.23 Overvoltage Protection with 3-Phase Voltage Stage with Definite-Time Characteristic Curve 6.23.3 6.23.3.1 Description Logic of the Stage [lo3phasi-090611-01.tif, 3, en_US] Figure 6-180 Logic Diagram of the Definite-Time Overvoltage Protection with 3-Phase Voltage Method of Measurement Use the Method of measurement parameter to define whether the stage uses the fundamental comp.
Page 694: Application And Setting Notes
Select this method of measurement to suppress harmonics or transient fundamental comp. voltage peaks. Siemens recommends this method of measurement as the default setting. Select this method of measurement if you want the stage to take harmonics RMS value into account (for example, at capacitor banks). Do not set the threshold value of the stage under 10 V for this method of measurement.
Page 695 1 out of 3 range. Siemens recommends 1 out of 3 as the default setting. This reflects how the function behaved in previous generations (SIPROTEC 4, SIPROTEC 3). Select this setting when using the stage to disconnect from the power 3 out of 3 system (in the case of wind farms, for example).
Page 696: Settings
Protection and Automation Functions 6.23 Overvoltage Protection with 3-Phase Voltage Stage Setting Values 1.5 V 0.1 s to 0.2 s rated 6.23.3.3 Settings Addr. Parameter Setting Options Default Setting Definite-T 1 • _:181:1 Definite-T 1:Mode • • test • _:181:2 Definite-T 1:Operate &...
Page 697 Protection and Automation Functions 6.23 Overvoltage Protection with 3-Phase Voltage Information Data Class Type (Type) _:181:53 Definite-T 1:Health _:181:55 Definite-T 1:Pickup _:181:300 Definite-T 1:Pickup loop AB _:181:301 Definite-T 1:Pickup loop BC _:181:302 Definite-T 1:Pickup loop CA _:181:56 Definite-T 1:Operate delay expired _:181:57 Definite-T 1:Operate Definite-T 2...
Page 698: Stage With Inverse-Time Characteristic Curve
Protection and Automation Functions 6.23 Overvoltage Protection with 3-Phase Voltage Stage with Inverse-Time Characteristic Curve 6.23.4 6.23.4.1 Description Logic of the Stage [lo3phinv, 2, en_US] Figure 6-181 Logic Diagram of the Inverse-Time Overvoltage Protection with 3-Phase Voltage Method of Measurement Use the Method of measurement parameter to define whether the stage uses the fundamental comp.
Page 699 Protection and Automation Functions 6.23 Overvoltage Protection with 3-Phase Voltage • Measurement RMS value : This method of measurement determines the voltage amplitude from the sampled values according to the defining equation of the RMS value. Harmonics are included in the analysis. Pickup Mode With the Pickup mode parameter, you define whether the protection stage picks up if all 3 measuring elements detect the overvoltage condition ( 3 out of 3 ) or if only 1 measuring element detects the over-...
Page 700 Protection and Automation Functions 6.23 Overvoltage Protection with 3-Phase Voltage The inverse-time characteristic is shown in the following figure. [dwovpinv, 2, en_US] Figure 6-182 Operate Curve of Inverse-Time Characteristic The inverse-time delay is calculated with the following formula: Where Inverse-time delay Time multiplier (parameter Time dial ) Measured voltage Threshold value (parameter Threshold )
Page 701: Application And Setting Notes
With the Pickup factor parameter, you modify the pickup value. To avoid a long-time operate delay after pickup when the measured value is slightly over the threshold, Siemens recommends using the default setting. Specify the Threshold (pickup threshold) and Pickup factor for the specific application.
Page 702: Settings
Under network conditions of intermittent faults or faults which occur in rapid succession, Siemens recom- mends setting the Reset time to an appropriate value (> 0 s) to ensure the operation. Otherwise Siemens recommends to keep the default value to ensure a fast reset of the function.
Page 703: Information List
Protection and Automation Functions 6.23 Overvoltage Protection with 3-Phase Voltage Addr. Parameter Setting Options Default Setting Inverse-T #:Threshold 0.300 V to 340.000 V 110.000 V _:101 Inverse-T #:Pickup factor 1.00 to 1.20 1.10 _:102 Inverse-T #:Charact. 0.00 to 300.00 1.00 constant k _:103 Inverse-T #:Charact.
Page 704: Overvoltage Protection With Zero-Sequence Voltage/Residual Voltage
Protection and Automation Functions 6.24 Overvoltage Protection with Zero-Sequence Voltage/Residual Voltage 6.24 Overvoltage Protection with Zero-Sequence Voltage/Residual Voltage Overview of Functions 6.24.1 The Overvoltage protection with zero-sequence voltage/residual voltage function (ANSI 59N): • Detects ground faults in isolated or arc-suppression-coil-grounded systems •...
Page 705: Stage Description
Protection and Automation Functions 6.24 Overvoltage Protection with Zero-Sequence Voltage/Residual Voltage Stage Description 6.24.3 Logic of a Stage [loovpu03-090611-01.tif, 2, en_US] Figure 6-184 Logic Diagram of an Overvoltage Protection with Zero-Sequence Voltage/Residual Voltage Stage Measured Value, Method of Measurement The device measures the residual voltage at the broken-delta winding. The measured voltage is converted to the zero-sequence voltage V .
Page 706: Application And Setting Notes
RMS value. Parameter Value Description This method of measurement suppresses the harmonics or transient voltage fundamental comp. peaks. Siemens recommends using this setting as the standard method. SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 707 A pickup delay can be necessary if high transients are anticipated after fault inception due to high line and ground capacitances. Siemens recommends using the default setting Pickup delay = 0.00 ms. Parameter: Threshold •...
Page 708 At V = 100 V, the value has to be set to rated 75 V, for example. Siemens recommends using the default setting V> healthy ph-to-gnd volt. = 75.000 V. Operation as Supervision Function If you want the stage to have a reporting effect only, generation of the operate indication and fault logging can be disabled via the Operate &...
Page 709: Settings
Protection and Automation Functions 6.24 Overvoltage Protection with Zero-Sequence Voltage/Residual Voltage Settings 6.24.5 Addr. Parameter Setting Options Default Setting Stage 1 • _:331:1 Stage 1:Mode • • test • _:331:2 Stage 1:Operate & • flt.rec. blocked • _:331:10 Stage 1:Blk. by meas.- •...
Page 710: Overvoltage Protection With Positive-Sequence Voltage
Protection and Automation Functions 6.25 Overvoltage Protection with Positive-Sequence Voltage 6.25 Overvoltage Protection with Positive-Sequence Voltage Overview of Functions 6.25.1 The function Overvoltage protection with positive-sequence voltage (ANSI 59) is used to: • Detect symmetric stationary overvoltages • Supervise the voltage range if the positive-sequence voltage is the decisive quantity Unbalanced overvoltages, for example, caused by ground faults and unbalanced faults, are not detected due to the evaluation of the positive-sequence voltage.
Page 711: Stage Description
Protection and Automation Functions 6.25 Overvoltage Protection with Positive-Sequence Voltage Stage Description 6.25.3 Logic of a Stage [logovpu1-090611-01.tif, 1, en_US] Figure 6-186 Logic Diagram of a Stage: Overvoltage Protection with Positive-Sequence Voltage Method of Measurement The stage uses the positive-sequence voltage. The positive-sequence voltage is calculated from the measured phase-to-ground voltages according to the defining equation.
Page 712: Settings
Protection and Automation Functions 6.25 Overvoltage Protection with Positive-Sequence Voltage Parameter: Dropout ratio • Recommended setting value (_:211:4) Dropout ratio = 0.95 The default value of 0.95 is appropriate for most applications. To achieve high measurement precision, the Dropout ratio can be reduced, to 0.98, for example. General Notes If the overvoltage is high, the first stage can trip with a short time delay.
Page 713 Protection and Automation Functions 6.25 Overvoltage Protection with Positive-Sequence Voltage Information Data Class Type (Type) _:211:56 Stage 1:Operate delay expired _:211:57 Stage 1:Operate Stage 2 _:212:81 Stage 2:>Block stage _:212:54 Stage 2:Inactive _:212:52 Stage 2:Behavior _:212:53 Stage 2:Health _:212:55 Stage 2:Pickup _:212:56 Stage 2:Operate delay expired _:212:57...
Page 714: Overvoltage Protection With Negative-Sequence Voltage
Protection and Automation Functions 6.26 Overvoltage Protection with Negative-Sequence Voltage 6.26 Overvoltage Protection with Negative-Sequence Voltage Overview of Functions 6.26.1 The function Overvoltage protection with negative-sequence voltage (ANSI 47) is used to: • Monitor the power system and electric machines for voltage unbalances •...
Page 715: Application And Setting Notes
For sensitive settings of the parameter Threshold, for example, lower than 10 % of the rated voltage, Siemens recommends using a higher number of cycles. Siemens recommends 10 cycles, and in this case, the pickup time is increased.
Page 716: Settings
The binary input signal >Open of the function block VTCB is connected to the voltage-transformer circuit breaker (see chapter 9.3.4.1 Overview of Functions). Parameter Value Description The protection function is blocked (= default setting). Siemens recommends using the default setting. The protection function is not blocked. 6.26.3.3 Settings Addr.
Page 717: Stage With Negative-Sequence Voltage
Protection and Automation Functions 6.26 Overvoltage Protection with Negative-Sequence Voltage Stage with Negative-Sequence Voltage 6.26.4 6.26.4.1 Description Logic of a Stage [lou23pol-090611-01.tif, 3, en_US] Figure 6-189 Logic Diagram of the Stage: Overvoltage Protection with Negative-Sequence Voltage Method of Measurement The stage uses the average value of the negative-sequence voltage, which is calculated from the function block General Functionality.
Page 718 Protection and Automation Functions 6.26 Overvoltage Protection with Negative-Sequence Voltage Parameter: Dropout ratio • Default setting (_:271:4) Dropout ratio = 0.95 The default setting of 0.95 is appropriate for most applications. You can decrease the dropout ratio to avoid chattering of the stage if the threshold value is low. For example, for the stage with a 2 % setting, you can use a dropout ratio of 0.90.
Page 719: Settings
Siemens recommends using multiple stages for a better grading, whereby a sensitive setting of the threshold permits an increased tripping delay.
Page 720: Information List
Protection and Automation Functions 6.26 Overvoltage Protection with Negative-Sequence Voltage Addr. Parameter Setting Options Default Setting _:271:4 Stage 1:Dropout ratio 0.90 to 0.99 0.95 _:271:6 Stage 1:Operate delay 0.00 s to 60.00 s 3.00 s Stage 2 • _:272:1 Stage 2:Mode •...
Page 721: Overvoltage Protection With Any Voltage
Protection and Automation Functions 6.27 Overvoltage Protection with Any Voltage 6.27 Overvoltage Protection with Any Voltage Overview of Functions 6.27.1 The function Overvoltage protection with any voltage (ANSI 59) detects any 1-phase overvoltages and is intended for special applications. Structure of the Function 6.27.2 The Overvoltage protection with any voltage function is used in protection function groups, which are based on voltage measurement.
Page 722: Stage Description
Protection and Automation Functions 6.27 Overvoltage Protection with Any Voltage Stage Description 6.27.3 Logic of a Stage [louxovpr-211212-01.tif, 1, en_US] Figure 6-193 Logic Diagram of a Stage: Overvoltage Protection with Any Voltage NOTE If the function Overvoltage protection with any voltage is used in a 1-phase function group, the param- eter Measured value is not visible.
Page 723: Application And Setting Notes
Select this method of measurement to suppress harmonics or transient fundamental comp. voltage peaks. Siemens recommends this method of measurement as the default setting. Select this method of measurement if you want the stage to take harmonics RMS value into account (for example at capacitor banks). Do not set the threshold value of the tripping stage under 10 V for this method of measurement.
Page 724 Protection and Automation Functions 6.27 Overvoltage Protection with Any Voltage NOTE From V7.30 on, the value VN measured is no longer provided. If you have selected this value in earlier versions, you can use either the following methods instead after upgrading the configuration to V7.30 or a later version: •...
Page 725: Settings
Protection and Automation Functions 6.27 Overvoltage Protection with Any Voltage Settings 6.27.5 Addr. Parameter Setting Options Default Setting Stage 1 • _:391:1 Stage 1:Mode • • test • _:391:2 Stage 1:Operate & flt.rec. • blocked • _:391:9 Stage 1:Measured value VA measured VA measured •...
Page 726 Protection and Automation Functions 6.27 Overvoltage Protection with Any Voltage Information Data Class Type (Type) _:391:54 Stage 1:Inactive _:391:52 Stage 1:Behavior _:391:53 Stage 1:Health _:391:55 Stage 1:Pickup _:391:56 Stage 1:Operate delay expired _:391:57 Stage 1:Operate Stage 2 _:392:81 Stage 2:>Block stage _:392:54 Stage 2:Inactive _:392:52...
Page 727: Overvoltage Protection With Negative-Sequence Voltage/Positive-Sequence Voltage
Protection and Automation Functions 6.28 Overvoltage Protection with Negative-Sequence Voltage/Positive-Sequence Voltage 6.28 Overvoltage Protection with Negative-Sequence Voltage/Positive- Sequence Voltage Overview of Functions 6.28.1 The function Overvoltage protection with negative-sequence voltage/positive-sequence voltage is used • Monitor the power system and electric machines for voltage unbalances •...
Page 728: Application And Setting Notes
For sensitive settings of the parameter Threshold, for example, lower than 10 % of the rated voltage, Siemens recommends using a higher number of cycles. Siemens recommends 10 cycles, and in this case, the pickup time is increased.
Page 729: Settings
The binary input signal >Open of the function block VTCB is connected to the voltage-transformer circuit breaker (see chapter 9.3.4.1 Overview of Functions). Parameter Value Description The protection function is blocked (= default setting). Siemens recommends using the default setting. The protection function is not blocked. 6.28.3.3 Settings Addr.
Page 730: Stage With Negative-Sequence Voltage/Positive-Sequence Voltage
Protection and Automation Functions 6.28 Overvoltage Protection with Negative-Sequence Voltage/Positive-Sequence Voltage Stage with Negative-Sequence Voltage/Positive-Sequence Voltage 6.28.4 6.28.4.1 Description Logic of a Stage [lo_V2V1_PROV_20150326, 1, en_US] Figure 6-196 Logic Diagram of the Stage: Overvoltage Protection with Negative-Sequence Voltage/Positive- Sequence Voltage Method of Measurement The stage uses the average value of the negative-sequence voltage/positive-sequence voltage, which is calcu- lated from the function block General Functionality.
