SIEMENS Automation System Part 1 of 3
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Overview: Siemens Automation System Part 1 of 3
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Overview: Siemens Substation Automation System Part 2 of 3 (DIGSI software)
Content: IEC 61850- Design a feeder, Configuration in DIGSI, Create an interlocking page, Goose Message-configuration in DIGSI, Import IEC61850 to PASFS
DIGSI 4.91 is Compatible with Windows 7, Windows 8, and Windows 10. Elec-Engg provides a comprehensive training course on DIGSI 4 and DIGSI 5.
DIGSI software Introduction, Part I
DIGSI Tutorial, Part II: Implementation of a simple function in a SIPROTEC relay with DIGSI
In a world where the number of people who need to learn about data communications and networking is exploding, Forouzan’s book is the answer. The book’s visual approach makes it easy for students to learn about and understand the concepts involved in this rapidly developing field.
TCP/IP Protocol Suite teaches students and professionals, with no prior knowledge of TCP/IP everything they need to know about the subject. This comprehensive book uses hundreds of figures to make technical concepts easy to grasp as well as many examples that help tie the material to the real world.
The fourth edition of TCP/IP Protocol Suite has been fully updated to include all of the recent technology changes in the field. Additionally, out-of-date material has been overhauled to reflect recent changes in technology.
SIEMENS Protection and Automation Manuals & Catalogs
IEC 61850-9-2 Process bus equipment
The AMU is a Merging Unit in a digital substation that can publish messages over the substation process bus in compliance with the IEC 61850-9-2LE or IEC61869-9 standard. Data is published in the form of sampled values (SV) that comply with the light edition (LE) of the IEC 61850-9-2. And it has high accuracy time synchronization via PPS or IRIG-B, NTP, PTP1588, local clock, or via its internal built-in GPS receiver. It Complies with: IEC 61850-9-2LE and IEC 61850 GOOSE messaging. Also complies with the new IEC 61869-9 standard.
IEC61850 Video Training Package
Part I, Introduction:
DIGSI Tutorial Part II: Implementation of a simple function in a Siprotec relay with DIGSI
We welcome your questions, enhancement requests, improvement suggestions, criticisms, and any comments.
This File contains DIGSI 4.82, the PC program for configuring, parameterizing, starting, and operating all digital SIPROTEC protection, combination, and bay devices, in its current version 4.82. With a PC or a notebook, you can parameterize the devices via the interfaces and export and visualize the fault data.
VAMP 57 Relays Schneider Make,
VAMP Relays 50 Series Schneider Electric,
VAMP Relays 200 series Schneider Electric,
VAMP Relays 300 Series Schneider Electric,
SEPAM Relays 40 Series Schneider Electric,
SEPAM Relays 60 Series Schneider Electric,
SEPAM Relays 80 Series Schneider Electric
VAMP 57 Relays Schneider Make
Vamp series are smart Feeders and Motor protection relays. The vamp is an expert in communication with fast experience in interfacing different system integrators SCADA, RTUs, PLCs, and gateways using large numbers of supported protocols. The VAMP 57 offers a complete set of measurement functions to replace the conventional metering functions of switchgear and control gear installations. The measurement functions cover phase, line, and residual current imbalance, system frequency, and harmonics from phase currents.
Conditional monitoring continuously monitors trip circuit breaker wear and current transformer.
VAMP Relays 50 Series Schneider Electric
VAMP 50 series offers a comprehensive selection of modular protection relays for overcurrent, earth fault, voltage, frequency, and line differential protection. Models available: VAMP50, VAMP52, VAMP55, VAMP59. Schneider Electrics VAMP 50 series product range is highly flexible and meets the protection and control needs of a number of power systems, from simple overcurrent to busbar voltage or line differential applications. Featuring native IEC 61850 and VAMPs unique arc flash protection, the VAMP 50 series is designed around proven technology concepts and developed in close cooperation with customers, making it both reliable and modern. VAMP 50 series also introduces a complete set of measurement functions including line and residual currents, current imbalance, system frequency, and harmonics, replacing conventional metering functions in switchgear and control gear installations. User-friendliness is a designed-in feature of VAMP products and the VAMP 50 series is no exception with a large LCD display, programmable
function keys, and easy-to-use VAMPSET software.
VAMP Relays 200 series Schneider Electric
VAMP 200 series offers a comprehensive family of protection and control devices with complex measurement functions for the management of feeders, motors, and capacitor banks. Models available: VAMP210, VAMP230, VAMP255, VAMP257, VAMP259, VAMP265, VAMP265M
VAMP Relays 300 Series Schneider Electric
VAMP 300 series offers a comprehensive family of protection and control devices with complex measurement functions for the management of feeders and motors. Models available: VAMP300F, VAMP300M, VAMP300G, VAMP300T
SEPAM Relays 40 Series Schneider Electric
Sepam series 40 offers 13 types of digital current or voltage protection for demanding distribution systems, each one dedicated to a single application. Models available: Sepam S40, S41, S42, S50, S51, S52, S53, S54, T40, T42, T50, T52, M41, G40 Sepam series 40 includes 13 types of Sepam. One type of Sepam is dedicated to one application. Characteristics: 3 types of User-Machine Interface 4 current inputs 3 voltage inputs 10 logic inputs 8 8 relay outputs logic equation editor 1 Modbus communication port 16 temperature sensor inputs
SEPAM Relays 80 Series Schneider Electric
Sepam series 80 offers 16 types of digital current or voltage protection for any distribution system, each one dedicated to a single application. Models available: Sepam S80, S81, S82, S84, T81, T82, T87, M81, M87, M88, G82, G87, G88, B80, B83, C86 Sepam series 80 includes 16 types of Sepam. One type of Sepam is dedicated to one application. Characteristics: 3 types of UMI 12 analog input: – 8 current inputs and 4 voltage inputs – 4 current inputs and 8 voltage inputs 42 logic inputs 23 relay outputs 2 Modbus communication ports 16 temperature sensor inputs removable memory cartridge with parameters and settings for quick commissioning after replacement Logipam programming software (optional), to program-specific functions.
SEPAM Relays 10 Series Schneider Electric
Overcurrent and earth fault relay for basic protection of feeders and distribution transformers The Sepam series 10 range includes 3 models: series 10 N provides protection against earth fault. series 10 B provides protection against overloads, phase-to-phase faults, and earth faults. series 10 A performs the same functions as the Sepam series 10 B, with digital inputs and additional relay outputs, one communication port, and additional protection and monitoring functions Sepam series 10 replaces RH110, VIP 50, and Sepam 100RT due to the end of commercialization (November 2009 ) Applications Protection of secondary power distribution networks (MV/MV, MV/LV substations) Protection of buildings with MV power supply (office buildings, shopping centers, industry, warehouses)
SEPAM Relays 60 Series Schneider electric
Digital Protection Relays for Distribution Systems The Sepam series 60 includes 8 types of Sepam. One type of Sepam is dedicated to one application. Characteristics: 3 types of User-Machine Interface 4 current inputs 3 voltage inputs 28 binary inputs 16 binary outputs logic equation editor IEC 61850 w/ GOOSE 1 Modbus communication port 16 RTD inputs removable memory cartridge with parameters and settings for quick commissioning Applications S60, S62: substation incomers and feeders protection M61: motor protection T60, T62: transformer protection G60, G62: generator protection C60: capacitor protection
SEPAM 80 catalog
AQ-S255 BAY CONTROL IED
AQ-S255 bay control IED may be applied for demanding control applications. The AQ-S255 comes with full current, voltage, power, and energy measurement capability and may be equipped with additional I/O depending on application needs. Easy to use and powerful logic programming expands further the application range to more demanding control needs. Up to 11 optional I/O or communication cards can be inserted depending on application requirements. A large freely programmable HMI display provides a quick visualization of the object, alarm, and event status. The AQ-S255 communicates using various protocols including IEC 61850 substation communication standard.
Highlights
- Bay control unit with extensive IO
- Synchrocheck for up to three circuit breakers
- Up to class 0.2S power and energy measurement accuracy
The 7SR18 is a numeric three-phase differential protection used to detect in-zone phase and earth faults. The relay is applied to the overhead line and underground cable circuits as well as shorter circuits such as interconnections.
The relays have integral backup overcurrent/earth fault protection and inter-tripping channels.
Relays (and associated CTs) are installed at each end of the protected circuit. The relays are connected together with a fully supervised fiber optic protection communications link.
Relays have four current inputs and are housed in E6 cases.