Page 731 Protection and Automation Functions 6.28 Overvoltage Protection with Negative-Sequence Voltage/Positive-Sequence Voltage In the application with a lower threshold setting of about 2.00 %, there is a risk of an overfunction due to the measuring errors with small values as well as an influence via disturbances. Parameter: Dropout ratio •...
Page 732: Settings
Siemens recommends using multiple stages for a better grading, whereby a sensitive setting of the threshold permits an increased tripping delay.
Page 733: Information List
Protection and Automation Functions 6.28 Overvoltage Protection with Negative-Sequence Voltage/Positive-Sequence Voltage Addr. Parameter Setting Options Default Setting • _:17072:2 Stage 2:Operate & • flt.rec. blocked _:17072:3 Stage 2:Threshold 0.50 % to 100.00 % 15.00 % _:17072:4 Stage 2:Dropout ratio 0.90 to 0.99 0.95 _:17072:6 Stage 2:Operate delay...
Page 734: Undervoltage Protection With 3-Phase Voltage
Protection and Automation Functions 6.29 Undervoltage Protection with 3-Phase Voltage 6.29 Undervoltage Protection with 3-Phase Voltage Overview of Functions 6.29.1 The function Undervoltage protection with 3-phase voltage (ANSI 27): • Monitors the permissible voltage range • Protects equipment (for example, plant components and machines) against damages caused by under- voltage •...
Page 735: Stage With Definite-Time Characteristic Curve
Protection and Automation Functions 6.29 Undervoltage Protection with 3-Phase Voltage Stage with Definite-Time Characteristic Curve 6.29.3 6.29.3.1 Description Logic of the Stage [louvp3ph-140611-01_stagecontrol.vsd, 2, en_US] Figure 6-200 Logic Diagram of the Stage Control SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 736 Protection and Automation Functions 6.29 Undervoltage Protection with 3-Phase Voltage [louvp3ph-140611-01.tif, 2, en_US] Figure 6-201 Logic Diagram of the Definite-Time Undervoltage Protection with 3-Phase Voltage Method of Measurement With the Method of measurement parameter, you select the relevant method of measurement, depending on the application.
Page 737: Application And Setting Notes
Protection and Automation Functions 6.29 Undervoltage Protection with 3-Phase Voltage Pickup Mode With the Pickup mode parameter, you define whether the stage picks up when there is a lower threshold- value violation in one measuring element (1 out of 3) or when there is a lower threshold-value violation in all 3 measuring elements (3 out of 3).
Page 738 Select this method of measurement to suppress harmonics or transient fundamental comp. voltage peaks. Siemens recommends using this parameter value as the default setting. Select this method of measurement if you want the stage to take harmonics RMS value into account (for example at capacitor banks). Do not set the threshold value of the stage under 10 V for this method of measurement.
Page 739 1 out of 3 range. Siemens recommends 1 out of 3 as the default setting. This reflects how the function behaved in previous generations (SIPROTEC 4, SIPROTEC 3). Select this setting when using the stage to disconnect from the power 3 out of 3 system (in the case of wind farms, for example).
Page 740: Settings
Recommended setting value (_:2311:101) Threshold I> = 0.05 A The Threshold I> parameter makes it possible to detect when the circuit breaker is closed. Siemens recom- mends setting the Threshold I> parameter to 5% of the rated current. With a secondary rated transformer current of 1 A, the secondary setting value for Threshold I>...
Page 741: Information List
Protection and Automation Functions 6.29 Undervoltage Protection with 3-Phase Voltage Addr. Parameter Setting Options Default Setting • _:421:9 Definite-T 1:Measured phase-to-ground phase-to-phase • value phase-to-phase • _:421:8 Definite-T 1:Method of fundamental comp. fundamental • measurement RMS value comp. • _:421:101 Definite-T 1:Pickup mode 1 out of 3 1 out of 3...
Page 742: Stage With Inverse-Time Characteristic Curve
Protection and Automation Functions 6.29 Undervoltage Protection with 3-Phase Voltage Information Data Class Type (Type) _:421:300 Definite-T 1:Pickup loop AB _:421:301 Definite-T 1:Pickup loop BC _:421:302 Definite-T 1:Pickup loop CA _:421:56 Definite-T 1:Operate delay expired _:421:57 Definite-T 1:Operate Definite-T 2 _:422:81 Definite-T 2:>Block stage _:422:54...
Page 743 Protection and Automation Functions 6.29 Undervoltage Protection with 3-Phase Voltage [lo_UVP3ph_In, 4, en_US] Figure 6-203 Logic Diagram of the Inverse-Time Undervoltage Protection with 3-Phase Voltage Method of Measurement With the Method of measurement parameter, you define whether the stage uses the fundamental comp.
Page 744 Protection and Automation Functions 6.29 Undervoltage Protection with 3-Phase Voltage Measured Value With the Measured value parameter, you define whether the stage analyzes the phase-to-phase voltages , and V , or the phase-to-ground voltages V , and V If the measured value is set to phase-to-phase, the function reports those measuring elements that have picked up.
Page 745 Protection and Automation Functions 6.29 Undervoltage Protection with 3-Phase Voltage The inverse-time characteristic is shown in the following figure: [dwUVP3ph_inverse, 1, en_US] Figure 6-204 Inverse-Time Characteristics for Undervoltage Protection Pickup Delay The Pickup delay parameter is only available and of relevance if you are using the current-flow criterion of the function (parameter Current-flow criterion = on).
Page 746: Application And Setting Notes
Select this method of measurement to suppress harmonics or transient fundamental comp. voltage peaks. Siemens recommends using this parameter value as the default setting. Select this method of measurement if you want the stage to take harmonics RMS value into account (for example, at capacitor banks). Do not set the threshold value of the stage under 10 V for this method of measurement.
Page 747 1 out of 3 range. Siemens recommends 1 out of 3 as the default setting. This reflects how the function behaved in previous generations (SIPROTEC 4, SIPROTEC 3). Select this setting when using the stage to disconnect from the power 3 out of 3 system (in the case of wind farms, for example).
Page 748 Under network conditions of intermittent faults or faults which occur in rapid succession, Siemens recom- mends setting the Reset time to an appropriate value > 0 s to ensure the operation. Otherwise, Siemens recommends keeping the default value to ensure a fast reset of the function.
Page 749: Settings
Protection and Automation Functions 6.29 Undervoltage Protection with 3-Phase Voltage 6.29.4.3 Settings Addr. Parameter Setting Options Default Setting Inverse-T # • Inverse-T #:Mode • • test • Inverse-T #:Operate & • flt.rec. blocked • _:10 Inverse-T #:Blk. by • meas.-volt. failure •...
Page 750: Undervoltage Protection With Positive-Sequence Voltage
Protection and Automation Functions 6.30 Undervoltage Protection with Positive-Sequence Voltage 6.30 Undervoltage Protection with Positive-Sequence Voltage Overview of Functions 6.30.1 The Undervoltage protection with positive-sequence voltage function (ANSI 27): • Monitors the permissible voltage range • Protects equipment (for example, plant components and machines) from damages caused by under- voltage •...
Page 751: Stage Description
Protection and Automation Functions 6.30 Undervoltage Protection with Positive-Sequence Voltage Stage Description 6.30.3 Logic of the Stage [louv3pu1-021012-01.tif, 1, en_US] Figure 6-206 Logic Diagram of the Stage Undervoltage Protection with Positive-Sequence Voltage Method of Measurement The stage uses the positive-sequence voltage. The positive-sequence voltage is calculated from the measured phase-to-ground voltages according to the defining equation.
Page 752: Application And Setting Notes
Protection and Automation Functions 6.30 Undervoltage Protection with Positive-Sequence Voltage Pickup Delay The Pickup delay parameter is only available and of relevance if you are using the current-flow criterion of the function (parameter Current-flow criterion = on). If the circuit breaker opens when the current-flow criterion is being used, the undervoltage detection and current-flow dropout functions conflict with one another.
Page 753 (see chapter 9.3.4.1 Overview of Functions). Parameter Value Description The protection stage is blocked (= default setting). Siemens recommends using the default setting. The protection stage is not blocked. Parameter: Current-flow criterion • Recommended setting value (_:2311:104) Current-flow criterion = on Depending on the system, the voltage transformers can be located on the supply or the output side.
Page 754 Recommended setting value (_:2311:101) Threshold I> = 0.05 A The Threshold I> parameter makes it possible to detect when the circuit breaker is closed. Siemens recom- mends setting the Threshold I> parameter to 5% of the rated current. With a secondary rated transformer current of 1 A, the secondary setting value for Threshold I>...
Page 755: Settings
Protection and Automation Functions 6.30 Undervoltage Protection with Positive-Sequence Voltage Undervoltage causes excessive torques and current surges which place inadmissible strains on the motor. The voltage at which motors do no longer start up is in the range of (0.55 … 0.70) V .
Page 756: Information List
Protection and Automation Functions 6.30 Undervoltage Protection with Positive-Sequence Voltage Addr. Parameter Setting Options Default Setting _:482:4 Stage 2:Dropout ratio 1.01 to 1.20 1.05 _:482:6 Stage 2:Operate delay 0.00 s to 60.00 s 0.50 s Information List 6.30.6 Information Data Class Type (Type) General...
Page 757: Undervoltage Protection With Any Voltage
Protection and Automation Functions 6.31 Undervoltage Protection with Any Voltage 6.31 Undervoltage Protection with Any Voltage Overview of Functions 6.31.1 The function Undervoltage protection with any voltage (ANSI 27) detects any 1-phase undervoltage and is intended for special applications. Structure of the Function 6.31.2 The Undervoltage protection with any voltage function is used in protection function groups, which are based on voltage measurement.
Page 758: Stage Description
Protection and Automation Functions 6.31 Undervoltage Protection with Any Voltage Stage Description 6.31.3 Logic of a Stage [louvpuxx-100611-01.tif, 1, en_US] Figure 6-208 Logic Diagram of a Stage: Undervoltage Protection with Any Voltage NOTE If the function Undervoltage protection with any voltage is used in a 1-phase function group, the param- eter Measured value is not visible.
Page 759: Application And Setting Notes
Select this method of measurement to suppress harmonics or transient fundamental comp. voltage peaks. Siemens recommends using this parameter value as the default setting. Select this method of measurement if you want the stage to take harmonics RMS value into account (for example at capacitor banks). Do not set the threshold value of the tripping stage under 10 V for this method of measurement.
Page 760 Protection and Automation Functions 6.31 Undervoltage Protection with Any Voltage • Measured phase-to-phase voltage V (VAB measured) • Measured phase-to-phase voltage V (VBC measured) • Measured phase-to-phase voltage V (VCA measured) • Calculated phase-to-phase voltage V (VAB calculated) • Calculated phase-to-phase voltage V (VBC calculated) •...
Page 761: Settings
Protection and Automation Functions 6.31 Undervoltage Protection with Any Voltage Parameter Value Description Because of the application, it makes sense that the stage is only active (that is, not blocked) when a certain current flow is present (see note). Current flow monitoring does not make sense for the application. NOTE Because of the flexible setting options of the voltage measurand, the function itself does not determine the current associated with the voltage.
Page 762: Information List
Protection and Automation Functions 6.31 Undervoltage Protection with Any Voltage Addr. Parameter Setting Options Default Setting • _:572:9 Stage 2:Measured value VA measured VA measured • VB measured • VC measured • VAB measured • VBC measured • VCA measured •...
Page 763: Overfrequency Protection
Protection and Automation Functions 6.32 Overfrequency Protection 6.32 Overfrequency Protection Overview of Functions 6.32.1 The Overfrequency protection function (ANSI 81O): • Detect overfrequencies in electrical power systems or machines • Monitor the frequency band and output failure indications • Disconnect generating units when the power frequency is critical •...
Page 764: Overfrequency-Protection Stage
Protection and Automation Functions 6.32 Overfrequency Protection Overfrequency-Protection Stage 6.32.3 Logic of a Stage [lostofqp-040411-01.tif, 1, en_US] Figure 6-210 Logic Diagram of the Overfrequency-Protection Stage Frequency-Measurement Method Overfrequency protection is available in 2 functional configurations. These work with different frequency- measurement methods.
Page 765: Application And Setting Notes
Protection and Automation Functions 6.32 Overfrequency Protection Both methods of measurement are characterized by a high measuring accuracy combined with a short pickup time. Disturbance values such as harmonics, high frequency disturbances, phase-angle jumps during switching operations and compensation processes due to power swings are effectively suppressed. Functional Measured Value The angle-difference method provides the following measured value: Measured Value...
Page 766: Settings
Protection and Automation Functions 6.32 Overfrequency Protection When determining the setting value, please keep in mind the measurement method and the measuring connection that you have selected. If you work with the positive-sequence voltage, remember that the maximum voltage is equal to the phase-to-ground voltage. The default setting is referred to this value. Parameter: Dropout differential •...
Page 767: Information List
Protection and Automation Functions 6.32 Overfrequency Protection Addr. Parameter Setting Options Default Setting _:32:6 Stage 2:Operate delay 0.00 s to 600.00 s 5.00 s Information List 6.32.6 Information Data Class Type (Type) General _:2311:300 General:Undervoltage blocking _:2311:301 General:f Group indicat. _:4501:55 Group indicat.:Pickup _:4501:57...
Page 768: Underfrequency Protection
Protection and Automation Functions 6.33 Underfrequency Protection 6.33 Underfrequency Protection Overview of Functions 6.33.1 The Underfrequency protection function (ANSI 81U) is used to: • Detect underfrequencies in electrical power systems or machines • Monitor the frequency band and output failure indications •...
Page 769: Underfrequency-Protection Stage
Protection and Automation Functions 6.33 Underfrequency Protection Underfrequency-Protection Stage 6.33.3 Logic of a Stage [lostufqp-040411-01.tif, 2, en_US] Figure 6-212 Logic Diagram of the Underfrequency-Protection Stage Frequency-Measurement Method Underfrequency protection is available in 2 functional configurations. These work with different frequency- measurement methods.
Page 770: Application And Setting Notes
Protection and Automation Functions 6.33 Underfrequency Protection Both methods of measurement are characterized by a high measuring accuracy combined with a short response time. Disturbance values such as harmonics, high frequency disturbances, phase-angle jumps during switching operations and compensation processes due to power swings are effectively suppressed. Behavior on Leaving the Operating Range The sampling-frequency tracking makes a wide frequency operating range possible.
Page 771: Settings
Protection and Automation Functions 6.33 Underfrequency Protection Due to the high-precision frequency measurement, the recommended setting value for the Dropout differential can remain at 20 mHz. If in your application you wish a subsequent dropout of the tripping stage, then increase the setting value of the dropout differential. For instance, if the pickup value (parameter Threshold ) of the tripping stage is set to 49.8 Hz and the Dropout differential to 100 mHz, the stage will drop out at 49.9 Hz.
Page 772: Information List
Protection and Automation Functions 6.33 Underfrequency Protection Addr. Parameter Setting Options Default Setting • _:62:2 Stage 2:Operate & flt.rec. • blocked _:62:3 Stage 2:Threshold 40.00 Hz to 70.00 Hz 47.50 Hz _:62:6 Stage 2:Operate delay 0.00 s to 600.00 s 10.00 s Stage 3 •...
Page 773: Underfrequency Load Shedding
Protection and Automation Functions 6.34 Underfrequency Load Shedding 6.34 Underfrequency Load Shedding Overview of Functions 6.34.1 The Underfrequency load shedding function: • Detects underfrequencies in the electrical power systems • Switches off the medium-voltage busbar or feeders that consume active power to stabilize the frequency •...
Page 774: General Functionality
Protection and Automation Functions 6.34 Underfrequency Load Shedding General Functionality 6.34.3 6.34.3.1 Description Logic [lo_UFLS_General functionality, 1, en_US] Figure 6-214 Logic Diagram of the General Functionality n means the number of the protection stage. SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 775 Protection and Automation Functions 6.34 Underfrequency Load Shedding Measurands The general functionality requires the following input measurands: • Positive-sequence voltage V1 • Positive-sequence current I1 • Positive-sequence system apparent power S1 • Positive-sequence system active power P1 • Frequency S1 and P1 are both calculated from V1 and I1. The frequency is calculated from V1. The frequency and the frequency change rate df/dt are calculated via the angle difference algorithm.
Page 776 Protection and Automation Functions 6.34 Underfrequency Load Shedding [dw_load shedding_Power crit.<0, 1, en_US] Figure 6-215 Power-Criterion Checking at Phi (power criterion) ≤ 0 [dw_load shedding_Power crit.>0, 1, en_US] Figure 6-216 Power-Criterion Checking at Phi (power criterion) > 0 The power criterion contains the check of the current criterion and of the power-angle criterion. You can determine whether to check the power criterion or not by setting the Power criterion parameter.
Page 777: Application And Setting Notes
If the magnitude of V1 is smaller than the Minimum voltage, all protection stages are blocked. The Minimum voltage parameter is set as a per-unit value related to the rated voltage of the connected voltage measuring point. Siemens recommends using the default setting. Parameter: Positive power direction •...
Page 778 Protection and Automation Functions 6.34 Underfrequency Load Shedding The following figure shows 2 application scenarios of protection devices with the Underfrequency load shed- ding function. [dw_UFLS_positive power direction, 1, en_US] Figure 6-217 Application Scenarios Dotted arrow: Standard forward direction of the protection functionality Solid arrow: Positive active-power flow direction The standard forward direction of the protection functionality is from the busbar to the protected object which...
Page 779 If a feeder can deliver active power towards the busbar, or if the medium-voltage busbar can deliver active power to the high-voltage busbar, Siemens recommends using the power criterion to exclude the feeder or the medium-voltage busbar from being shed under this condition. If a feeder or the medium- voltage busbar is always consuming active power, the power criterion is not required.
Page 780: Stage Description
Protection and Automation Functions 6.34 Underfrequency Load Shedding The default setting is a reasonable value. Siemens recommends using the default setting. 6.34.4 Stage Description 6.34.4.1 Description Logic of the Stage [lo_load shedding_stage, 1, en_US] Figure 6-218 Logic Diagram of the Underfrequency Load Shedding Stage...
Page 781 Protection and Automation Functions 6.34 Underfrequency Load Shedding If the Pickup signal is maintained during the Operate delay time, an Operate indication is issued. Exclusive Stage Activation A load-shedding schema defines in which order feeders (power consumers) are disconnected. To not discrimi- nate power consumers, this order is changed regularly.
Page 782: Application And Setting Notes
(approx. 10 ms to 30 ms) plus the 6 times measuring repetition of 60 ms, which is 70 ms to 90 ms in total. In order to avoid a wrong pickup in case of a phase jump, Siemens recommends setting the value of the f< stabilization counter parameter not below 5.
Page 783: Settings
Protection and Automation Functions 6.34 Underfrequency Load Shedding Settings 6.34.5 Addr. Parameter Setting Options Default Setting General _:18121:101 General:Minimum 0.300 p.u. to 0.900 p.u. 0.700 p.u. voltage • _:18121:103 General:Power criterion • _:18121:104 General:Min. current 0.020 p.u. to 0.200 p.u. 0.050 p.u.
Page 784 Protection and Automation Functions 6.34 Underfrequency Load Shedding Information Data Class Type (Type) Group indicat. _:4501:55 Group indicat.:Pickup _:4501:57 Group indicat.:Operate Stage 1 _:18151:81 Stage 1:>Block stage _:18151:500 Stage 1:>Block delay & op. _:18151:502 Stage 1:>Exclusive activation _:18151:347 Stage 1:Exclusive activation _:18151:54 Stage 1:Inactive _:18151:52...
Page 785: Rate Of Frequency Change Protection
Protection and Automation Functions 6.35 Rate of Frequency Change Protection 6.35 Rate of Frequency Change Protection Overview of Functions 6.35.1 The function Rate of frequency change protection is used to: • Detect a frequency change quickly • Prevent the system from not secure states caused by unbalance between the generated and consumed active power •...
Page 786: Application And Setting Notes
For information regarding pickup time and measuring accuracy, refer to the technical data. The default setting provides maximum measuring accuracy. If you do not have specific requirements for a decreased pickup time, Siemens recommends using the default setting. SIPROTEC 5, Overcurrent Protection, Manual...
Page 787: Stage Description
Protection and Automation Functions 6.35 Rate of Frequency Change Protection The default setting is a reasonable compromise between measuring accuracy and pickup time. For a non- sensitive setting (high threshold value), you can set the parameter Measuring window to a smaller value. 6.35.4 Stage Description 6.35.4.1...
Page 788: Application And Setting Notes
Protection and Automation Functions 6.35 Rate of Frequency Change Protection 6.35.4.2 Application and Setting Notes Parameter: Threshold • Default setting (_:13231:3) Threshold = 3.000 Hz/s The pickup value depends on the application and is determined by power-system conditions. In most cases, a network analysis will be necessary.
Page 789: Settings
Protection and Automation Functions 6.35 Rate of Frequency Change Protection NOTE In case of power-system incidents, especially in case of transmission incidents and influence of voltage- stabilizing measures via power-electronic components (reactive-power compensation through SVC), the magnitude and the phase angle of the voltage can change. Sensitive settings can lead to overfunction. Therefore, it is reasonable to block the Rate of Frequency Change Protection if other protection func- tions, for example, residual voltage or negative-sequence voltage, pick up.
Page 790 Protection and Automation Functions 6.35 Rate of Frequency Change Protection Information Data Class Type (Type) df/dt falling1 _:13231:81 df/dt falling1:>Block stage _:13231:54 df/dt falling1:Inactive _:13231:52 df/dt falling1:Behavior _:13231:53 df/dt falling1:Health _:13231:55 df/dt falling1:Pickup _:13231:56 df/dt falling1:Operate delay expired _:13231:57 df/dt falling1:Operate df/dt rising1 _:13201:81 df/dt rising1:>Block stage...
Page 791: Vector-Jump Protection
Protection and Automation Functions 6.36 Vector-Jump Protection 6.36 Vector-Jump Protection Overview of Functions 6.36.1 The Vector-jump protection function: • Is used for network decoupling of the power generating unit in case of a load loss • Evaluates the phase-angle jump of the voltage phasors 6.36.2 Structure of the Function The Vector-jump protection function can be used in the following function groups:...
Page 792 Protection and Automation Functions 6.36 Vector-Jump Protection [dw_load loss, 1, en_US] Figure 6-223 Voltage Vector of the Steady State The following figure shows the situations after the load is switched off: • The terminal voltage V changes to V'. • An additional phase-angle jump occurs.
Page 793 Protection and Automation Functions 6.36 Vector-Jump Protection The following measures are applied to avoid unwanted tripping: • Correction of steady-state deviations from rated frequency • Frequency operating range limited to f ± 3 Hz rated • High measuring accuracy by using frequency-tracked measured values and evaluation of the positive- sequence phasor •...
Page 794: Application And Setting Notes
When voltages are connected or disconnected, the overfunction can be avoided with the timer T Block. Siemens recommends to use the default setting of the parameter T Block. Keep in mind that the parameter T Block has always to be set to 2 cycles more than the measuring window for vector-jump measurement.
Page 795: Δφ Stage
Protection and Automation Functions 6.36 Vector-Jump Protection Δφ Stage 6.36.4 6.36.4.1 Description Logic [lo_DeltaPhi_Stage, 1, en_US] Figure 6-226 Logic Diagram of the Δφ Stage In the logic diagram, the I1 < Release stage is instantiated. You can find more information in chapter 6.36.5.1 Description.
Page 796: Application And Setting Notes
If the setting for the parameter Threshold Δφ is too sensitive, every time loads are connected or discon- nected, the protection function performs a network decoupling. Therefore, If no other calculated value is applicable to the setting of this parameter, Siemens recommends using the default setting. Parameter: Operate delay •...
Page 797: Settings
Protection and Automation Functions 6.36 Vector-Jump Protection 6.36.4.3 Settings Addr. Parameter Setting Options Default Setting Stage Δφ 1 • _:19261:1 Stage Δφ 1:Mode • • test • _:19261:2 Stage Δφ 1:Operate & • flt.rec. blocked _:19261:101 Stage Δφ 1:Threshold 2.0° to 30.0° 10.0°...
Page 798: Application And Setting Notes
Protection and Automation Functions 6.36 Vector-Jump Protection 6.36.5.2 Application and Setting Notes Parameter: I< Threshold • Default setting (_:101) I< Threshold = 0.100 A With the parameter I< Threshold, you can set the pickup value of the I < Release stage corresponding to the specific application.
Page 799: Power Protection (P,Q), 3-Phase
Protection and Automation Functions 6.37 Power Protection (P,Q), 3-Phase 6.37 Power Protection (P,Q), 3-Phase Overview of Functions 6.37.1 The 3-phase power protection (P, Q) function (ANSI 32) is used to: • Detect whether the active or reactive power rises above or drops below a set threshold •...
Page 800: Active Power Stage
Protection and Automation Functions 6.37 Power Protection (P,Q), 3-Phase [lo_GPP operate indication logical comb, 2, en_US] Figure 6-229 Logical Combination of Operate Indications in CFC 6.37.3 Active Power Stage Logic of a Stage [lo_3-phase active power, 2, en_US] Figure 6-230 Logic Diagram of the Active Power Stage (Stage Type: Power P<) Measured Value The Measured value parameter is used to specify which measured power value is analyzed by the tripping...
Page 801 Protection and Automation Functions 6.37 Power Protection (P,Q), 3-Phase The Threshold parameter is used to define the pickup threshold of the stage. The Tilt power charac- teristic parameter is used to define the tilt of the pickup characteristic. The figure below shows the defini- tion of the signs.
Page 802: Reactive Power Stage
Protection and Automation Functions 6.37 Power Protection (P,Q), 3-Phase Reactive Power Stage 6.37.4 Logic of a Stage [lo_3phase reactive power, 2, en_US] Figure 6-232 Logic Diagram of the Reactive Power Stage (Stage Type: Power Q<) Measured Value The Measured value parameter is used to specify which measured power value is processed by the tripping stage.
Page 803: Application Example
Protection and Automation Functions 6.37 Power Protection (P,Q), 3-Phase [dw_tilt-power reactive power, 2, en_US] Figure 6-233 Tilt-Power Characteristic Pickup The stage compares the selected power value with the set Threshold. Depending on the stage type (Power Q> or Power Q<) being above or falling below the threshold value will lead to a pickup. Dropout Delay A delay can be set for the dropout when the measured value falls below the dropout threshold.
Page 804: Setting Notes For The Active Power Stage
• Recommended setting value (_:6271:105) Measured value = positive seq. power The Measured value parameter is used to specify which measured power value is evaluated. For 3-phase measurement, Siemens recommends to evaluate the positive-sequence system power. Parameter: Threshold • Recommended setting value (_:6271:3) Threshold = 0 % The Threshold parameter is used to define the pickup threshold of the active power stage.
Page 805: Setting Notes For The Reactive Power Stage
• Recommended setting value (_:6331:105) Measured value = positive seq. power The Measured value parameter is used to specify which measured power value is evaluated. For 3-phase measurement, Siemens recommends to evaluate the positive-sequence system power. Parameter: Threshold • Recommended setting value (_:6331:3) Threshold = 0 % The Threshold parameter is used to define the pickup threshold of the reactive power stage.
Page 806: Settings
Protection and Automation Functions 6.37 Power Protection (P,Q), 3-Phase Parameter: Tilt power characteristic • Recommended setting value (_:6331:103) Tilt power characteristic = +20° The Tilt power characteristic parameter is used to incline the pickup characteristic. In the example (see Figure 6-234), the power characteristic has a tilt of 20°.
Page 807: Information List
Protection and Automation Functions 6.37 Power Protection (P,Q), 3-Phase Addr. Parameter Setting Options Default Setting _:6271:7 Power P< 1:Dropout delay 0.00 s to 60.00 s 0.00 s _:6271:6 Power P< 1:Operate delay 0.00 s to 60.00 s 1.00 s Power Q> 1 •...