Integrated logic is provided to allow the optimal configuration of relay functionality with the relays analog inputs and binary input/output circuits.
Protection and instrumentation functionality is accessible via the data comms channel – a front USB, RS485, and IEC 61850 (optional) rear ports.
The GRD200 multi-function protection IED is designed to provide comprehensive protection and control applications for transmission lines and distribution feeders in all types of networks. Typical feeder protection such as multiple, high accuracy overcurrent protection elements with inverse time and definite time delay functions which can be independently subject to directional control, thermal overload, under/overvoltage, under/over frequency, circuit breaker failure, and voltage-controlled overcurrent protection can be provided. Among the model lineup, current-base, voltage-based or current, and voltage-base configurations can be selected.
Protection functions
- Low impedance differential protection for up to 8 discriminating zones and check zone
- Percentage restrained characteristic ensuring stability against external faults
- Countermeasure for CT saturation
- Mixed different CT ratios and 1/5A ratings
- Operation with out-of-service bay units
- Circuit breaker failure
- End zone protection and blind zone protection
- Backup overcurrent and earth fault protection
- Independent voltage check element (option)
Metering and recording functions
- Metering
- Power system currents, voltages (option), and frequency (option)
- Recording
- Event record
- Fault record
- Disturbance record
Human interfaces
Selection of HMI: Standard LCD, large LCD, or separate large LCD
24 configurable tri-state LEDs selectable red/ green/ yellow
7 programmable function keys for user demand operation
Personal computer interface (USB and Ethernet ports)
Monitoring jacks for internal circuit tests
Built for speed, security, and simplicity.
- 1 ms traveling wave elements: TW87 and TW32.
- 4 ms time-domain elements: TD21 and TD32.
- Easy to set and less dependent on short-circuit studies.
- Nearest-tower fault location, with and without communications.
- time-synchronized, high-resolution data recorder with 1 MHz
- 18-bit sampling rate captures transient events.
- Complements your traditional protection and gives you speed.
Key Features
Ultra-High-Speed Fault-Clearing Times With Security Protect critical lines using the SEL-T400L with time-domain principles. The relay operates at ultra-high speeds without compromising security. The incremental quantity-based TD21 distance element can be set as far as 80 percent of the line length and operates in the order of 4 ms without communications. The POTT scheme with an incremental quantity-based TD32 directional element operates as fast as 2 ms, and the TW32 directional element operates as fast as 1 ms. The TW87 traveling-wave differential element operates in 1 to 4 ms, depending on the line length and fault location. The relay includes solid-state, trip-rated outputs. When used with a low-latency communications channel, the SEL-T400L trips breakers in the order of 4 to 6 ms for the vast majority of line faults.
Easy Settings and Deployment Use the SEL-T400L with existing control cables and wiring to connect to conventional current and voltage transformers, including CCVTs. The traveling wave differential (TW87) element uses current inputs for differential protection. The traveling wave directional (TW32) element can be used with CCVTs because it relies on stray capacitances for measuring the polarity of the first voltage wave. The incremental quantity elements (TD21 and TD32) use a lower-frequency spectrum and work well with any voltage or current transformer.
fast Mirrored Bits communications over direct fiber or a multiplexer for communications-assisted schemes. The TW87 differential element uses a dedicated 1 Gbps direct fiber channel for both communications and data alignment. None of the SEL-T400L protection elements require absolute time input, such as IRIG-B. Setting the SEL-T400L is simple and does not require complex short-circuit studies. It uses nameplate data that do not need to be reevaluated as the system evolves.
Time-domain line protection, SEL-T4287, T400l SEL, SELtraveling wave, SEL-T400l.
These include current and voltage transformer ratios, line impedances and length, TD21 reach, and port configuration settings.
This Relay coordination study and setting calculation, Which applies the selective system to clear only faulted feeder, is used to temporarily energize substation 133kV Switchgear and related incomings, bustie 33/6.3kV transformer feeders.
Format: PDF
Page: 370
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About:
This course is a combination of lectures, software packages, tutorial videos of the experiences in the lab. Become familiar with the DIGSI 4 software for configuring and setting SIPROTEC 4 relays with Windows-based MATRIX-driven software.
Learn also how to analyze grid fault events based on the data stored in the relay.
The training is intended for protective relay engineers, designers, and technicians from electric utilities and the industrial section interested in the programming, commissioning, maintenance, and operating of SIPROTEC4 protection devices.
DIGSI 4 and DIGSI 5 Online Training
DIGSI 4 Online Training Course
DIGSI 5 Online Training Course
Place of training:
This course will be held in your place.
Instructors:
- Dr. Saeed Roostaee
More information Please Contact Us
Related product:
DIGSI 4 Training Pack
Click here to Download IEC 61850 Video training course (4 hours)
This course provides comprehensive coverage of IEC 61850 and will provide you with the tools and knowledge to tackle your next digital substation project with confidence.
Topics:
INTRODUCTION
- 7-layer communication model
- Network topologies
- Client/server concept
- Publish/subscribe concept
- Key features of IEC 61850
- General functional requirements (Parts 3, 4, and 5)
- Mapping of abstract data objects and services onto the Manufacturing Messaging Specification (MMS) (Part 8.1)
- Mapping of Sample Measured Values onto ISO/IEC 8802-3 (IEEE 802.3/Ethernet)
IEC 61850 SUBSTATION ARCHITECTURE
- Merging Units (MUs)
- Station Bus
- Process Bus
ETHERNET COMMUNICATION WITHIN SUBSTATIONS
- Physical Interfaces (10/ 100/ 1000 Mbps)
- Media (copper, multi-mode fiber, single-mode fiber)
- Media access (full-duplex vs. CSMA/CD)
- MAC (L2) addressing: broadcasting, multicasting, unicasting
- Frame (packet) structure
- Bridges/switches
- VLANs
- Port-based vs. tagged VLANs
- IEEE802.1p port prioritisation
- IEEE802.1Q VLAN
- Time synchronization
- Network redundancy
- Parallel Redundancy Protocol (IEC 62439-3)
- Basic routing concepts
COMMUNICATION PROFILES
- Sampled Values (SV) multicast
- Generic Object Oriented Substation Event (GOOSE)
- GOOSE messages over L2
- GOOSE messages over L3 (IEC 61850-90-5)
- Generic Substation Status Event (GSSE)
- Time Sync (SNTP/GPS/IRIG-B)
- Application of and comparison between profiles
MAPPING OF IEC 61850 TO COMMUNICATION PROFILES
- Abstract Communication Service Interface (ACSI)
- Mapping of IEC61850 to MMS
- Object mapping
- Service mapping
CONFIGURATION
- Configuration of Sample Values
- Configuration of GOOSE
- Software tools
CONFORMANCE AND TESTING
- Documentation and process
- Assessment process
- Tools
- Testing methods
- Interpretation of Compliance Certificates
PRACTICAL SESSIONS
Practical exercises will include the following:
- Set up and configure Ethernet infrastructure
- Send and receive Sample Values
- Send and receive GOOSE messages
- Play and explanation of the recorded videos which is related to our lab experiment
Place of training:
This course will be held in your place.