Page 808 Protection and Automation Functions 6.37 Power Protection (P,Q), 3-Phase Information Data Class Type (Type) _:6271:54 Power P< 1:Inactive _:6271:52 Power P< 1:Behavior _:6271:53 Power P< 1:Health _:6271:55 Power P< 1:Pickup _:6271:56 Power P< 1:Operate delay expired _:6271:57 Power P< 1:Operate Power Q>...
Page 809: Reverse-Power Protection
Protection and Automation Functions 6.38 Reverse-Power Protection 6.38 Reverse-Power Protection Overview of Functions 6.38.1 The Reverse-power protection function (ANSI 32R): • Monitors the motor operation of generators and thus detects driving-power failure • Prevents endangering the turbine (e.g. the turbine-blade damage due to overheating) by opening the circuit breaker of the system •...
Page 810: General Functionality
Protection and Automation Functions 6.38 Reverse-Power Protection General Functionality 6.38.3 6.38.3.1 Description Logic of the Function [lo_RPP general functionality, 2, en_US] Figure 6-236 Logic Diagram of the Cross-Stage Functionality Calculating the Reverse Power The reverse-power protection calculates the active power from the symmetrical components of the funda- mental components of the voltages and currents.
Page 811: Application And Setting Notes
Protection and Automation Functions 6.38 Reverse-Power Protection The angle error between voltage transformer and current transformer has a strong influence on the measuring accuracy. With the parameter (_:2311:101) Angle correction , you can correct the angle error. The following 2 methods are possible here: •...
Page 812 Protection and Automation Functions 6.38 Reverse-Power Protection Example This example uses a class 0.2 voltage transformer with a rated burden of 45 VA. The following data was taken from the measuring report. Table 6-18 For Phase A V/Vn ε δ [min] ε...
Page 813: Settings
With the parameter Minimum voltage V1, you can limit the operating range of the reverse-power protec- tion. If the positive-sequence voltage falls below the set value, the reverse-power protection is deactivated. If no other restrictions are known, Siemens recommends using the default setting. 6.38.3.3 Settings Addr.
Page 814: Stage Description
Protection and Automation Functions 6.38 Reverse-Power Protection Stage Description 6.38.4 6.38.4.1 Description Logic of the Stage [lo_RPP stage, 2, en_US] Figure 6-237 Logic Diagram of the Reverse-Power Protection Stage Trip Command To bridge brief power consumption during synchronization or during power swings caused by system inci- dents, tripping (shutdown of the generator via reverse power) is delayed by a settable time (for example, 10 A brief delay is enough when the quick-stop valve is closed.
Page 815: Application And Setting Notes
Protection and Automation Functions 6.38 Reverse-Power Protection 6.38.4.2 Application and Setting Notes If reverse power occurs in a power plant, the turbo-generator set must be disconnected from the electrical power system. Operating the turbine without the minimum steam flow (cooling effect) is dangerous. For a gas turbine cogeneration unit, the motor load can also be too great for the electrical power system.
Page 816: Information List
Protection and Automation Functions 6.38 Reverse-Power Protection 6.38.4.4 Information List Information Data Class Type (Type) Group indicat. _:4501:55 Group indicat.:Pickup _:4501:57 Group indicat.:Operate Stage 1 _:991:81 Stage 1:>Block stage _:991:500 Stage 1:>Stop valve closed _:991:54 Stage 1:Inactive _:991:52 Stage 1:Behavior _:991:53 Stage 1:Health _:991:55...
Page 817: Overexcitation Protection
Protection and Automation Functions 6.39 Overexcitation Protection 6.39 Overexcitation Protection Overview of Functions 6.39.1 The Overexcitation protection (ANSI 24) is used for detecting high induction values in generators and trans- formers. It protects the equipment from excessive thermal loads. The induction is recorded indirectly by analyzing the V/f ratio (also referred to as Volt per Hertz protection). Overvoltage leads to excessive magnetizing currents, while underfrequency leads to higher losses when reset- ting the magnetization.
Page 818: Stage With Dependent Characteristic Curve (Thermal Stage)
Protection and Automation Functions 6.39 Overexcitation Protection Stage with Dependent Characteristic Curve (Thermal Stage) 6.39.3 6.39.3.1 Function Description Logic [lothchuf-080513-01.tif, 1, en_US] Figure 6-239 Logic of the Overexcitation Protection with Thermal Characteristic Curve Heating Cooling V/f Method of Measurement The input values of the protection function are the continuously measured voltage and the frequency. The phase-to-phase voltage is used to process the voltage.
Page 819 Protection and Automation Functions 6.39 Overexcitation Protection Measured voltage (maximum phase-to-phase voltage) Adjusted rated voltage of the protected object rated, obj. Measured frequency Adjusted rated frequency rated Based on the definition above, the protection function refers exclusively to primary values of the protected object.
Page 820 Protection and Automation Functions 6.39 Overexcitation Protection [dwovexak-210313-01.tif, 1, en_US] Figure 6-241 Tripping Zone of the Thermal Characteristic Curve (I) If the Threshold is greater, then a cutoff occurs (see Figure 6-242). [dwovexab-210313-01.tif, 1, en_US] Figure 6-242 Tripping Zone of the Thermal Characteristic Curve (II) Warning Threshold If the Threshold is exceeded, the time delay (parameter (_:13591:101) Warning delay) is started.
Page 821: Application And Setting Notes
Protection and Automation Functions 6.39 Overexcitation Protection Measured Value Description Thermal tripping of the overexcitation protection. If (_:13591:321) V/f th. the value reaches 100 %, the tripping occurs. Cooling Time If the value drops below the threshold ((_:13591:3) Threshold), tripping of the thermal characteristic curve (dependent characteristic curve) is reverted.
Page 822: Settings
Adjust the value individually. Set a V/f/time value pair for each characteristic-curve point. The setting depends on the characteristic curve you want to realize. The default settings refer to a Siemens standard transformer. NOTE The value pairs must be entered in continuous order.
Page 823 Protection and Automation Functions 6.39 Overexcitation Protection Information Data Class Type (Type) _:4501:57 Group indicat.:Operate Definite-T 1 _:13621:81 Definite-T 1:>Block stage _:13621:54 Definite-T 1:Inactive _:13621:52 Definite-T 1:Behavior _:13621:53 Definite-T 1:Health _:13621:55 Definite-T 1:Pickup _:13621:56 Definite-T 1:Operate delay expired _:13621:57 Definite-T 1:Operate Therm.charact.
Page 824: Stage With Independent Characteristic Curve
Protection and Automation Functions 6.39 Overexcitation Protection Stage with Independent Characteristic Curve 6.39.4 6.39.4.1 Function Description Logic [lodtchuf-080513-01.tif, 1, en_US] Figure 6-243 Logic of the Overexcitation Protection with Inpendent Characteristic Curve (Definite-Time Stage) Method of Measurement This stage evaluates also the V/f value that is identical to the input value of the thermal stage. Measurement-relevant details can be found in chapter 6.39.3 Stage with Dependent Characteristic Curve (Thermal...
Page 825: Settings
Protection and Automation Functions 6.39 Overexcitation Protection Parameter: Tripping delay • Default setting (_:13621:6) Operate delay = 1.00 s The Operate delay parameter is used to determine the time by which the stage is delayed after the pickup. This time delay depends on the specific application. The default value is practical for the applica- tion described in the previous chapter.
Page 826 Protection and Automation Functions 6.39 Overexcitation Protection Information Data Class Type (Type) _:13591:52 Therm.charact.:Behavior _:13591:53 Therm.charact.:Health _:13591:55 Therm.charact.:Pickup _:13591:301 Therm.charact.:Warning _:13591:57 Therm.charact.:Operate _:13591:321 Therm.charact.:V/f th. SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 827: Undervoltage-Controlled Reactive-Power Protection
Protection and Automation Functions 6.40 Undervoltage-Controlled Reactive-Power Protection 6.40 Undervoltage-Controlled Reactive-Power Protection Overview of Functions 6.40.1 The Undervoltage-controlled reactive-power protection function (ANSI 27/Q): • Detects critical power-system situations, mainly in case of regenerative generation • Prevents a voltage collapse in power system by disconnecting the power-generation facility from the main power systems •...
Page 828: Protection Stage
Protection and Automation Functions 6.40 Undervoltage-Controlled Reactive-Power Protection Protection Stage 6.40.3 6.40.3.1 Description Logic of the Stage [loqvprst-110713-01.tif, 1, en_US] Figure 6-245 Logic Diagram of the Protection Stage of the Undervoltage-Controlled Reactive-Power Protec- tion SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 829: Application And Setting Notes
Parameter Value Description The Protection stage is blocked when a measuring-voltage failure is detected. Siemens recommends using the default setting, as there is no assurance that the Protection stage will function correctly if the measuring voltage fails. SIPROTEC 5, Overcurrent Protection, Manual...
Page 830 Recommended setting value (_:13921:105) I> release threshold = 0.100 A You use the I> release threshold parameter to define a precondition that the stage can pick up. The default setting is at 10 % of the rated current. Siemens recommends using the default setting. Parameter: V< threshold value •...
Page 831: Settings
Protection and Automation Functions 6.40 Undervoltage-Controlled Reactive-Power Protection Parameter: Trip interface contains • Default setting (_:13921:101) Trip interface contains = operate (grid) The stage provides 2 operate signals, the Operate (generator) and the Operate (grid) . You use the Trip interface contains parameter to define whether one or none of them will be forwarded to the trip interface of the circuit-breaker interaction.
Page 832: Information List
Protection and Automation Functions 6.40 Undervoltage-Controlled Reactive-Power Protection Addr. Parameter Setting Options Default Setting _:13921:6 Prot. stage 1:Operate 0.00 s to 60.00 s 1.50 s delay grid CB 6.40.3.4 Information List Information Data Class Type (Type) Group indicat. _:4501:55 Group indicat.:Pickup _:4501:57 Group indicat.:Operate Prot.
Page 833: Reclosure Stage
Protection and Automation Functions 6.40 Undervoltage-Controlled Reactive-Power Protection Reclosure Stage 6.40.4 6.40.4.1 Description Logic of the Stage [loqvclst-110713-01.tif, 3, en_US] Figure 6-246 Logic Diagram of Reclosure Stage in Undervoltage-Controlled Reactive-Power Protection Measurand The stage works with fundamental values of voltage and current. Release for Reconnecting The release for reconnecting the power-generation facility is given under the following conditions: SIPROTEC 5, Overcurrent Protection, Manual...
Page 834: Application And Setting Notes
Recommended setting value (_:13951:106) I> release threshold = 0.100 A You use the I> release threshold parameter to define a precondition that the stage can work. The default setting is at 10 % of the rated current. Siemens recommends using the default setting. Parameter: V> threshold value •...
Page 835: Settings
Protection and Automation Functions 6.40 Undervoltage-Controlled Reactive-Power Protection Siemens recommends using the default settings, which reflect common practice in Germany. Other national transmission codes may require a slightly different range. Parameter: Time delay • Default setting (_:13951:108) Time delay = 0.00 s You use the Time delay parameter to specify the minimum time delay for releasing the reconnection of the power-generation facility after tripping by protection.
Page 836: Circuit-Breaker Failure Protection
The 2 functions are identical, with the exception of a slightly increased processor load, in terms of setting options, logic and indications. Siemens recommends using the adaptive circuit-breaker failure protection and avoiding mixing the protection types in one device. You can find additional information on the processor load in DIGSI for each device under Device information in the Resource consumption tab.
Page 837: Function Description
Protection and Automation Functions 6.41 Circuit-Breaker Failure Protection [losvsbfp-090712-01.tif, 2, en_US] Figure 6-248 Function Logic Overview Function Description 6.41.3 The Circuit-breaker failure protection function is started by device-internal protection functions and/or exter- nally (via a binary input or an interface, such as GOOSE). Figure 6-249 Figure 6-250 show the function-...
Page 838 Protection and Automation Functions 6.41 Circuit-Breaker Failure Protection [loanwint-160611-01.tif, 2, en_US] Figure 6-249 Internal Start of the Circuit-Breaker Failure Protection Function External Start The parameter Start via binary input is used to set whether the external start is initiated by a 1- channel or 2-channel signal.
Page 839 Protection and Automation Functions 6.41 Circuit-Breaker Failure Protection Supervision is disabled in the following cases: • On pickup of the Circuit-breaker failure protection function (only in the case of an external start). This prevents an unwanted pickup of the supervision if the external protection that starts the Circuit-breaker failure protection function uses a lockout functionality.
Page 840 Protection and Automation Functions 6.41 Circuit-Breaker Failure Protection If you set the 3I0 criterion parameter to Direct release, you prevent the plausibility check of the zero-sequence current. In this way, a pickup only by way of this current can be achieved. With the Threshold 3I0 dir.
Page 841 Protection and Automation Functions 6.41 Circuit-Breaker Failure Protection Circuit-Breaker Auxiliary Contact Criterion Settings allow you to specify whether the circuit-breaker auxiliary contacts are permitted for determining the circuit-breaker position. The double-point indication 3-pole position (from the Circuit-breaker function block) is used to deter- mine whether all 3 poles of the circuit breaker are closed.
Page 842 Protection and Automation Functions 6.41 Circuit-Breaker Failure Protection [loanreg1-030211-01.tif, 4, en_US] Figure 6-254 Pickup/Dropout of the Circuit-Breaker Failure Protection Function Delay/Tripping In a first step, tripping at the local circuit breaker can be repeated. Tripping is repeated after expiration of the settable delay T1.
Page 843: Application And Setting Notes
Protection and Automation Functions 6.41 Circuit-Breaker Failure Protection [lo-bbp-verza-3ph.vsd, 5, en_US] Figure 6-255 Delay/Tripping of the Circuit-Breaker Failure Protection Function Application and Setting Notes 6.41.4 Figure 6-256 gives an overview of the functions involved in an external start of the CBFP function. In the case of an internal start, there is no external protection device and the protection functionality is located in the CBFP device.
Page 844 Protection and Automation Functions 6.41 Circuit-Breaker Failure Protection [loextpol-021112-01.tif, 2, en_US] Figure 6-256 Circuit-Breaker Failure Protection with External Start, Tripping Repetition and 3-Pole Tripping (T2) Routing: Configuration of Internal Starting Sources (Internal Protection Function) Configuration of the internal starting sources takes place in the protection function groups via the Circuit- breaker interaction entry (for this, see 2.1 Function Embedding in the Device,...