Instructors: Dr. Saeed Roostaee
- Contact at ” info@Elec-Engg.com”
- Whatsapp: +989129613659
Click here to Download IEC 61850 Video training course (4 hours)
| [1] | 00-SEPAM Protection Principles. | |
| [2] | 01-Plan_Network structures. | |
| [3] | 02-Plan_Network and machine faults. | |
| [4] | 2V73 Setting Guide High Impedance Differential Relay. | |
| [5] | 03-Plan_Source of Isc. | |
| [6] | 04-Plan_Symmetrical components. | |
| [7] | 05-Plan_Calculation of Isc. | |
| [8] | 06-Plan_Calculation of Isc_exercises. | |
| [9] | 7PG17 – XR Intertripping, Interposing, Supervision, and Special Purpose Relays. | |
| [10] | 7PG21 – Solkor R/Rf Pilot Wire Current Differential Protection. | |
| [11] | 7PJ15 – Trip Relay High-Speed Tripping. | |
| [12] | 07-Plan_Earthing systems. | |
| [13] | 7SA. | |
| [14] | 7SG18 Solkor N Current Differential Protection. | |
| [15] | 7SG23 – MSCDN Capacitor Bank Protection. | |
| [16] | 7SG26 – Tau Autoreclose and synchronization. | |
| [17] | 7SG26 Auto re-close. | |
| [18] | 7SG117 Argus 7 Synchronising Relay. | |
| [19] | 7SR10 Argus Overcurrent and Earth Fault Relay. | |
| [20] | 7SR11 and 7SR12 Argus Overcurrent Relays. | |
| [21] | 7SR11 and 7SR12 Argus Overcurrent Relays. | |
| [22] | 7SR17 Rho Motor Protection Relay. | |
| [23] | 7SR23 DAD High Impedance Protection Relay. | |
| [24] | 7SR45 Argus Self-Powered Overcurrent and Earth Fault Relay. | |
| [25] | 7SR157 Argus Check and System Synchronising Relays. | |
| [26] | 7SR158 Argus Voltage and Frequency Relays. | |
| [27] | 7SR191 Capa Capacitor Bank Protection Relay. | |
| [28] | 7SR210 & 7SR220 Argus Overcurrent Protection Relay. | |
| [29] | 7SR224 Argus Recloser Controller. | |
| [30] | 7SR224 Argus Recloser Controller. | |
| [31] | 7SR242 Duobias Transformer Protection Relay. | |
| [32] | 08-Plan_Earthing systems_exercises. | |
| [33] | 09-Plan_CTs. | |
| [34] | 10-Plan_CTs_exercises. | |
| [35] | 11-Plan_Irsd measurement. | |
| [36] | 12-Plan_LPCT. | |
| [37] | 13-Plan_VTs. | |
| [38] | 14-Plan_Vrsd measurement. | |
| [39] | 15-Plan_Prot funct general charact. | |
| [40] | 16-Plan_IDMT curves_exercises. | |
| [41] | 17-Plan_Discrimination. | |
| [42] | 18-Plan_ANSI 67. | |
| [43] | 19-Plan_ANSI 67N. | |
| [44] | 20-Plan_Differential_87. | |
| [45] | 21-Plan_ANSI 87M. | |
| [46] | 22-Plan_ANSI 87T. | |
| [47] | 23-Plan_ANSI 64REF. | |
| [48] | 24-Plan_ANSI 49RMS. | |
| [49] | 25-Plan_Network protection. | |
| [50] | 26-Plan_Busbar protection. | |
| [51] | 27-Plan_Transformer protection. | |
| [52] | 28-Plan_ANSI 24_transformer. | |
| [53] | 29-Plan_ANSI 26-63. | |
| [54] | 30-Plan_Motor protection. | |
| [55] | 31-Plan_ANSI 40_motor. | |
| [56] | 32-Plan_ANSI 78PS_motor. | |
| [57] | 33-Plan_Synchronous generator protection. | |
| [58] | 34-Plan_ANSI 21B. | |
| [59] | 35-Plan_ANSI 24_generator. | |
| [60] | 36-Plan_ANSI 40_generator. | |
| [61] | 37-Plan_ANSI 50-27. | |
| [62] | 38-Plan_ANSI 64G. | |
| [63] | 39-Plan_ANSI 78PS_generator. | |
| [64] | 40-Plan_Capacitor protection. | |
| [65] | 100% stator earth fault protection: ANSI 64G. | |
| [66] | 100% stator ground fault protection – a comparison of two protection methods. | |
| [67] | 269 Motor Management Relay Instruction Manual. | |
| [68] | 369 Motor Management Relay Instruction Manual. | |
| [69] | 369 Motor Management Relay QuickStart Guide. | |
| [70] | 469 Motor Management Relay Instruction Manual. | |
| [71] | 469 Motor Management Relay INSTRUCTION MANUAL. | |
| [72] | 469 MOTOR MANAGEMENT RELAY® Instruction Manual. | |
| [73] | 489 GENERATOR MANAGEMENT RELAY® Instruction Manual. | |
| [74] | 615 series ANSI IEC 61850 Engineering Guide. | |
| [75] | 615 series ANSI Technical Manual. | |
| [76] | 650 series IEC 61850 Communication Protocol Manual. | |
| [77] | 670 series 2.0 ANSI DNP3 Communication Protocol Manual. | |
| [78] | 670 series 2.0 IEC Engineering Manual. | |
| [79] | 670 series 2.0 IEC IEC 60870-5-103 Communication Protocol Manual. | |
| [80] | 670 series 2.0 IEC IEC 61850 Edition 1 Communication Protocol Manual. | |
| [81] | 670 series 2.0 IEC IEC 61850 Edition 2 Communication Protocol Manual. | |
| [82] | 670 series 2.0 IEC LON Communication Protocol Manual. | |
| [83] | 670 series 2.0 IEC Operation Manual. | |
| [84] | 670 series 2.0 IEC SPA Communication Protocol Manual. | |
| [85] | 670 series Engineering Manual. | |
| [86] | 670 series IEC 2.0 Cyber Security Deployment Guideline. | |
| [87] | 745 TRANSFORMER MANAGEMENT RELAY INSTRUCTION MANUAL. | |
| [88] | 750/760 Feeder Management Relay® Instruction Manual. | |
| [89] | 800 question. | |
| [90] | 2013 IEC 61850 INTEROPERABILITY TEST Munich, Germany. | |
| [91] | 2015Protection, monitoring, and control solutions using Wide Area Monitoring Systems. | |
| [92] | 61400-25-2 Wind turbines – Part 25-2: Communications for monitoring and control of wind power plants – Information models. | |
| [93] | 61850-1. | |
| [94] | 61850-2. | |
| [95] | 61850-3. | |
| [96] | 61850-4. | |
| [97] | 61850-7-1{ed1.0}. | |
| [98] | 61850-9-1{ed1.0}en. | |
| [99] | 61850-9-2{ed1.0}en. | |
| [100] | 61850-90-1. | |
| [101] | 61850-90-5. | |
| [102] | 61850-90-7. | |
| [103] | 61850-90-7. | |
| [104] | 61850 easy. | |
| [105] | ABB AFS660 Switch High-availability Ethernet device based on new IEC-standard redundancy protocols PRP/HSR. | |
| [106] | ABB is implementing the first commercial installation of IEC 61850-9-2 LE process-bus technology. | |
| [107] | ABB Power and Automation: Solid Foundations for Smart Cities. | |
| [108] | ABB PROTECTION APPLICATION HANDBOOK. | |
| [109] | ABB review Special Report IEC 61850. | |
| [110] | ABB S.p.A. PPD U.O. Adda – HV PASS Family & new products. | |
| [111] | ABB technologies that changed the world. | |
| [112] | ABB wind power solutions Total solutions for wind power plants. | |
| [113] | AC_A_en_670_series_Ver.1.2__IEC_symbols. | |
| [114] | Acceptance, Commissioning, and Field Testing for Protection and Automation Systems. | |
| [115] | ACSELERATOR Diagram Builder User’s Guide. | |
| [116] | ACSELERATOR QuickSet SEL-5030 Software Instruction Manual. | |
| [117] | ACSELERATOR RTAC® SEL-5033 Software Instruction Manual. | |
| [118] | Active Management of Distributed Energy Resources Using Standardized Communications and Modern Information Technologies. | |
| [119] | Adapting Electricity Networks to a Sustainable Energy System – Smart metering and smart grids. | |
| [120] | ADAPTIVE DISTANCE RELAY SETTING FOR TRANSMISSION LINES IN THE PRESENCE OF UPFC AND WIND FARMS. | |
| [121] | Adaptive Protection and Microgrid Control Design for Hailuoto Island. | |
| [122] | Advanced protection and control IEDs from ABB. | |
| [123] | ADVANCED TAP-CHANGER CONTROL TO COUNTERACT POWER SYSTEM VOLTAGE INSTABILITY. | |
| [124] | AE_en_670_series_ver._2.0__IEC_symbols. | |
| [125] | AGILE DIGITAL SUBSTATIONS 2.0. | |
| [126] | AGILE DIGITAL SUBSTATIONS The complete guide. | |
| [127] | Air-Insulated Medium-Voltage Switchgear NXAIR, up to 24 kV. | |
| [128] | Alborz Distribution Network Planning Long-term planning. | |
| [129] | Alpha – Electromechanical Relays. | |
| [130] | Alpha – Electromechanical Relays. | |
| [131] | ALPS Advanced Line Protection System Instruction Manual. | |
| [132] | ALSTOM RELAY PRODUCT RANGE. | |
| [133] | American National Standard Dictionary of Electromagnetic Compatibility (EMC) including Electromagnetic Environmental Effects (E3). | |
| [134] | Analysis and implementation of the IEC 61850 standard. | |
| [135] | Analysis and Simulation of Electrical and Computer Systems. | |
| [136] | Anomaly Checks for Relay Settings. | |
| [137] | ANSI code protection. | |
| [138] | Application Considerations of IEC 61850/UCA 2 for Substation Ethernet Local Area Network Communication for Protection and Control. | |
| [139] | Application Examples Communication set-up for RED 670 Differential protection and 670 series binary transfer in telecommunication networks. | |
| [140] | Application guide for calculation of short-circuit currents in low-voltage radial systems. | |
| [141] | Application Guide for the choice of protective relays. | |
| [142] | Application Manual Connecting the worlds of building construction and power distribution. | |
| [143] | Application Models for Power Distribution Data Centres. | |
| [144] | APPLICATION NOTE AQ 2xx Relay Output Guideline. | |
| [145] | Application Note Extending existing PTL items for distance protection with power swing blocking and tripping tests. | |
| [146] | Application Note High current relay testing. | |
| [147] | Application Note Power Transformer Vector Group and Turns Ratio Testing with CMC 256plus/356. | |
| [148] | Application Note Rogowski current sensor simulation with a CMC Test Set. | |
| [149] | Application Note Testing 6-phase Synchronizers with two CMC Test Sets. | |
| [150] | Application Note Testing a relay’s power swing impedance characteristic with Advance Distance Module. | |
| [151] | Application Note Testing transducers with multiple outputs. | |
| [152] | Application Note Using a Single CMC Test Set for Testing Six-Phase Synchronizing Relays. | |
| [153] | Application Note Using the Relay Setting Import Filter for SEL Relays. | |
| [154] | Application of an IEC 61850 and Synchrophasor Solution for Electricity of Vietnam. | |
| [155] | Application of Overreaching Distance Relays. | |
| [156] | Application of Overreaching Distance Relays. | |
| [157] | Application of Unit Protection Schemes for AutoTransformers. | |
| [158] | APPLICATIONS OF A REAL-TIME DIGITAL SIMULATOR IN POWER-SYSTEM EDUCATION AND RESEARCH. | |
| [159] | Applications of IEC 61850 Standard to Protection Schemes. | |
| [160] | Applications of Phasor Measurement Units. | |
| [161] | Applications of PMU measurements in the Belgian electrical grid. | |
| [162] | The Application-View Model of the International Standard IEC 61850. | |
| [163] | Applying IEC 61850 to Real Life: Modernization Project for 30 Electrical Substations. | |
| [164] | Applying Radio Communication in Distribution Generation Teleprotection Schemes. | |
| [165] | AQ-200 series protection, control, measurement, and monitoring IEDs. | |
| [166] | Arc Fault Monitoring System. | |
| [167] | Arc Protection Relay REA 101. | |
| [168] | The art and science of protective relaying. | |
| [169] | AS-Interface. | |
| [170] | Asynchronous motor protection. | |
| [171] | Auto Re-close and Sync Check. | |
| [172] | Automated Analysis of power system events. | |
| [173] | Automated Test Solutions for Agile Protection Relays. | |
| [174] | Automatic Testing of Relays in R&D at ABB Sweden. | |
| [175] | Auxiliary Relay (7PJ111, 7PJ112, 7PJ113) and Trip Relay (7PJ121) Better protection and more efficiency for your power system. | |
| [176] | Basic Application and Simulation Testing of a High-Speed Motor Bus Transfer System. | |
| [177] | BASIC PRINCIPLES OF DISTANCE PROTECTION DEVICES1. | |
| [178] | Basics of Current and Voltage Transformers. | |
| [179] | Battery fundamental. | |
| [180] | Bay control REC670 Pre-configured Product Guide. | |
| [181] | Bay control REC670 Relion® 670 series Ver. 1.2. | |
| [182] | The Building Blocks of a Data-Aware Transport Network: Deploying Viable Ethernet and Virtual Wire Services via Multiservice ADMs. | |
| [183] | bus bar protection 1. | |
| [184] | Busbar Differential Protection / 7SS52 SIPROTEC 4 7SS52 distributed numerical busbar and breaker failure protection. | |
| [185] | Busbar Differential Protection / 7SS60 SIPROTEC 7SS60 centralized numerical busbar protection. | |
| [186] | CABLE LIST. | |
| [187] | CABLE TRAY LADDER LAYOUT WITH INSTRUMENT LOCATION IF ANY. | |
| [188] | Cahier technique no. 192 Protection of MV/LV substation transformers. | |
| [189] | Cahier technique no. 211 The protection of LV motors. | |
| [190] | CALCULATING LOADABILITY LIMITS OF DISTANCE RELAYS. | |
| [191] | Calculation of Relay Setting of P543 for Majalgon S.S.K. | |
| [192] | Calculations for LV and HV networks. | |
| [193] | Calibration System for Electronic Instrument Transformers With Digital Output. | |
| [194] | A Calibration System for Instrument Transformers with Digital Output. | |
| [195] | Capacitor Protection Relay SPAJ 160 C Product Guide | |
| [196] | CASE STUDIES RELATED TO OVERHEAD TRANSMISSION-LINE SYSTEM DISTURBANCES. | |
| [197] | Case Study: Design and Implementation of IEC 61850 From Multiple Vendors at CFE La Venta II. | |
| [198] | Case Study: Introduction of New Technologies in Unattended Substations in Panama. | |
| [199] | Case Study: Using IEC 61850 Methods for RTU Replacement and Distributed Automation. | |
| [200] | CB Simulation Application Note. | |
| [201] | CENTRALISED BUSBAR PROTECTION FOR SMARTER GRIDS. | |
| [202] | Centralized and Distributed Active and Reactive Power Control of a Utility Connected Microgrid Using IEC61850. | |
| [203] | Challenges and Integration of PV and Wind Energy Facilities from a Smart Grid Point of View. | |
| [204] | Challenges and Lessons Learned from Commissioning an IEC 61850-90-5 Based Synchrophasor System. | |
| [205] | Challenges in Protection of a Series-Compensated 400 kV Double Line. | |
| [206] | chapter AC motors starting and protection systems. | |
| [207] | Characteristics of Elements. | |
| [208] | Circuit Breaker Monitoring Using the SEL-421 Relay. | |
| [209] | Circuit-Breaker Switchgear Type 8BT2 up to 36 kV, 31.5 kA, Air-Insulated. | |
| [210] | Circuit-Breaker Switchgear Type SIMOPRIME, up to 17.5 kV, Air-Insulated. | |
| [211] | A closer look at accuracy Reliable harmonic assessment by measuring voltage transformer accuracy. | |
| [212] | CMC 256. | |
| [213] | CMC 256plus Reference Manual. | |
| [214] | CMC 353 Reference Manual. | |
| [215] | CMEngine. | |
| [216] | CMGPS. | |
| [217] | Commissioning Instructions For use with Substation and Telecontrol Batteries BA300 Battery Alarm. | |
| [218] | Commissioning of a Distributed Busbar Protection Using a System-Oriented Test in the Field. | |
| [219] | COMMON REQUIREMENTS FOR ELECTRIC POWER EQUIPMENT. | |
| [220] | Communication in Power application. | |
| [221] | Communication Networks Communication solutions for mission-critical applications. | |
| [222] | Communication set-up for Relion 670-series 2.0 using PCM600 2.6 or later Setting and application guide. | |
| [223] | Communications network solutions for smart grids. | |
| [224] | Communications-Assisted Schemes for Distributed Generation Protection. | |
| [225] | Comparison of the operational speed of hard-wired and IEC 61850 standard-based implementations of a reverse blocking protection scheme. | |
| [226] | Comparisons process-to-bay level peer-to-peer network delay in IEC61850 substation communication systems. | |
| [227] | Complete Sepam Presentation_EN_2009. | |
| [228] | A Comprehensive Investigation of Wireless LAN for IEC 61850–Based Smart Distribution Substation Applications. | |
| [229] | Comprehensive testing of motor protection systems and Testing practice in the petrochemical industry. | |
| [230] | Comprehensive Testing of Synchronous Generator Protection Systems and AVR Reaction. | |
| [231] | Comprehensive Testing of Synchronous Generator Protection Systems and AVR Reaction. | |
| [232] | COMPUTER RELAYING FOR POWER SYSTEMS. | |
| [233] | Concept. | |
| [234] | The concept of IEC 61850. | |
| [235] | Configuration and Performance of IEC 61850 for First-Time Users – UNC Charlotte Senior Design Project. | |
| [236] | Connecting the SEL-849 Motor Management Relay to EtherNet/IP™ Networks. | |
| [237] | Connection of AC500 to an IEC60870-5-101 (Serial) Master via ProCon164. | |