Page 845 There can be operating conditions under which the current flow is higher than the pickup value. To avoid a possible overfunction, Siemens recommends using the 2-channel start. The 1-channel start must be used where only one control circuit of a binary 1 channel input is available for starting the CBFP.
Page 846 NOTE Siemens would like to point out that, with a hold signal, the CBFP generates a trip signal each time a starting pulse is received and the current flow is high enough. Remember this particularly in the case of an external start.
Page 847 Recommended setting value (_:123) Threshold I2 dir. release = approx. 0.5 I2 This parameter is effective only if the I2 criterion parameter is set to Direct release. Siemens recom- mends setting the parameter to half the permissible negative-sequence current (I2 ) to achieve a fast fault clearing in case of an undesired negative-sequence system component.
Page 848 With these parameters, you set the monitoring time of the binary inputs >Start/>Release. If the Circuit- breaker failure protection does not pick up during this monitoring time, a failure in the binary-input circuit is assumed. Siemens recommends retaining the default setting of 15 s. EXAMPLES Applications which require you to permit the circuit-breaker auxiliary contact criterion: •...
Page 849 6.41 Circuit-Breaker Failure Protection • If the minimum fault-clarification time has top priority, Siemens recommends setting the time to 0. This setting causes initiation of the retrip immediately upon the start. The drawback is that a defect of the 1st trip circuit is not detected.
Page 850: Settings
Protection and Automation Functions 6.41 Circuit-Breaker Failure Protection Parameter: Minimum operate time • Default setting (_:112) Minimum operate time = - The Minimum operate time parameter is used to set the minimum duration for tripping the function. CAUTION Do not set a time that is too short. If you set a time that is too short, there is a danger (dropout of the function without the current-flow criterion) that the device contacts will interrupt the control circuit.
Page 851: Information List
Protection and Automation Functions 6.41 Circuit-Breaker Failure Protection Addr. Parameter Setting Options Default Setting • _:104 50BF Ad.CBF #:Dropout with effective criterion with effective • w. aux.c. and curr.crit. criterion • _:108 50BF Ad.CBF #:Retrip • after T1 start T2 after T1 •...
Page 852 Protection and Automation Functions 6.41 Circuit-Breaker Failure Protection Information Data Class Type (Type) _:53 50BF Ad.CBF #:Health _:55 50BF Ad.CBF #:Pickup _:305 50BF Ad.CBF #:Retrip T1 _:306 50BF Ad.CBF #:Trip T2 _:302 50BF Ad.CBF #:BI start routing miss. _:304 50BF Ad.CBF #:BI aux.ct. rout. miss. _:300 50BF Ad.CBF #:Fail.
Page 853: Circuit-Breaker Restrike Protection
Protection and Automation Functions 6.42 Circuit-Breaker Restrike Protection 6.42 Circuit-Breaker Restrike Protection Overview of Function 6.42.1 The Circuit-breaker restrike protection function: • Monitors the circuit breaker against restriking, for example, caused by an overvoltage over the circuit- breaker poles after switching off a capacitor bank •...
Page 854 Protection and Automation Functions 6.42 Circuit-Breaker Restrike Protection [lo_paus-210113-01.vsd, 1, en_US] Figure 6-259 Logic Diagram for the Plausibility Release of the Circuit-Breaker Restrike Protection The plausibility-release logic checks the following conditions: • When the parameter Plausibility via 50BF fct. is set to yes, the pickup signal of the Circuit- breaker failure protection is monitored.
Page 855 Protection and Automation Functions 6.42 Circuit-Breaker Restrike Protection [lo_starstop-210113-01.vsd, 2, en_US] Figure 6-260 Logic Diagram for Start/Stop Monitoring of the Circuit-Breaker Restrike Protection The monitoring is started if one of the following conditions is met: • The circuit-breaker position is detected as open via the circuit-breaker auxiliary contacts during the time set with the parameter Position recognition delay.
Page 856 Protection and Automation Functions 6.42 Circuit-Breaker Restrike Protection [lo_pickdrop-210113-01.vsd, 1, en_US] Figure 6-261 Logic Diagram for Measuring Value, Pickup/Dropout of the Circuit-Breaker Restrike Protection If restriking occurs, the current signal drops below the current threshold if the time between restrike pulses is long enough.
Page 857: Application And Setting Notes
Protection and Automation Functions 6.42 Circuit-Breaker Restrike Protection Application and Setting Notes 6.42.4 Parameter: Switch On or Off Additional Plausibility Release Criteria • Default setting (_:101) Plausibility via 50BF fct. = no • Default setting (_:102) Plaus. via open/trip cmd = no •...
Page 858 The parameter Dropout delay ensures that a short dropping below the current threshold does not cause the operate delay timers to be reset. Since restriking is normally a periodical effect, the dropout delay can be set to a rather small time. Siemens recommends applying the default value of 50 ms.
Page 859 Circuit-breaker restrike protection function will drop out during the T2 delay time. Siemens recommends applying a retrip on the local circuit breaker. Since the retrip is a safety mechanism, it can be given without a delay time. Siemens recommends setting the delay time to 0 s.
Page 860: Settings
Protection and Automation Functions 6.42 Circuit-Breaker Restrike Protection Output signal: Retrip T1 The output signal Retrip T1 must be routed to a binary output. If only one control circuit is available for the local circuit breaker, the output signal must be routed to the binary output to which the general circuit breaker trip command (command Position ) is routed.
Page 861: Information List
Protection and Automation Functions 6.42 Circuit-Breaker Restrike Protection Information List 6.42.6 Information Data Class Type (Type) Restrike prt.# _:500 Restrike prt.#:>Start _:501 Restrike prt.#:>Stop _:502 Restrike prt.#:>release _:82 Restrike prt.#:>Block function _:503 Restrike prt.#:>CB defect _:54 Restrike prt.#:Inactive _:52 Restrike prt.#:Behavior _:53 Restrike prt.#:Health _:304...
Page 862: Restricted Ground-Fault Protection
Protection and Automation Functions 6.43 Restricted Ground-Fault Protection 6.43 Restricted Ground-Fault Protection Overview of Functions 6.43.1 The Restricted ground-fault protection function (ANSI 87N): • Detects ground faults in transformers, shunt reactors, neutral reactors or rotating machinery in which the neutral point is grounded. •...
Page 863: Function Description
Protection and Automation Functions 6.43 Restricted Ground-Fault Protection Function Description 6.43.3 Logic of the Function [loreffkt-170712-01.tif, 1, en_US] Figure 6-264 Logic Diagram of the Restricted Ground-Fault Protection Function The protection function processes the neutral-point current I * (exactly 3I ) and the calculated zero-sequence current I ** (exactly 3I ) from the phase currents (see following figure).
Page 864 Protection and Automation Functions 6.43 Restricted Ground-Fault Protection [dwgrdpri-170712-01.tif, 1, en_US] Figure 6-265 Basic Principle of the Function In accordance with the logic diagram, Figure 6-264 the protection function consists of 3 parts: Effect of Pickup Value The differential current and the restraint current are calculated from the residual currents. The reference arrows are defined as positive when pointing to the protected object (see Figure 6-265).
Page 865 Protection and Automation Functions 6.43 Restricted Ground-Fault Protection [dwstabke-170712-01.tif, 1, en_US] Figure 6-266 Stabilized Characteristic Curve Processing a Ground Side for Auto Transformer Instead of a 1-phase neutral point, with an auto transformer, a 3-phase ground side can also be used. [dwautraf-201112-01.tif, 1, en_US] Figure 6-267 Connecting a Ground Side on the Auto Transformer...
Page 866 Protection and Automation Functions 6.43 Restricted Ground-Fault Protection The following applies for the restraint current: = |I | + |I | + |I | + |I | + |I | + |I Rest,REF gnd,A gnd,B gnd,C NOTE If both 1-phase neutral point and 3-phase ground side are connected, only the 1-phase neutral point is used by the restricted ground-fault protection.
Page 867 Protection and Automation Functions 6.43 Restricted Ground-Fault Protection In an external short circuit (180°), the current becomes positive. At a smaller angle (<180°) due to transformer saturation, the angle remains positive. The amount also decreases. [dwwinken-011112-01.tif, 1, en_US] Figure 6-269 Angle Decision in Internal and External Faults For tripping to occur, the neutral-point current I * must reach the value I...
Page 868: Application And Setting Notes
Protection and Automation Functions 6.43 Restricted Ground-Fault Protection [dwfehler-291112-01.tif, 1, en_US] Figure 6-270 Behavior under Different Fault Conditions Functional Measured Values Measured Value Description (_:306) I REF,operate Operate quantity of the restricted ground-fault protection from the angle criterion (_:307) I Angle,REF Stabilizing value (angle) of the restricted ground-fault protection from the angle criterion (_:311) I REF,Trip operate...
Page 869 Protection and Automation Functions 6.43 Restricted Ground-Fault Protection In the following, typical applications are described for the restricted ground-fault protection. Protection of a Solidly Grounded Star Winding (Y Side) [dwanster-170712-01.tif, 1, en_US] Figure 6-271 Application Star Side This application is a standard application. Here the phase currents of one side and the neutral-point current are processed.
Page 870 Protection and Automation Functions 6.43 Restricted Ground-Fault Protection Explanations on the Connection and Current-Direction Definition Uniform reference arrows and transformer burdens are defined for the SIPROTEC 5 device series. These agree- ments also apply to the transformer protection devices. The special handling of the neutral-point current described previously is a result of this.
Page 871 Protection and Automation Functions 6.43 Restricted Ground-Fault Protection external ground fault. To prevent that, the neutral-point current is rotated in the Transformer neutral-point function group. It follows that: I = |I – I | = 0. Diff, REF NOTE If the neutral-point current is included in the protection function (zero-sequence current correction), this rotation also has an effect for the differential protection.
Page 872 Protection and Automation Functions 6.43 Restricted Ground-Fault Protection The following view can be used to derive the threshold value. The transformer is supplied, for example, via the delta winding and a 1-pole ground fault occurs on the star side. NOTE For estimation of the short-circuit current, note that the inductance changes quadratically with the winding and linearly with the voltage.
Page 873 3 I/Irated,S in the intersection calculation for the restraint current. In the load case, the maximum trans- former rated current flows on one side. If, however, several measuring points are on the supply side (for example, breaker-and-a-half layout), Siemens recommends including all phase currents in the intersection calculation, in order to avoid too strong a stabili- zation.
Page 874 The primary transformer rated current is 1500 A. With this, you can estimate the minimum permissible pickup value. [foscwe01-170712-01.tif, 1, en_US] Siemens recommends a setting value of 0.2 I/Irated,S. • Recommended setting value (_:103) Threshold = 0.2 I/Irated,S SIPROTEC 5, Overcurrent Protection, Manual...
Page 875 400 kV side must be adapted to this rated current. The adaptation factor results from the inverse ratio (230 kV/400 kV). The following restraint current goes into the calculation: [fostbrst-231012-01.tif, 1, en_US] Siemens recommends using the setting value 0.07. • Recommended setting value (_:105) Slope = 0.07 Protection of a Resistance-Grounded Star Winding (Y Side) [dwrefspa-170712-01.tif, 1, en_US]...
Page 876 Protection and Automation Functions 6.43 Restricted Ground-Fault Protection [foschwe3-170712-01.tif, 1, en_US] So that the function is responsive, select a setting value of 0.08 I/Irated,S. • Recommended setting value (_:103) Threshold = 0.08 I/Irated,S As gradient, the following results: [fosteig1-170712-01.tif, 1, en_US] •...
Page 877 Protection and Automation Functions 6.43 Restricted Ground-Fault Protection [dwstrpkt-170712-01.tif, 1, en_US] Figure 6-281 Application with Neutral Reactor As side rated value, the following results: 140 MVA/(√3 · 34.4 kV) = 2343 A You can thus define the lower limit for the threshold value: [foschwe5-170712-01.tif, 1, en_US] If the fault is in the middle of the winding, the minimum ground current will arise, as shown in Figure...
Page 878: Settings
Select 0.35 I/Irated,S as threshold value. • Recommended setting value (_:103) Threshold = 0.35 I/Irated,S For the shunt reactor, there is no external fault that can lead to overfunction. Siemens recommends a minimum rise (0.05). • Recommended setting value (_:105) Slope = 0.05 6.43.5...
Page 879: Information List
Protection and Automation Functions 6.43 Restricted Ground-Fault Protection Addr. Parameter Setting Options Default Setting _:103 87N REF #:Threshold 0.05 I/IrObj to 2.00 I/IrObj 0.20 I/IrObj _:105 87N REF #:Slope 0.00 to 0.95 0.07 _:109 87N REF #:Operate delay 0.00 s to 60.00 s; ∞ 0.00 s •...
Page 880: External Trip Initiation 3-Pole
Protection and Automation Functions 6.44 External Trip Initiation 3-Pole 6.44 External Trip Initiation 3-Pole Overview of Functions 6.44.1 The External trip initiation function: • Processes any signals from external protection or supervision devices • Enables the integration of any signals from external protection equipment in the indication and tripping processing, for example from transient ground-fault relays or Buchholz protection •...
Page 881: Stage Description
Protection and Automation Functions 6.44 External Trip Initiation 3-Pole Stage Description 6.44.3 Logic of the Stage [lotrip3p-070611-01.tif, 1, en_US] Figure 6-284 Logic Diagram for the External Trip-Initiation Stage Binary Input Signal >External Trip The binary input signal >External trip starts the Pickup and the Operate delay. Blocking the Stage The stage can be switched to ineffective via a number of signals.
Page 882: Settings
Protection and Automation Functions 6.44 External Trip Initiation 3-Pole Settings 6.44.5 Addr. Parameter Setting Options Default Setting Stage 1 • _:901:1 Stage 1:Mode • • test • _:901:2 Stage 1:Operate & flt.rec. • blocked _:901:6 Stage 1:Operate delay 0.00 s to 60.00 s 0.05 s 6.44.6 Information List...
Page 883: Automatic Reclosing Function
Protection and Automation Functions 6.45 Automatic Reclosing Function 6.45 Automatic Reclosing Function Overview of Functions 6.45.1 The Automatic reclosing function: • Automatically closes overhead lines after arc short-circuits • Is only permissible for overhead lines, because only the possibility of self-activated extinguishing of an arc short-circuit exists here •...
Page 884 Protection and Automation Functions 6.45 Automatic Reclosing Function For the Cyclic automatic reclosing function, 1 cycle is preset. The preset cycle cannot be deleted. You can add and delete additional cycles from the function library in DIGSI 5. [dwzykawe-100611-01.tif, 1, en_US] Figure 6-287 Structure/Embedding of the Cyclic Automatic Reclosing Function Automatic Reclosing Function with Adaptive Dead Time...
Page 885: Cooperation Of The Automatic Reclosing Function And Protection Functions
Protection and Automation Functions 6.45 Automatic Reclosing Function [loarcfkt-090211-01.tif, 1, en_US] Figure 6-290 Function Control for the Automatic Reclosing Function Cooperation of the Automatic Reclosing Function and Protection Functions 6.45.3 The Automatic reclosing function (AREC) can be influenced by the protection functions in the following way: •...
Page 886 Protection and Automation Functions 6.45 Automatic Reclosing Function [loawesig-190912-01.tif, 1, en_US] Figure 6-291 Signals between Protection Functions and Automatic Reclosing Functions The configuration of the interaction between internal protection functions and automatic reclosing functions can be set separately for each protection function, see Figure 6-291.
Page 887: Cyclic Automatic Reclosing Function
Protection and Automation Functions 6.45 Automatic Reclosing Function [scdigsia-080311-01.tif, 1, en_US] Figure 6-292 Configuration of the Protection Functions for Starting and Blocking the Automatic Reclosing Function in DIGSI 5 If a protection function or the stage of a protection function is connected with the AREC through the matrix, this means that the respective pickup and operate indications are forwarded to the AREC.
Page 888 Protection and Automation Functions 6.45 Automatic Reclosing Function Operating Mode 1: with op., with act. time The operating mode with op., with act. time allows different automatic reclosing cycles depending on the tripping type and operate time of the protection function(s). With this operating mode, the automatic reclosing must be started with the operate indications.
Page 889 Protection and Automation Functions 6.45 Automatic Reclosing Function With raising general pickup, the action times of the configured automatic reclosing cycles start. The general pickup is in this connection the group indication of all internal protection functions configured for starting the automatic reclosing and the external binary input for general pickup >Gen.
Page 890: Structure Of The Cyclic Automatic Reclosing Function
Protection and Automation Functions 6.45 Automatic Reclosing Function The start of the dead time occurs after each trip command. Additionally, the pickup sample from the conductor pickups is considered: • With 1-phase pickup, the automatic reclosing cycles set for 1-phase dead times are activated. 1-phase pickup includes both pickup samples phase-to-ground and only grounding.
Page 891: Input Logic For Operating Modes With Tripping
Protection and Automation Functions 6.45 Automatic Reclosing Function [lozykawe-310511-01.tif, 1, en_US] Figure 6-297 Cyclic Reclosing Function: Block Diagram of Automatic Reclosing 6.45.4.3 Input Logic for Operating Modes with Tripping The operate indications are used as starting signals. For operating modes with action time, the start of the action time(s) occurs with the pickup messages.
Page 892: Input Logic For Operating Modes With Pickup
Protection and Automation Functions 6.45 Automatic Reclosing Function Applications with 3-Pole Tripping For applications with only 3-pole tripping options, the internal operate indications are always 3-pole. For external starts, there is a binary input, which signalizes a 3-pole tripping of the external protection device. The outputs of the input logic signalize that the reclosing start has occurred through a 3-pole operate indica- tion.
Page 893: Start
Protection and Automation Functions 6.45 Automatic Reclosing Function For operating modes with action time, the start of the action time(s) occurs with the pickup indications. During operating modes with pickup, the pickup indications affect the selection of the dead times. During all operating modes, the pickup indications are also required during the processing of faults and for supervision during the reclaim time.
Page 894: Cycle Control With Operating Mode 1: With Tripping/With Action Time
Protection and Automation Functions 6.45 Automatic Reclosing Function Transition to the Dead-Time State The transition of the automatic reclosing function to the dead-time state occurs for: • Clearing operate indications if none of the signal inputs for operate indications are active •...
Page 895 Protection and Automation Functions 6.45 Automatic Reclosing Function is set to invalid. If both dead times are set to invalid, the respective automatic aft. 1-pole trip reclosing cycle will be completely blocked. With the binary input >Block 79 cycle , you can block the asso- ciated automatic reclosing cycle.
Page 896: Cycle Control With Operating Mode 2: With Pickup/With Action Time
Protection and Automation Functions 6.45 Automatic Reclosing Function [loauswir-140611-01.tif, 1, en_US] Figure 6-301 Cycle Control with Operating Mode: With Tripping/With Action Time 6.45.4.7 Cycle Control with Operating Mode 2: With Pickup/With Action Time The cycle control checks the readiness for each automatic reclosing cycle and controls the process of the action time(s).
Page 897 Protection and Automation Functions 6.45 Automatic Reclosing Function Action Time If the automatic reclosing function is in the idle state automatic reclosing function ready, an incoming general pickup will affect the start of the action time. This applies for the reclosing function cycles that are released through the parameter Start from idle state allow.
Page 898: Cycle Control With Operating Mode 3: With Tripping/Without Action Time
Protection and Automation Functions 6.45 Automatic Reclosing Function [loanrwir-140611-01.tif, 1, en_US] Figure 6-302 Cycle Control with Operating Mode: With Pickup/With Action Time 6.45.4.8 Cycle Control with Operating Mode 3: With Tripping/Without Action Time The cycle control checks the availability for each automatic reclosing cycle. In Figure 6-303, the cycle control for the 1st automatic reclosing cycle and other reclosing cycles is illustrated.
Page 899: Cycle Control With Operating Mode 4: With Pickup/Without Action Time
Protection and Automation Functions 6.45 Automatic Reclosing Function tive automatic reclosing cycle will be completely blocked. With the binary input >Block 79 cycle , you can block the associated automatic reclosing cycle. For applications with 1-pole tripping, the cycle control provides a signal, based on which the protection func- tions can recognize that the automatic reclosing function only occurs after 1-pole tripping ( AR only after 1p.
Page 900: Stage Release
Protection and Automation Functions 6.45 Automatic Reclosing Function The cycle availability is influenced through the parameterization of the dead time and through a binary input. In this way, setting the parameter Dead time aft.1ph. pickup to invalid avoids an automatic reclosing after 3-pole tripping due to 1-phase short circuits.
Page 901: Dead Time For Operating Modes With Tripping
Protection and Automation Functions 6.45 Automatic Reclosing Function Figure 6-305 shows the tripping stage release for the 1st automatic reclosing cycle. With available automatic reclosing functions, the tripping stage release typically occurs up to the expiration of the dead time. The cycle number in this state is on 1.
Page 902: Dead Time For Operating Modes With Pickup
Protection and Automation Functions 6.45 Automatic Reclosing Function As soon as an evolving fault is recognized (see chapter 6.45.4.13 Evolving-Fault Detection During Dead Time), switching to an automatic reclosing cycle for 3-pole interruption occurs. With the 3-pole cut-off of the evolving fault, a separate adjustable dead time for the evolving fault begins.
Page 903: Evolving-Fault Detection During Dead Time
Protection and Automation Functions 6.45 Automatic Reclosing Function As soon as an evolving fault is recognized (see chapter 6.45.4.13 Evolving-Fault Detection During Dead Time), a separate dead time for faults begins with the stopping of the fault. The total dead time is composed of the part of the dead time that expired until the evolving fault was stopped for the 1st disruption plus the dead time for the evolving fault.
Page 904 Protection and Automation Functions 6.45 Automatic Reclosing Function The evolving-fault detection is divided into components: • Detection of Evolving Faults • Evolving-Faults Processing • 3-pole circuit-breaker intertripping during evolving faults The procedure during evolving faults is illustrated in Figure 6-309. Detection of Evolving Faults For the detection of an evolving fault, the following criteria can be selected through parameters: •...
Page 905: Closing Indication And Close Command
Protection and Automation Functions 6.45 Automatic Reclosing Function [lofolsjk-021212-01.tif, 1, en_US] Figure 6-310 Cyclic Automatic Reclosing Function - Logic of Evolving-Fault Detection 6.45.4.14 Closing Indication and Close Command After the expiration of the dead time, the Automatic reclosing function will be in the closing state. The closing state can depend on the following influences, see Figure 6-311:...
Page 906 Protection and Automation Functions 6.45 Automatic Reclosing Function [loeinsha-141111-01.tif, 1, en_US] Figure 6-311 Cyclic Reclosing Function: Logic for the Closing Indication Testing the Circuit-Breaker Readiness Directly before Closing For each of the automatic reclosing cycles, you can set if a test of the circuit-breaker readiness should occur directly before closing (parameters CB ready check bef.close, Figure 6-312).
Page 907 Protection and Automation Functions 6.45 Automatic Reclosing Function [lolsvoei-130511-01.tif, 1, en_US] Figure 6-312 Cyclic Reclosing Function: Logic for the Query of the Circuit-Breaker Readiness Directly before Closing Synchrocheck For each of the configured automatic reclosing cycles, you can set if a synchrocheck should be executed and which functionality should be used here, see Figure 6-313.
Page 908: Reclaim Time
Protection and Automation Functions 6.45 Automatic Reclosing Function In addition to the closing indication, additional indications will be created that describe the type of closure. These include: • Close command after 3-pole tripping in the first cycle ( Cls.cmd after 3p.1.cyc ) •...
Page 909: Circuit-Breaker Readiness
Protection and Automation Functions 6.45 Automatic Reclosing Function [losperre-140611-01.tif, 1, en_US] Figure 6-314 Cyclic Reclosing Function: Logic for the reclaim time 6.45.4.16 Circuit-Breaker Readiness The automatic reclosing function requires the readiness of the circuit breaker for the following purposes, see Figure 6-315: •...
Page 910: Blockings
Protection and Automation Functions 6.45 Automatic Reclosing Function [lolsbere-130511-01.tif, 1, en_US] Figure 6-315 Cyclic Reclosing Function: Logic for the Circuit-Breaker Readiness 6.45.4.17 Blockings The Automatic reclosing function differentiates between 2 types of blockings, see Figure 6-316: • Static blocking • Dynamic blocking Static Blocking The Automatic reclosing function is statically blocked if the function is switched on, but is not ready for...
Page 911 Protection and Automation Functions 6.45 Automatic Reclosing Function Condition Indication No reclosing cycle possible Inactive Recognition due to the following causes: • Automatic reclosing cycle is not set. • Automatic reclosing cycles are set, but all are blocked, for example, via binary input. •...
Page 912 Protection and Automation Functions 6.45 Automatic Reclosing Function Condition Indication If the inquiry of the circuit-breaker readiness is switched on Not ready directly before the close command through the parameter and Blk.by CB ready sup. the maximum dead-time prolongation expires Blk.by max.d.t.
Page 913: Dead-Line Checking (Dlc) And Reduced Dead Time (Rdt)
Protection and Automation Functions 6.45 Automatic Reclosing Function [lobloawe-100611-01.tif, 3, en_US] Figure 6-316 Cyclic Reclosing Function: Blocking Logic in the Example for a 1-Pole Cycle (Static and Dynamic Blocking) 6.45.4.18 Dead-Line Checking (DLC) and Reduced Dead Time (RDT) The additional functions Dead-line check (DLC) and Reduced dead time (RDT), are only possible for applica- tions with a voltage-transformer connection.
Page 914 Protection and Automation Functions 6.45 Automatic Reclosing Function Both additional functions DLC and RDT are mutually exclusive, because the DLC checks if the value falls below a voltage threshold, while the RDT checks if the value exceeds the voltage threshold. The respectively selected additional function runs in the automatic reclosing state dead time.
Page 915: Settings
Protection and Automation Functions 6.45 Automatic Reclosing Function [lovrkarc-130511-01.tif, 1, en_US] Figure 6-317 Cyclic Reclosing Function: Logic for the Functions of Reduced Dead Time and Dead-Line Check 6.45.4.19 Settings Addr. Parameter Setting Options Default Setting General • _:6601:1 General:Mode • •...
Page 916 Protection and Automation Functions 6.45 Automatic Reclosing Function Addr. Parameter Setting Options Default Setting • _:6601:102 General:CB ready check • bef. start _:6601:103 General:Reclai. time 0.50 s to 300.00 s 3.00 s aft.succ.cyc. _:6601:104 General:Block. time aft. 0.00 s to 300.00 s 1.00 s man.close _:6601:105...
Page 917: Information List
Protection and Automation Functions 6.45 Automatic Reclosing Function Addr. Parameter Setting Options Default Setting • _:6571:110 Cycle 1:Synchroch. aft. none none • 3-pole d.t. internal • external _:6571:112 Cycle 1:Intern. synchro- Setting options depend on check with configuration 6.45.4.20 Information List Information Data Class Type...
Page 918 Protection and Automation Functions 6.45 Automatic Reclosing Function Information Data Class Type (Type) _:6601:308 General:AR only after 1p. trip _:6601:309 General:In progress _:6601:310 General:Reclaim time running _:6601:311 General:Start sig. superv.exp. _:6601:313 General:Evolv.-fault detected _:6601:314 General:RDT CloseCmd indicat. _:6601:315 General:Dead t. aft.1pole trip _:6601:316 General:Dead t.
Page 919: Automatic Reclosing Function With Adaptive Dead Time (Adt)
Protection and Automation Functions 6.45 Automatic Reclosing Function Automatic Reclosing Function with Adaptive Dead Time (ADT) 6.45.5 6.45.5.1 Description Description It is also possible to set the dead times only at one line end and to configure the adaptive dead time at the other end or ends.
Page 920: Settings
Protection and Automation Functions 6.45 Automatic Reclosing Function 6.45.5.2 Settings Addr. Parameter Setting Options Default Setting General • _:6601:1 General:Mode • • test • _:6601:101 General:79 operating mode with op., w/o act. time with op., with • with op., with act. time act.