| [238] | CONSTRUCTION OF 220 KV GAS-INSULATED SUBSTATIONS (GIS) SECTOR-20 GURGAON ON TURNKEY BASIS AGAINST TENDER ENQUIRY NO. JICA-011. | |
| [239] | CONTROL BOARD SPECIFICATION & DETAILS. | |
| [240] | Control of district heat substations Reliable and energy-efficient. | |
| [241] | CONTROL SYSTEM. | |
| [242] | Control your CMC test set with your tablet PC and the new CMControl P App. | |
| [243] | Coordination Analysis and Relay Setting Tool. | |
| [244] | Coordination Analysis and Relay Setting Tool. | |
| [245] | Coordination of Overcurrent Relays for Industrial Radial System. | |
| [246] | COSI-NXCT F3 Flexible Optical Current Transformer. | |
| [247] | Cost-Efficient Solution for Power Distribution. | |
| [248] | CPOL Polarity Checher. | |
| [249] | Creating Nonvolatile Counters in SELOGIC® Control Equations. | |
| [250] | CT Saturation in Industrial Applications – Analysis and Application Guidelines. | |
| [251] | Current and Energy Measurement Technology. | |
| [252] | CURRENT TRANSFORMER PERFORMANCE ANALYSIS. | |
| [253] | CURRENT TRANSFORMERS. | |
| [254] | Current Transformers Ratio / Polarity / Types. | |
| [255] | Current-Sense Transformer Application Design Guidelines. | |
| [256] | Current-Transformer Phase-Shift Compensation and Calibration. | |
| [257] | D30 Line Distance Relay Instruction Manual D30 revision: 5.2x. | |
| [258] | D60 Line Distance relay Setting Example. | |
| [259] | Data transport network. | |
| [260] | DBF Digital Breaker Failure Protection Instruction Manual GEK-106168F | |
| [261] | DCCB AND DELTA I RELAY SETTING CALCULATION METHOD. | |
| [262] | DCS in Substation | |
| [263] | Dealing with Packet Delay Variation in IEEE 1588 Synchronization Using a Sample-Mode Filter. | |
| [264] | Defining and Designing Communications Determinism for Substation Applications. | |
| [265] | Design & Commissioning of a Distributed IEC 61850 Communication Based Protection Scheme for a Railway Electrification Project. | |
| [266] | Design and Implementation of Packet Analyzer for IEC 61850 Communication Networks in Smart Grid. | |
| [267] | Design and Performance Testing of a Multivendor IEC61850–9-2 Process Bus Based Protection Scheme. | |
| [268] | Design of 132/33KV Substation. | |
| [269] | The design of a modern protection system for a Static Var Compensator. | |
| [270] | Design of a Priority-Based Load Shed Scheme and Operation Tests. | |
| [271] | Design, Development, and Commissioning of a Substation Automation Laboratory to Enhance Learning. | |
| [272] | Design, Development, and Commissioning of a Substation Automation Laboratory to Enhance Learning. | |
| [273] | Design, Development, and Commissioning of a Supervisory Control and Data Acquisition (SCADA) Laboratory for Research and Training. | |
| [274] | Design, Modeling, and Evaluation of Protective Relays for Power Systems. | |
| [275] | Designing next generation’s protection systems. | |
| [276] | DETAILED CONNECTION (WIRING) DIAGRAM AND PART LIST OF COMMON PANEL. | |
| [277] | Detecting Power System Islanding With Time Error Measurement. | |
| [278] | Determining the Faulted Phase. | |
| [279] | DEVELOPING PROTECTIVE RELAY FACEPLATES. | |
| [280] | Development of IEC61850 Based Substation Engineering Tools with IEC61850 Schema Library. | |
| [281] | Development of laboratory exercises based on OPNET Modeler. | |
| [282] | DGP Digital Generator Protection Relay™ Instruction Manual. | |
| [283] | Differential (87) Element Settings. | |
| [284] | Differential Protection. | |
| [285] | Differential Protection 7UT6x | |
| [286] | Differential protection for shunt reactors and power transformers – similarities and differences. | |
| [287] | Differential Protection RET 54_/Diff6T function Application and Setting Guide. | |
| [288] | Digital Protection for Power Systems. | |
| [289] | Digital Substation Solutions. | |
| [290] | Digital umspannwerk. | |
| [291] | Digitalization in Transmission and Distribution. | |
| [292] | DIGSI 4 Start-Up Manual. | |
| [293] | DIGSI 5 Software Description V07.00 Help. | |
| [294] | Direct Evaluation of IEC 61850-9-2 Process Bus Network Performance. | |
| [295] | Directional Earth Fault Relay Operation in Mutually Coupled Multiple Circuit Distribution Lines. | |
| [296] | Directional Overcurrent Relaying (67) Concepts. | |
| [297] | Distance. | |
| [298] | Distance Protection 7SA6. | |
| [299] | Distance Protection 7SA6 SIPROTEC 4 7SA6 distance protection relay for all voltage levels. | |
| [300] | Distance Protection 7SA522 SIPROTEC 4 7SA522 distance protection relay for transmission lines. | |
| [301] | Distance Protection for transmission lines: part 1. | |
| [302] | Distance Protection for transmission lines: part 2. | |
| [303] | Distance Protection in Distribution Systems: How It Assists With Integrating Distributed Resources. | |
| [304] | Distance Protection OHL Setting Example. | |
| [305] | Distance Protection Power Swing. | |
| [306] | Distance Protection: Earth-Faults and Fault Resistance. | |
| [307] | Distance Protection: Earth-Faults in Isolated and Resonant grounded Systems. | |
| [308] | Distance Protection: Monitoring Functions. | |
| [309] | Distance Protection: Negative Sequence Direction Measurement. | |
| [310] | Distance Protection: Series Compensated Lines. | |
| [311] | Distance Protection: Tele-Protection and weak indeed. | |
| [312] | Distance Relay Element Design. | |
| [313] | Distance Relays. | |
| [314] | Distance Relays 101 30th Annual Hands-On Relay School March 2013. | |
| [315] | Distributed busbar protection REB500 including line and transformer protection Product Guide. | |
| [316] | Distributed energy resources present new challenges for protection systems and the way they are tested. | |
| [317] | Distributed Multifunction Fault Recorder. | |
| [318] | A Distributed PMU for Electrical Substations With Wireless Redundant Process Bus. Download: contact Us | |
| [319] | Distribution Automation Handbook Section 3 Elements of power distribution systems. | |
| [320] | Distribution Automation Handbook Section 8.1 Electrical Safety. | |
| [321] | Distribution Automation Handbook Section 8.2 Relay Coordination. | |
| [322] | Distribution Automation Handbook Section 8.2 Relay Coordination. | |
| [323] | Distribution Automation Handbook Section 8.5 MV Feeder Short-circuit Protection. | |
| [324] | Distribution Automation Handbook Section 8.6 MV Feeder Earth-fault Protection. | |
| [325] | Distribution Automation Handbook Section 8.7 Protection of HV Transformers. | |
| [326] | Distribution Automation Handbook Section 8.10 Protection of Capacitor Banks. | |
| [327] | Distribution Automation Handbook Section 8.11 Motor Protection. | |
| [328] | Distribution Automation Handbook Section 8.13 Backup Protection. | |
| [329] | Distribution Automation Handbook Section 8.14 Automatic Reclosing. | |
| [330] | Distribution Automation Handbook Section 8.15 Impedance-based Fault Location. | |
| [331] | Distribution Grid Automation Raising the bar in grid efficiency and reliability. | |
| [332] | Distribution Switchgear. | |
| [333] | Dr. Vladimir Gurevich. | |
| [334] | Draft Trial-Use Recommended Practice for Grounding of Direct Current Equipment Enclosures in Traction Power Distribution Facilities. | |
| [335] | DRAWING PACKAGE FOR 1CP001 PANEL. | |
| [336] | DRAWING PACKAGE FOR 2CP001. | |
| [337] | DRAWING PACKAGE FOR 2CP002. | |
| [338] | DRAWING PACKAGE FOR 2CP003. | |
| [339] | DRAWING PACKAGE FOR 3CP002. | |
| [340] | DRAWING PACKAGE FOR 3CP003. | |
| [341] | DRAWING PACKAGE FOR 4CP001. | |
| [342] | DRAWING PACKAGE FOR 4CP002. | |
| [343] | DRAWING PACKAGE FOR 4CP003. | |
| [344] | DRAWING PACKAGE FOR 5C. | |
| [345] | Duplicate and Circulating Frames Discard Methods for PRP and HSR (IEC62439-3). | |
| [346] | Dynamic Testing of an IEC 61850 Based 110 kV Smart Substation Solution. | |
| [347] | Early Detection of Power System Oscillations for Improved Stability Assessment. | |
| [348] | earth fault relay with recorder guide. | |
| [349] | Earth Fault protection. | |
| [350] | EARTHING CONNECTIONS POINTS DRAWING. | |
| [351] | Easy and Intuitive Method for Testing Transformer Differential Relays. | |
| [352] | ECT Evaluation by an Error Measurement System According to IEC 60044-8 and 61850-9-2. | |
| [353] | ECT Evaluation by an Error Measurement System According to IEC 60044-8 and 61850-9-2. | |
| [354] | Eduard Muljadi, https://www.nrel.gov/research/eduard-muljadi.html. | |
| [355] | The Effects of Waveform Distortion on Power Protection Relays. | |
| [356] | Efficient Energy Automation with the IEC 61850 Standard Application Examples Energy Automation. | |
| [357] | Efficient network integration of renewable energy resources on the distribution level. | |
| [358] | Electrical components for the railway industry. | |
| [359] | Electrical installation guide According to IEC International Standards. | |
| [360] | Electrical installation handbook Protection, control, and electrical devices. | |
| [361] | Electrical Integration with System 800xA. | |
| [362] | Electrical Machines Mathematical Fundamentals of Machine Topologies. | |
| [363] | ELECTRICAL POWER FACILITIES SYSTEM AND EQUIPMENT PROTECTIVE RELAYING. | |
| [364] | Electrical Power Systems by D. Das (2006). | |
| [365] | Electrical Protection. | |
| [366] | Electrical Transmission and Distribution Reference Boo. | |
| [367] | Electricity and Electronics Fundamentals, 2nd Ed. by Dale R. Patrick, Stephen W. Fardo (2008). | |
| [368] | Emerging Applications of Synchronous Ethernet in Telecommunication Networks. | |
| [369] | Enabling digital substations. | |
| [370] | Energy Management of Internet Data Centers in Smart Grid. | |
| [371] | EnerLyzer. | |
| [372] | ENGINE CONTROL SYSTEM DETAIL MANUAL. | |
| [373] | Engineering Perspective on IEC 61850. | |
| [374] | The Engineering Application of Jianfeng Smart Substation based on Integration of Power Secondary Systems. | |
| [375] | Enter the network of expertise. | |
| [376] | Ergon_appendix_f_proposed_substation_Design_A. | |
| [377] | ERL 61850 IED Configurator. | |
| [378] | ETAP_ComparisonResults. | |
| [379] | Ethernet & IEC 61850 Concepts, Implementation, Commissioning. | |
| [380] | Ethernet in SAS. | |
| [381] | Ethernet in Substation Automation Applications – Issues and Requirements. | |
| [382] | Ethernet Module EN100 for IEC 61850 with electrical/optical 100 MBit Interface Application Examples. | |
| [383] | Ethernet Networks Redundancy With Focus On IEC 61850 Applications. | |
| [384] | ETHERNET NETWORKS REDUNDANCY WITH FOCUS ON IEC 61850 APPLICATIONS. | |
| [385] | Ethernet-Based Public Communication Services: Challenge and Opportunity. | |
| [386] | ETM/V1/CT-R0-03-2017. | |
| [387] | Evaluation of IEC 61850-9-2 Samples Loss on Total Vector Error of an Estimated Phasor. | |
| [388] | Evaluation of Time Gateways for Synchronization of Substation Automation Systems. | |
| [389] | An Example Distance Protection Application with Complicating Factors. | |
| [390] | An Example Distance Protection Application with Complicating Factors. | |
| [391] | Executive Summary (Introduction to MMS. | |
| [392] | Experience with Multiterminal Line Differential Protection Installed on Series Compensated, 400 kV Line with FiveEnds. | |
| [393] | F650 Digital Bay Controller Instruction manual GEK-106310T. | |
| [394] | F650 Digital Bay Controller User manual GEK-113000T. | |
| [395] | Fast substation busbar protection with IEC 61850 and GOOSE. | |
| [396] | Fault Current Distribution Across Special Transformers. | |
| [397] | A Fault Location Technique for Two-Terminal Multisection Compound Transmission Lines Using Synchronized Phasor Measurements. | |
| [398] | Fault locator with 2 ended measurement. | |
| [399] | FAULTS AND PROTECTION OF ELECTRIC ENERGY SYSTEMS. | |
| [400] | Feeder Protection and Control REF615 Application Manual. | |
| [401] | Feeder Protection Relay REF610. | |
| [402] | Feeder Terminal REF 54_. | |
| [403] | Fiber OpticsCurrentSensor –Free Standing Enabling smart grids and digital substations. | |
| [404] | Fieldbus_Mahe. | |
| [405] | Focus on the application – IEC 61850 experience with the third-party system configuration tool. | |
| [406] | Frequency of Calibration of OMICRON CMC Test Equipment. | |
| [407] | Frequency Response Characteristic of MV Voltage Transformers and their Accurate Measurement up to 2.5/3 kHz. | |
| [408] | A Fresh Look at Limits to the Sensitivity of Line Protection. | |
| [409] | From IEC 61850-Compliant SEL Device CID File Configuration to Network Optimization: A Job Done® Example. | |
| [410] | Fundamentals and Improvements for Directional Relays. | |
| [411] | Fundamentals Of Differential Protection. | |
| [412] | Fundamentals of-Directional Overcurrent & Earth Fault Protection. | |
| [413] | G30 Generator Management Relay UR Series Instruction Manual. | |
| [414] | G60 Generator Management Relay UR Series Instruction Manual. | |
| [415] | Gas Insulated Switchgear Concept Design for Service Continuity in GIS. | |
| [416] | GE motor protection. | |
| [417] | General Guideline. | |
| [418] | GENERAL INDUSTRY SAFETY INSTRUCTIONS OF GEN-SET. | |
| [419] | General Training Electrical Protection. | |
| [420] | General Training Electrical Protection. | |
| [421] | Generator Black Start Validation Using Synchronized Phasor Measurement. | |
| [422] | GENERATOR PROTECTION. | |
| [423] | Generator Protection. | |
| [424] | Generator Protection / 7RW600 SIPROTEC 7RW600 numerical voltage, frequency and overexcitation protection relay. | |
| [425] | Generator Protection / 7UM61 SIPROTEC 4 7UM61 multifunction generator and motor protection relay. | |
| [426] | Generator Protection / 7UM62 SIPROTEC 4 7UM62 multifunction generator, motor and transformer protection relay. | |
| [427] | Generator Protection / 7VE6 SIPROTEC 7VE6 multifunction paralleling device 11/. | |
| [428] | Generator Protection Application Guide. | |
| [429] | Generator Protection Setting Criteria. | |
| [430] | Generator Protection, Relay Setting Calculations. | |
| [431] | GENERATOR TERMINAL BOX DRAWING. | |
| [432] | Generic IEC61850 IED Connectivity Package User‘s Guide. | |
| [433] | Get on the digital bus to SA. | |
| [434] | Getting Started IPC@CHIP Embedded Web Controller Family IEC 61850 Basics. | |
| [435] | Go Rugged. With Siemens!. | |
| [436] | GOOSE AIR. | |
| [437] | GOOSE-based Protection Scheme Implementation & Testing in Laboratory. | |
| [438] | GOOSE Configuration Example. | |
| [439] | GOOSE Configuration Example Testing an IEC 61850-Compliant Relay with a CMC Test Set, the GOOSE Configuration
Module and IEDScout 4.00. | |
| [440] | GOOSE Message-Based Multi Substation Overload Shedding (OLS) Scheme using Ethernet over Internet Protocol (EoIP) Tunnelling. | |
| [441] | Goose Messaging Determining its potential in a real case. | |
| [442] | GOOSE Timing Measurements in an IEC 61850 Substation – Using a Distributed Hybrid Signal Analyzer. | |
| [443] | GPS and IEEE 1588 synchronization for the measurement of synchrophasors in electric power systems. | |
| [444] | Green Electricity – 25 Green Technologies That Will Electrify Your Future by Kendall Haven (2011). | |
| [445] | Grid Automation REC615 and RER615 IEC 61850 Engineering Guide. | |
| [446] | Grid Connectivity Standards, Grid standards. | |
| [447] | Ground Fault Protection. | |
| [448] | GSSE Configuration Example. | |
| [449] | Guide to Power System Selective Coordination 600V and Below. | |
| [450] | HardFiber. | |
| [451] | High Reliability with ABB Disconnector. | |
| [452] | High-Speed Busbar Protection with GOOSE. | |