Page 921 Protection and Automation Functions 6.45 Automatic Reclosing Function Information Data Class Type (Type) _:6601:502 General:>Blk. with 1-ph pickup _:6601:503 General:>Blk. with 2-ph pickup _:6601:504 General:>Blk. with 3-ph pickup _:6601:505 General:>Blk. 1-pole AR _:6601:506 General:>Blk. 3-pole AR _:6601:507 General:>Pickup A for start _:6601:508 General:>Pickup B for start _:6601:509...
Page 922: Cooperation With External Automatic Reclosing Function
Protection and Automation Functions 6.45 Automatic Reclosing Function Information Data Class Type (Type) _:6601:330 General:Blk.by action time exp _:6601:331 General:Blk.by max.d.t. expiry _:6601:337 General:Block. by no cycle _:6601:338 General:Block. by protection _:6601:335 General:Blk.by loss of voltage _:6601:336 General:Block. by max. cycles _:6601:339 General:Cyc1 1p AR _:6601:340...
Page 923: Information List
Protection and Automation Functions 6.45 Automatic Reclosing Function [loaweext-140212-01.tif, 1, en_US] Figure 6-319 Connection of an External Automatic Reclosing Function There are no setting parameters for operation with external automatic reclosing functions. The function provides exclusively the following described binary inputs. The external reclosing device can thus have an influence on the effects of the internal protection functions.
Page 924: Application And Setting Notes For General Settings
Protection and Automation Functions 6.45 Automatic Reclosing Function Application and Setting Notes for General Settings 6.45.7 For the automatic reclosing function, there are 3 functions available in the function library. In each circuit- breaker function group, a function from the automatic reclosing function can be used. Configure one of the 3 following function specifications: •...
Page 925 Siemens generally recommends this setting for applications with 1/3-pole trip- ping and for applications with 3-pole tripping if a single dead time, independent of the type of connection working, is required in the automatic reclosing func- tion cycle.
Page 926 If the circuit breaker is not ready, the automatic reclosing function reports the static blocking. Siemens recommends using this setting. Note: The presetting of this parameter does not correspond with the recom- mended setting for operation. The automatic reclosing function would other- wise be blocked with a non-available circuit breaker-ready-signal.
Page 927 For applications with 1-/3-pole tripping, Siemens recommends the setting with trip if the system is adequately interconnected. If multiple individual lines in a row form a total transmission path, the setting with pickup may be better suitable.
Page 928 For the subfunction Dead-line check, the surpassing of a voltage threshold is checked. Siemens recommends the setting 0.10 s. Detailed information about the functionality can be found in the following parameters and in the chapters 6.45.4.18 Dead-Line Checking (DLC) and Reduced Dead Time (RDT)
Page 929 Protection and Automation Functions 6.45 Automatic Reclosing Function Parameter: Volt. thres.f. live line/bus This parameter is only important if you use the subfunction RDT or the function ADT. If you do not use any of these functions, the setting of this parameter is free to select. •...
Page 930: Application And Setting Notes For 1 Cycle Of The Cyclic Automatic Reclosing Function
Protection and Automation Functions 6.45 Automatic Reclosing Function You can find detailed information about this functionality in the chapter 6.45.4.14 Closing Indication and Close Command Application and Setting Notes for 1 Cycle of the Cyclic Automatic Reclosing 6.45.8 Function For the function of the cyclic automatic reclosing function, 1 cycle is preset. The preset cycle cannot be deleted.
Page 931 Siemens recommends this setting, if it is sufficient to check the readiness of the circuit breaker for the entire switching cycle once before the start of a reclosing function, consisting of tripping-reclosing-tripping.
Page 932 (_: 6601:111) Max. dead-time extension . Siemens recommends this setting, if it can be assumed that the circuit breaker becomes available to switch on the reclosing function only after an additional waiting period.
Page 933: Fault Locator
Protection and Automation Functions 6.46 Fault Locator 6.46 Fault Locator Overview of Functions 6.46.1 The Fault locator function serves for measuring the fault distance in the event of a short circuit. Quick determination of fault location and the associated rapid troubleshooting increase the availability of the line for the power transmission in the electrical power system.
Page 934: Function Description
Protection and Automation Functions 6.46 Fault Locator Function Description 6.46.3 Starting Conditions The fault location is an independent function with its own measurand memory and its own filter algorithms. To define the valid measuring loop and the most favorable time interval for the measured variable saving, only a start command is required by the short-circuit protection.
Page 935: Application And Setting Notes
Protection and Automation Functions 6.46 Fault Locator Measured-Value Correction at Load Current on Lines Fed on Both Sides In the case of faults on lines fed on both sides and with load transport (see next figure), the fault voltage Υ not only influenced by the source voltage Ε...
Page 936 Protection and Automation Functions 6.46 Fault Locator Parameter: Start • Default setting (_:101) Start = with dropout The Start parameter is used to define the criterion for starting the fault location. The following functions can start the fault locator: • Overcurrent protection, phases or ground •...
Page 937 Protection and Automation Functions 6.46 Fault Locator EXAMPLE 110-kV overhead line, 150 mm with the data R´ = 0.19 Ω/km X´ = 0.42 Ω/km You calculate the setting value for the line angle as follows: [folwibsp-050912-01.tif, 1, en_US] Parameter: Kr and Kx •...
Page 938 Protection and Automation Functions 6.46 Fault Locator Parameter: K0 and Angle (K0) • Default setting K0 = 1.000 • Default setting Angle (K0) = 0.00° NOTE The visibility of the K0 and Angle (K0) parameters depends on the selected setting format of the residual compensation factors.
Page 939: Settings
Protection and Automation Functions 6.46 Fault Locator [fofork04-180912-01.tif, 1, en_US] When determining the angle, take note of the quadrant of the result. The following table lists the quadrants and the angle range obtained from the operational signs of the real and imaginary parts of K0 . Real Part Imagi- tan Phi Quadrant/Range...
Page 940 Protection and Automation Functions 6.46 Fault Locator Information Data Class Type (Type) _:308 Fault locator:Fault resistance sec. _:309 Fault locator:Fault reactance sec. _:304 Fault locator:Fault distance _:305 Fault locator:Fault distance in % _:306 Fault locator:Fault loop _:307 Fault locator:FLO invalid SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 941: Temperature Supervision
Protection and Automation Functions 6.47 Temperature Supervision 6.47 Temperature Supervision Overview of Functions 6.47.1 The Temperature supervision function checks the thermal state of: • Motors • Generators • Transformers In rotating machines, it also checks bearing temperatures for a limit violation. The temperatures are measured at various locations of the protected object using temperature sensors (RTD = Resistance Temperature Detector) and are sent to the device via one or more RTD units.
Page 942: Function Description
Protection and Automation Functions 6.47 Temperature Supervision Function Description 6.47.3 Logic [lotmpsup-170712-01.tif, 2, en_US] Figure 6-324 Logic Diagram for a Temperature Supervision Location The Temperature supervision location function block (Location FB) receives a measured temperature value in °C or °F as an input variable delivered from the temperature sensor function blocks of the Analog units function group.
Page 943: Settings
Protection and Automation Functions 6.47 Temperature Supervision Parameter: Sensor location • Default setting (_:11101:46) Sensor location = Other You inform the device of the sensor installation location using the Sensor location parameter. Oil, Ambient, Turn, Bearing and Other are available for selection. The selection is not evaluated in the device, it only serves an informational purpose in the medium in which the temperature measurement takes place.
Page 944 Protection and Automation Functions 6.47 Temperature Supervision Addr. Parameter Setting Options Default Setting • _:11101:1 Point 1:Mode • • test _:11101:40 Point 1:Threshold stage 1 -50°C to 250°C 100°C _:11101:41 Point 1:Operate delay of 0 s to 60 s; ∞ stage 1 _:11101:42 Point 1:Threshold stage 2...
Page 945 Protection and Automation Functions 6.47 Temperature Supervision Addr. Parameter Setting Options Default Setting • _:11104:1 Point 4:Mode • • test _:11104:40 Point 4:Threshold stage 1 -50°C to 250°C 100°C _:11104:41 Point 4:Operate delay of 0 s to 60 s; ∞ stage 1 _:11104:42 Point 4:Threshold stage 2...
Page 946 Protection and Automation Functions 6.47 Temperature Supervision Addr. Parameter Setting Options Default Setting • _:11107:1 Point 7:Mode • • test _:11107:40 Point 7:Threshold stage 1 -50°C to 250°C 100°C _:11107:41 Point 7:Operate delay of 0 s to 60 s; ∞ stage 1 _:11107:42 Point 7:Threshold stage 2...
Page 947 Protection and Automation Functions 6.47 Temperature Supervision Addr. Parameter Setting Options Default Setting • _:11110:1 Point 10:Mode • • test _:11110:40 Point 10:Threshold stage 1 -50°C to 250°C 100°C _:11110:41 Point 10:Operate delay of 0 s to 60 s; ∞ stage 1 _:11110:42 Point 10:Threshold stage 2...
Page 948: Information List
Protection and Automation Functions 6.47 Temperature Supervision Information List 6.47.6 Information Data Class Type (Type) Point 1 _:11101:81 Point 1:>Block stage _:11101:54 Point 1:Inactive _:11101:52 Point 1:Behavior _:11101:53 Point 1:Health _:11101:61 Point 1:Pickup stage 1 _:11101:62 Point 1:Operate stage 1 _:11101:63 Point 1:Pickup stage 2 _:11101:64...
Page 949 Protection and Automation Functions 6.47 Temperature Supervision Information Data Class Type (Type) _:11105:64 Point 5:Operate stage 2 Point 6 _:11106:81 Point 6:>Block stage _:11106:54 Point 6:Inactive _:11106:52 Point 6:Behavior _:11106:53 Point 6:Health _:11106:61 Point 6:Pickup stage 1 _:11106:62 Point 6:Operate stage 1 _:11106:63 Point 6:Pickup stage 2 _:11106:64...
Page 950 Protection and Automation Functions 6.47 Temperature Supervision Information Data Class Type (Type) Point 11 _:11111:81 Point 11:>Block stage _:11111:54 Point 11:Inactive _:11111:52 Point 11:Behavior _:11111:53 Point 11:Health _:11111:61 Point 11:Pickup stage 1 _:11111:62 Point 11:Operate stage 1 _:11111:63 Point 11:Pickup stage 2 _:11111:64 Point 11:Operate stage 2 Point 12...
Page 951: Phase-Sequence Switchover
Protection and Automation Functions 6.48 Phase-Sequence Switchover 6.48 Phase-Sequence Switchover Overview of Functions 6.48.1 The Phase-sequence reversal function enables correct execution of the protection of the device and supervi- sion functions, independently of the phase sequence of the phases in a system or system section. The phase sequence is set via parameters.
Page 952 Protection and Automation Functions 6.48 Phase-Sequence Switchover • With the binary signal >Phs-rotation reversal , you change over the phase sequence of all meas- uring points. • With the binary signal >Invert Phases , you change over the phase sequence per measuring point. The Inverted phases parameter available for each measuring point is used to set which phases at the measuring point must be swapped.
Page 953 Protection and Automation Functions 6.48 Phase-Sequence Switchover [dwphrpsys1-151013, 1, en_US] Figure 6-327 Phase Sequence Switchover Changing Over the Phase Sequence per Measuring Point A switchover of the phase sequence per measuring point can also be necessary for operational reasons. This switchover enables proper behavior of the protection equipment, for example at the transition from generator operation to motor operation (pump operation).
Page 954: Application And Setting Notes
Protection and Automation Functions 6.48 Phase-Sequence Switchover The phase sequence is also relevant to the impedance protection (IED3). Depending on the switch position, the voltage measured values 1 and the current measured values 3 have a different phase sequence. The phase sequence of the system is set in the device via the Phase sequence parameter for generator operation.
Page 955: Settings
Protection and Automation Functions 6.48 Phase-Sequence Switchover Phase A changed over with phase C Phase B changed over with phase C Phase C changed over with phase B NOTE If you change the setting value of the parameter Inverted phases, consider the following: The device can take the new setting value only if the binary input signal >Invert Phases is not active.
Page 956: Information List
Protection and Automation Functions 6.48 Phase-Sequence Switchover Information List 6.48.6 Information Data Class Type (Type) General _:500 General:>Phs-rotation reversal _:501 General:>Invert Phases General _:319 General:Phase sequence ABC _:320 General:Phase sequence ACB _:321 General:Freq.out of oper.range _:322 General:f sys _:323 General:f track General _:315 VT 3-phase:Phases AB inverted...
Page 957: Current-Jump Detection
Protection and Automation Functions 6.49 Current-Jump Detection 6.49 Current-Jump Detection Overview of Functions 6.49.1 The Current jump detection function has the following tasks: • Detection of jumps in the phase or zero-sequence current (ΔI) • Generation of an indication when the measurands change by more than a configured threshold value from one system period to the next.
Page 958: Application And Setting Notes
Protection and Automation Functions 6.49 Current-Jump Detection Logic [lojumpii-271011-01.tif, 1, en_US] Figure 6-331 Current-Jump Detection Logic Application and Setting Notes 6.49.4 Parameter: Measured value • Default setting (_:9) Measured value = phase currents With the parameter Measured value, you set whether the line current(s) or the residual current is to be used for jump detection.
Page 959: Settings
Protection and Automation Functions 6.49 Current-Jump Detection Parameter: Minimum pulse length • Default setting (_:102) Minimum pulse length = 0.10 s With the parameter Minimum pulse length, you specify a consistent minimum size for the output indica- tion Pulse . Settings 6.49.5 Addr.
Page 960: Voltage-Jump Detection
Protection and Automation Functions 6.50 Voltage-Jump Detection 6.50 Voltage-Jump Detection Overview of Functions 6.50.1 The Voltage-jump detection function has the following tasks: • Recognition of jumps in the phase or zero-sequence voltage (ΔV) • Generation of an indication when the measurands change by more than a configured threshold value from one system cycle to the next.
Page 961: Application And Setting Notes
Protection and Automation Functions 6.50 Voltage-Jump Detection the measured value is set to phase-to-phase, the pulse duration is signaled selectively for the individual meas- uring elements that have picked up ( Pulse VAB , Pulse VBC or Pulse VCA ). Logic [lojumpuu-011211-01.tif, 2, en_US] Figure 6-333...