| [453] | High-voltage switchgear and control gear – Part 111: Automatic circuit reclosers and fault interrupters for alternating current systems up to 38 kV. | |
| [454] | History and Test Method of Protection Relay with Rogowski Coil Based Current Transformer. | |
| [455] | How network simulation improves protection testing and eases the application of end-to-end testing. | |
| [456] | How to enable SNTP on a CMC Test Set. | |
| [457] | How Would We Know?. | |
| [458] | HV Substation Design: Applications and Considerations. | |
| [459] | HV SUBSTATION PROJECT. | |
| [460] | iec61850-5{ed1.0}. | |
| [461] | iec61850-6{ed1.0}. | |
| [462] | iec61850-6{ed2.0}. | |
| [463] | IEC61850-7-2. | |
| [464] | iec61850-7-2{ed2.0}. | |
| [465] | IEC61850-7-3. | |
| [466] | iec61850-7-4{ed1.0}. | |
| [467] | iec61850-7-420{ed1.0}. | |
| [468] | iec61850-8-1{ed1.0}. | |
| [469] | iec61850-8-1{ed1.0}en-2004. | |
| [470] | iec61850-8-1{ed2.0}. | |
| [471] | iec61850-9-2{ed2.0}. | |
| [472] | iec61850-9-2{ed2.0}. | |
| [473] | IEC61850-9-2LE. | |
| [474] | iec61850-90-5{ed1.0}en. | |
| [475] | iec61850-90-7{ed1.0}. | |
| [476] | IEC61850 Based Process Bus Protection Solution for Remote Located Power Transformers. | |
| [477] | IEC61850 Modeling for Switch Management. | |
| [478] | IEC 60076-21 Power transformers – Part 21: Standard requirements, terminology, and test code for step-voltage regulators. | |
| [479] | IEC 60255-24 Measuring relays and protection equipment – Part 24: Common format for transient data exchange (COMTRADE) for power systems. | |
| [480] | IEC 60870-5-101/104 Slave Technical. | |
| [481] | IEC 60870-5-103 Communication Protocol Manual. | |
| [482] | IEC 60870-5-104. | |
| [483] | IEC 60909. | |
| [484] | IEC 61346-2 Industrial systems, installations and equipment, and industrial products – Structuring principles and reference designations – Part 2: Classification of objects and codes for classes. | |
| [485] | IEC 61400-12 Wind turbine generator systems – Part 12: Wind turbine power performance testing. | |
| [486] | IEC 61850-3 and IEEE 1588. | |
| [487] | IEC 61850-8-1-2004. | |
| [488] | IEC 61850-9-2 Based Process Bus. | |
| [489] | IEC 61850-9-2 Process Bus Communication Interface for Light Weight Merging Unit Testing Environment. | |
| [490] | IEC 61850-10. | |
| [491] | IEC 61850 – What It Can and Cannot Offer to Traditional Protection Schemes. | |
| [492] | IEC 61850: COMMUNICATION NETWORKS AND SYSTEMS IN SUBSTATIONS. | |
| [493] | IEC 61850 Based Breaker Failure Protection Scheme Design for TNB Double Busbar Substation. | |
| [494] | IEC 61850 -Communication Networks and Systems in Substations: An Overview of Computer Science. | |
| [495] | IEC 61850 driver FAQ. | |
| [496] | IEC 61850 Enabled Automatic Bus Transfer Scheme for Primary Distribution Substations. | |
| [497] | IEC 61850 General. | |
| [498] | IEC 61850 GOOSE and IEEE C37.118 Synchrophasors Used for Wide-Area Monitoring and Control, SPS, RAS, and Load and Generation Management. | |
| [499] | IEC 61850 Goose applications to distribution protection schemes. | |
| [500] | IEC 61850 in the oil and gas industries. | |
| [501] | IEC 61850 interoperability. | |
| [502] | IEC 61850 MMS Client Driver Help. | |
| [503] | IEC 61850 MMS SCADA Network Optimization for IEDs. | |
| [504] | IEC 61850 Model Expansion Toward Distributed Fault Localization, Isolation, and Supply Restoration. | |
| [505] | IEC 61850 Part 7-420 DER Logical Nodes Final Draft International Standard (FDIS). | |
| [506] | IEC 61850 Process Bus – It is Real!. | |
| [507] | IEC 61850 Protection Testing Versatile tools for working with IEC 61850 devices. | |
| [508] | IEC 61850 standard for SA. | |
| [509] | The IEC 61850 standard for SA. | |
| [510] | IEC 61850 Substation Configuration Language and Its Impact on the Engineering of Distribution Substation Systems. | |
| [511] | IEC 61850 System Configurator. | |
| [512] | IEC 61850 Technical Overview. | |
| [513] | IEC 61850 TRAINING PROGRAM. | |
| [514] | IEC 61850/61400 Model Designer. | |
| [515] | IEC 61850: Role of Conformance Testing in Successful Integration. | |
| [516] | IEC 61850: WHAT YOU NEED TO KNOW ABOUT FUNCTIONALITY AND PRACTICAL IMPLEMENTATION. | |
| [517] | IEC 61850-Based Feeder Terminal Unit Modeling and Mapping to IEC 60870-5-104. | |
| [518] | IEC 61850-Based Information Model and Configuration Description of Communication Network in Substation Automation. | |
| [519] | IEC 62357: TC57 Architecture Part 1: Reference Architecture for Power System Information Exchange. | |
| [520] | IEC 62439 PRP: Bumpless Recovery for Highly Available, Hard Real-Time Industrial Networks. | |
| [521] | IED Configuration Guidelines. | |
| [522] | IEDs interoperability, interchangeability, and logical nodes compatibility. | |
| [523] | IEEE-1588 Standard for a Precision Clock Synchronization Protocol for Networked Measurement and Control Systems. | |
| [524] | IEEE 802.1AS and IEEE 1588. | |
| [525] | IEEE 802.3ba 40 and100 Gigabit Ethernet Architecture. | |
| [526] | IEEE 1588. | |
| [527] | IEEE 1588 Precision Time Protocol Time Synchronization Performance. | |
| [528] | IEEE 1588 Precision Time Synchronization Solution for Electric Utilities. | |
| [529] | IEEE 1588 Version 2. | |
| [530] | IEEE Application Guide for IEEE Std 1547™, IEEE Standard for Interconnecting Distributed Resources with Electric Power
Systems. | |
| [531] | IEEE Guide for AC Motor Protection. | |
| [532] | IEEE Guide for AC Motor Protection. | |
| [533] | IEEE Guide for Application of Digital Line Current Differential Relays Using Digital Communication. | |
| [534] | IEEE Guide for Automatic Reclosing of Circuit Breakers for AC Distribution and Transmission Lines. | |
| [535] | IEEE Guide for Breaker Failure Protection of Power Circuit Breakers. | |
| [536] | IEEE Guide for Determining Fault Location on AC Transmission and Distribution Lines. | |
| [537] | IEEE Guide for Determining Fault Location on AC Transmission and Distribution Lines. | |
| [538] | IEEE Guide for Diagnostic Field Testing of Fluid-Filled Power Transformers, Regulators, and Reactors. | |
| [539] | IEEE Guide for Differential and Polarizing Relay Circuit Testing. | |
| [540] | IEEE Guide for Field Testing of Relaying Current Transformers. | |
| [541] | IEEE Guide for Field Testing of Relaying Current Transformers. | |
| [542] | IEEE Guide for Field Testing of Relaying Current Transformers. | |
| [543] | IEEE Guide for Gas-Insulated Substations Rated Above 52 kV Sponsored by the Substations Committee IEEE 3. | |
| [544] | IEEE Guide for Generating Station Grounding. | |
| [545] | IEEE Guide for Grounding of Instrument Transformer Secondary Circuits and Cases. | |
| [546] | IEEE Guide for Identifying and Improving Voltage Quality in Power Systems. | |
| [547] | IEEE Guide for Improving the Lightning Performance of Electric Power Overhead Distribution Lines. | |
| [548] | IEEE Guide for Moisture Measurement and Control in SF6 Gas-Insulated Equipment. | |
| [549] | IEEE Guide for Monitoring, Information Exchange, and Control of Distributed Resources Interconnected with Electric Power Systems. | |
| [550] | IEEE Guide for On-Site Acceptance Tests of Electrical Equipment and System Commissioning of 1000 kV AC and Above. | |
| [551] | IEEE Guide for Paralleling Regulating Transformers. | |
| [552] | IEEE Guide for Phasor Data Concentrator Requirements for Power System Protection, Control, and Monitoring. | |
| [553] | IEEE Guide for Phasor Data Concentrator Requirements for Power System Protection, Control, and Monitoring. | |
| [554] | IEEE Guide for Power System Protection Testing. | |
| [555] | IEEE Guide for Power System Protective Relay Applications of Audio Tones Over Voice Grade Channels. | |
| [556] | IEEE Guide for Power System Protective Relay Applications Over Digital Communication Channels. | |