Page 962: Settings
Protection and Automation Functions 6.50 Voltage-Jump Detection Parameter: Threshold • Default setting (_:101) Threshold = 5.000 V With the parameter Threshold , you set the threshold value for the measurand which, when exceeded, generates the output indication Jump . Parameter: Minimum pulse length •...
Page 963: Voltage Measuring-Point Selection
Protection and Automation Functions 6.51 Voltage Measuring-Point Selection 6.51 Voltage Measuring-Point Selection Overview of Functions 6.51.1 The function block Voltage measuring-point selection can: • Provide the ability to switchover the voltage measuring points to be applied, if various voltage measuring points are connected to the voltage interface of the function group •...
Page 964: Application And Setting Notes
Protection and Automation Functions 6.51 Voltage Measuring-Point Selection [scconnection, 1, en_US] Figure 6-335 Connecting the Measuring Points with the Capacitor Bank Function Group There are consistency checks that validate the connections of voltage measuring points to the function group: • The connection type must be identical for all measuring points connected to the same interface of the function group.
Page 965: Information List
Protection and Automation Functions 6.51 Voltage Measuring-Point Selection NOTE An invalid measuring-point selection (ID < 0 or an ID of a unconnected measuring point) for input >MP-ID selection results in the following: • The voltage measured values are displayed as failure. •...
Page 966 SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 967: Capacitor Bank Protection
Capacitor Bank Protection Introduction Overcurrent Protection for Capacitor Banks Thermal Overload Protection for Capacitor Banks Current-Unbalance Protection for Capacitors, 3-Phase Current-Unbalance Protection for Capacitors, 1-Phase 1002 Peak Overvoltage Protection for Capacitors 1020 Voltage Differential Protection for Capacitors 1032 Differential Protection for Capacitor Banks 1043 Detuning Supervision for Capacitor Banks 1070...
Page 968: Introduction
Capacitor Bank Protection 7.1 Introduction Introduction Capacitors and capacitor banks are used for various applications. Examples are: • Reactive-power compensation for voltage stabilization • Fast voltage- and reactive-power control • Filter circuits for the elimination of certain frequencies Capacitor banks for transmission systems are complex systems customized for the special application. The design depends much on the used switching technology (for example, mechanically or via thyristor).
Page 969: Overcurrent Protection For Capacitor Banks
Capacitor Bank Protection 7.2 Overcurrent Protection for Capacitor Banks Overcurrent Protection for Capacitor Banks Overview 7.2.1 You can use the following overcurrent protection function types in the Capacitor bank function group: • Overcurrent protection, phases with phase-segregated operate indications for short-circuit protection in the area between the busbar and the capacitor and for protecting against overload of a subbank.
Page 970: Function Description
Capacitor Bank Protection 7.2 Overcurrent Protection for Capacitor Banks [dwocpRLC-190813-01.vsd, 3, en_US] Figure 7-1 Structure/Embedding of the Overcurr. -3ph RLC Function 7.2.2.2 Function Description A feature of the Overcurr. -3ph RLC function is the selection of measuring points. A capacitor bank can include multiple filter circuits.
Page 971: Application And Setting Notes
Capacitor Bank Protection 7.2 Overcurrent Protection for Capacitor Banks Measured Values Description Primary Secondary % Referenced to (_:13501:301) Iph 3 phase currents of the meas- Parameter Capacitor uring point reference curr. or RLC rated current depending on the setting of parameter Rated-current selec- tion You can find the parameter Capacitor reference curr.
Page 972 Capacitor Bank Protection 7.2 Overcurrent Protection for Capacitor Banks Parameter Value Description Select this setting if you want to use the individual rated current of the RLC RLC rated current object to be proteced (for example, a resistor or reactor) as the reference value.
Page 973: Thermal Overload Protection For Capacitor Banks
Capacitor Bank Protection 7.3 Thermal Overload Protection for Capacitor Banks Thermal Overload Protection for Capacitor Banks Overview of Functions 7.3.1 The function Thermal overload protection for capacitor banks (Overload RLC) protects RLC filter circuit elements in a capacitor bank from thermal overload. NOTE The structure of the function Overload RLC differs only slightly from that of the standard Thermal over- load protection, 3-phase –...
Page 974: Application And Setting Notes
Capacitor Bank Protection 7.3 Thermal Overload Protection for Capacitor Banks Selection and Setting of the Rated Current With the parameter Rated-current selection, you define whether this function uses the rated current of the whole capacitor bank or the individual rated current of the protected object (for example, reactor or resistor branch within the capacitor-bank installation) as the reference value.
Page 975: Settings
Capacitor Bank Protection 7.3 Thermal Overload Protection for Capacitor Banks The selection list displays the measuring points that are connected to the I 3ph RLC interface of the Capacitor bank function group: [scmpselection_tolp_rlc, 1, en_US] Figure 7-5 Example of Measuring-Point Selection The MP selection parameter is set for all stages.
Page 976: Information List
Capacitor Bank Protection 7.3 Thermal Overload Protection for Capacitor Banks Addr. Parameter Setting Options Default Setting _:2311:102 General:RLC rated 1 A to 100 000 A 1 000 A current MP selection • _:13501:100 MP selection:Consistency no MP configured no MP config- •...
Page 977: Current-Unbalance Protection For Capacitors, 3-Phase
Capacitor Bank Protection 7.4 Current-Unbalance Protection for Capacitors, 3-Phase Current-Unbalance Protection for Capacitors, 3-Phase Overview of Functions 7.4.1 The Current-unbalance protection for capacitors, 3-phase function (ANSI 60C): • Protects in case of capacitor elements (C-elements) faults of a capacitor bank in H connection •...
Page 978 Capacitor Bank Protection 7.4 Current-Unbalance Protection for Capacitors, 3-Phase Logic for Compensation and Normalization [lo_FBallg_iunbal-020913.tif, 3, en_US] Figure 7-8 Cross-Stage Functionality Measuring-Point Selection With the MP selection parameter, you can select from a list of measuring points a measuring point that is connected to the I Unbalanced interface in the Capacitor bank function group.
Page 979 Capacitor Bank Protection 7.4 Current-Unbalance Protection for Capacitors, 3-Phase The compensated and non-compensated unbalanced currents are provided for the overcurrent-protection stage. Within the protection stage, one of the 2 values is selected in the protection stage via the parameter Measured value. Both values are available as functional measured values (see Figure 7-8).
Page 980 Capacitor Bank Protection 7.4 Current-Unbalance Protection for Capacitors, 3-Phase Automatic Compensation When using the parameter Automatic compensation , this automatic compensation function can be enabled or disabled. The automatic compensation consists of 2 different mechanisms: • The event-based compensation of any existing unbalance. This compensation is performed in the following situations: –...
Page 981 Capacitor Bank Protection 7.4 Current-Unbalance Protection for Capacitors, 3-Phase In this case, normalization with current I will no longer work properly either. The normalization is canceled in a phase-segregated manner. This means that the non-normalized value is used in place of the normalized value (see Figure 7-8).
Page 982 Capacitor Bank Protection 7.4 Current-Unbalance Protection for Capacitors, 3-Phase [lo-cnt-EF-260314-01, 3, en_US] Figure 7-9 Counting Faulty C-Elements Activation/Blocking Counting If at least one counter stage is enabled, the counter function is active. Furthermore, the counter function works only if the automatic compensation is enabled. In order to prevent counting as a consequence of the charging process, the counter function is implicitly blocked for 250 ms by setting I to 0 A, after the capacitor energizing has been detected.
Page 983 Capacitor Bank Protection 7.4 Current-Unbalance Protection for Capacitors, 3-Phase Resetting/Setting the Counters You can reset or set the counters of group 1 and group 2 via: • On-site operation panel directly on the device • Online DIGSI connection to the device •...
Page 984: Application And Setting Notes
Capacitor Bank Protection 7.4 Current-Unbalance Protection for Capacitors, 3-Phase [dwfehlerortinf_iunsy-020913, 1, en_US] Figure 7-10 Definition of the Fault-Location Information The black dot indicates the orientation of the current transformer. For the connection of the current trans- former shown in the previous figure, the following definition applies: •...
Page 985 C-element is detected. Information about occurring unbalanced current as a consequence of single faulty C-elements will be provided by the manufacturer of the capacitor bank. Siemens recommends to set the threshold value to approx. 75 % of the unbalanced current that occurs after the fault of the 1st C- element.
Page 986 Capacitor Bank Protection 7.4 Current-Unbalance Protection for Capacitors, 3-Phase Secondary setting value: 0.75 ⋅ 0.071 A = 0.053 A NOTE Use sensitive device current inputs in order to apply secondary thresholds of < 30 mA. If no information is provided by the manufacturer of the capacitor bank, the following example can be used as a basis in order to determine the value.
Page 987 Capacitor Bank Protection 7.4 Current-Unbalance Protection for Capacitors, 3-Phase 2b) Internal Structure of a Can The internal structure of a can must be known or must be determined. This information can be requested from the manufacturer of the capacitor bank. This example assumes the following internal structure of the can: - 14 parallel capacitances - Internal fuses (one internal fuse per capacitance)
Page 988 Capacitor Bank Protection 7.4 Current-Unbalance Protection for Capacitors, 3-Phase In this example, the phase current is determined using the following assumptions and data: • 1-phase rated capacitance of the capacitor bank: 2.81 μF • Phase-to-ground voltage of the fundamental component of the capacitor bank: 249.1 kV •...
Page 989 Capacitor Bank Protection 7.4 Current-Unbalance Protection for Capacitors, 3-Phase Based on the cross-linking of the cans, in case of an element fault, the capacitance of the parallel cans must be determined first: • Capacitance of 2 parallel cans in case of an element fault: = 19.456 μF + 19.67 μF = 39.126 μF 2K,1EF Capacitance in the quarter of C1 in case of an element fault:...
Page 990 Capacitor Bank Protection 7.4 Current-Unbalance Protection for Capacitors, 3-Phase Example 3 (a to d): Unbalanced-Current Information Not Available from the Manufacturer of the Capacitor Bank, External Capacitor-Bank Structure without Cross-Linked Cans Example 3 is almost identical to example 2. The only difference is that the cans are not cross-linked. Here, only the calculation part is discussed that is a result of the different external structure.
Page 991 Capacitor Bank Protection 7.4 Current-Unbalance Protection for Capacitors, 3-Phase [dw4tlkbnk-120314-01, 1, en_US] Figure 7-15 Quarters of the Capacitor Bank • Capacitance in the quarter of C1 in case of an element fault (C1 Capacitance in the row without element fault: = 1.5130 μF RoEF •...
Page 992 Capacitor Bank Protection 7.4 Current-Unbalance Protection for Capacitors, 3-Phase Resetting the Counters via Protocols IEC 60870-5-103, IEC 60870-5-104, DNP3, or Modbus The following example shows how to use a function chart (CFC) to reset the counters with the protocols IEC 60870-5-103, IEC 60870-5-104, DNP3, or Modbus. EXAMPLE •...
Page 993: Settings
Capacitor Bank Protection 7.4 Current-Unbalance Protection for Capacitors, 3-Phase 7.4.3.3 Settings Addr. Parameter Setting Options Default Setting MP selection • _:13501:100 MP selection:Consistency no MP configured no MP config- • failure no Sensor configured ured _:13501:81 MP selection:MP selec- Setting options depend on tion configuration General...
Page 994: Overcurrent-Protection Stage I
Capacitor Bank Protection 7.4 Current-Unbalance Protection for Capacitors, 3-Phase Information Data Class Type (Type) _:2311:323 General:Cp.vect. 7.4.4 Overcurrent-Protection Stage I> 7.4.4.1 Description Logic of a Stage [lounbalstufe-020913, 1, en_US] Figure 7-18 Logic Diagram of the Overcurrent-Protection Stage I> SIPROTEC 5, Overcurrent Protection, Manual C53000-G5040-C017-8, Edition 07.2017...
Page 995 Capacitor Bank Protection 7.4 Current-Unbalance Protection for Capacitors, 3-Phase Measurands Within the protection stage, the compensated and the non-compensated unbalanced currents are available. Use the parameter Measured value to select one of the 2 values. Both values are displayed as measured values of the function at the function stage.
Page 996: Application And Setting Notes
Capacitor Bank Protection 7.4 Current-Unbalance Protection for Capacitors, 3-Phase [dwfehlerortinf_iunsy-020913, 1, en_US] Figure 7-19 Definition for the Fault-Location Information The black dot indicates the orientation of the current transformer. For the connection of the current trans- former shown in the previous figure, the following definition applies: •...
Page 997: Settings
250 ms after energizing has been detected in order to avoid a pickup as a consequence of the charging process. Siemens recommends using compensated unbalanced values. In case that automatic compensation is applied, please consider the setting notes for the operate delay.
Page 998: Information List
Capacitor Bank Protection 7.4 Current-Unbalance Protection for Capacitors, 3-Phase 7.4.4.4 Information List Information Data Class Type (Type) I> 1 _:13801:81 I> 1:>Block stage _:13801:54 I> 1:Inactive _:13801:52 I> 1:Behavior _:13801:53 I> 1:Health _:13801:55 I> 1:Pickup _:13801:56 I> 1:Operate delay expired _:13801:57 I>...
Page 999: Counter Stage
Capacitor Bank Protection 7.4 Current-Unbalance Protection for Capacitors, 3-Phase Counter Stage 7.4.5 7.4.5.1 Description Logic of a Stage [lo-cnt-stage-260314-01, 2, en_US] Figure 7-20 Logic Diagram of the Counter Stage Measurands/Input Values The measurand/input values of the counter stage are the phase- and group-segregated counter contents that are determined in the General FB.
Page 1000: Application And Setting Notes
Capacitor Bank Protection 7.4 Current-Unbalance Protection for Capacitors, 3-Phase Pickup, Tripping Delay Supervision of the counter contents is phase-segregated. If a counter reaches the preset threshold (parameter Max. no. of def. elem. phs A , Max. no. of def. elem. phs B , Max. no. of def. elem.

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7sj85

Siemens 7SJ82 Manual

Preface

Open Source Software

1 Introduction

2 Basic Structure of the Function

3 System Functions

4 Applications

5 Function-Group Types

6 Protection and Automation Functions

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Summary of Contents for Siemens 7SJ82