| [557] | IEEE Guide for Protective Relay Application to Transmission-Line Series Capacitor Banks. | |
| [558] | IEEE Guide for Protective Relay Application to Transmission-Line Series Capacitor Banks. | |
| [559] | IEEE Guide for Protective Relay Applications to Distribution Lines. | |
| [560] | IEEE Guide for Protective Relay Applications to Power System Buses. | |
| [561] | IEEE Guide for Protective Relay Applications to Power Transformers. | |
| [562] | IEEE Guide for Protective Relaying of Utility-Consumer Interconnections. | |
| [563] | IEEE Guide for Sulphur Hexafluoride (SF6) Gas Handling for High-Voltage (over 1000 Vac) Equipment. | |
| [564] | IEEE Guide for Switchgear—Unit Substation—Requirements. | |
| [565] | IEEE Guide for Switchgear—Unit Substation—Requirements. | |
| [566] | IEEE Guide for Synchronization, Calibration, Testing, and Installation of Phasor Measurement Units (PMUs) for Power System Protection and Control. | |
| [567] | IEEE Guide for Temporary Protective Grounding Systems Used in Substations. | |
| [568] | IEEE Guide for the Application of Capacitance Current Switching for AC High-Voltage Circuit Breakers Above 1000 V. | |
| [569] | IEEE Guide for the Application of Current Transformers Used for Protective Relaying Purposes Corrigendum 1: corrections to Equation 18 and Equation 19. | |
| [570] | IEEE Guide for the Application of Current Transformers Used for Protective Relaying Purposes Corrigendum 1: Corrections to Equation 18 and Equation 19. | |
| [571] | IEEE Guide for the Application of Gas-Insulated Substations 1 kV to 52 kV. | |
| [572] | IEEE Guide for the Application of Neutral Grounding in Electrical Utility Systems, Part IV—Distribution. | |
| [573] | IEEE Guide for the Application of Neutral Grounding in Electrical Utility Systems—Part I: Introduction. | |
| [574] | IEEE Guide for the Application of Protective Relays Used for Abnormal Frequency Load Shedding and Restoration. | |
| [575] | IEEE Guide for the Application of Rogowski Coils Used for Protective Relaying Purposes. | |
| [576] | IEEE Guide for the Application of shunt reactor switching. | |
| [577] | IEEE Guide for the Application of Thyristor Surge Protective Device Components. | |
| [578] | IEEE Guide for the Design and Installation of Cable Systems in Substations. | |
| [579] | IEEE Guide for the Functional Specification of Fixed-Series Capacitor Banks for Transmission System Applications. | |
| [580] | IEEE Guide for the Interpretation of Gases Generated in Oil-Immersed Transformers. | |
| [581] | IEEE Guide for the Protection of Communication Installations from Lightning Effects. | |
| [582] | IEEE Guide for the Protection of Shunt Capacitor Banks. | |
| [583] | IEEE Guide for Transformer Loss Measurement. | |
| [584] | IEEE Guide for Transformer Loss Measurement. | |
| [585] | IEEE Guide to Describe the Occurrence and Mitigation of Switching Transients Induced by Transformers, Switching The device, and System Interaction. | |
| [586] | IEEE Recommended Practice for Calculating Short – Circuit Currents in Industrial and Commercial Power Systems. | |
| [587] | IEEE Recommended Practice for Establishing Liquid-Filled and Dry- Type Power and Distribution Transformer Capability When Supplying Nonsinusoidal Load Currents. | |
| [588] | IEEE Recommended Practice for Grounding of Industrial and Commercial Power Systems. | |
| [589] | IEEE Recommended Practice for Monitoring Electric Power Quality. | |
| [590] | IEEE Recommended Practice for Network Communication in Electric Power Substations. | |
| [591] | IEEE Recommended Practice for Overvoltage and Insulation Coordination of Transmission Systems at 1000 kV AC and Above. | |
| [592] | IEEE Recommended Practice for Protection and Coordination of Industrial and Commercial Power Systems. | |
| [593] | IEEE Recommended Practice for Protection and Coordination of Industrial and Commercial Power Systems_1988. | |
| [594] | IEEE Recommended Practice for Smart Grid Communications Equipment— Test Methods and Installation Requirements. | |
| [595] | IEEE Recommended Practice for the Application of Instrument Transformers in Industrial and Commercial Power Systems. | |
| [596] | IEEE Recommended Practice for the Interface of New Gas-Insulated Equipment in Existing Gas-Insulated Substations Rated above 52 kV. | |
| [597] | IEEE Recommended Practice for the Protection of Wire-Line Communication Facilities Serving Electric Supply Locations. | |
| [598] | IEEE Standard Common Format for Transient Data Exchange (COMTRADE) for Power Systems. | |
| [599] | IEEE Standard Communication Delivery Time Performance Requirements for Electric Power Substation Automation. | |
| [600] | IEEE Standard Criteria for the Protection of Class 1E Power Systems and Equipment in Nuclear Power Generating Stations. | |
| [601] | IEEE Standard Cybersecurity Requirements for Substation Automation, Protection, and Control Systems. | |
| [602] | IEEE Standard Electrostatic Discharge Tests for Protective Relays. | |
| [603] | IEEE Standard Environmental and Testing Requirements for Communications Networking Devices Installed in Electric Power Substations Amendment 1: Adding of one Definition, dc power supply requirements (5.1), and Annex E—History. | |
| [604] | IEEE Standard Environmental and Testing Requirements for Communications Networking Devices Installed in Electric Power Substations Amendment 1: Adding of one Definition, dc power supply requirements (5.1), and Annex E—History. | |
| [605] | IEEE Standard Environmental and Testing Requirements for Communications Networking Devices Installed in Electric Power Substations. | |
| [606] | IEEE Standard Environmental and Testing Requirements for Communications Networking Devices Installed in Electric Power Substations. | |
| [607] | IEEE Standard Environmental and Testing Requirements for Communications Networking Devices Installed in Electric Power Substations. | |
| [608] | IEEE Standard Environmental and Testing Requirements for Communications Networking Devices Installed in Transmission and Distribution Facilities. | |
| [609] | IEEE Standard for a Precision Clock Synchronization Protocol for Networked Measurement and Control Systems. | |
| [610] | IEEE Standard for a Precision Clock Synchronization Protocol for Networked Measurement and Control Systems. | |
| [611] | IEEE Standard for Broadband over Power Line Networks: Medium Access Control and Physical Layer Specifications. | |
| [612] | IEEE Standard for Common Format for Event Data Exchange (COMFEDE) for Power Systems. | |
| [613] | IEEE Standard for Conformance Test Procedures for Service Interoperability in Ethernet Passive Optical Networks, IEEE Std 1904.1TM Package A. | |
| [614] | IEEE Standard for DC (3200 V and below) Power Circuit Breakers Used in Enclosures. | |
| [615] | IEEE Standard for Device Discovery, Connection Management, and Control Protocol for IEEE 1722™ Based Devices. | |
| [616] | IEEE Standard for Electric Power Systems Communications— Distributed Network Protocol (DNP3). | |
| [617] | IEEE Standard for Electrical Power System Device Function Numbers, Acronyms, and Contact Designations. | |
| [618] | IEEE Standard for Ethernet. | |
| [619] | IEEE Standard for Ethernet. | |
| [620] | IEEE Standard for Ethernet Amendment 1: Physical Layer Specifications and Management Parameters for Extended Ethernet Passive Optical Networks. | |
| [621] | IEEE Standard for Ethernet Amendment 3: Physical Layer Specifications and Management Parameters for 40 Gb/s and 100 Gb/s Operation over Fiber Optic Cables. | |
| [622] | IEEE Standard for Information technology— Telecommunications and information exchange between systems Local and metropolitan area networks— Specific requirements Part 17: Resilient packet ring (RPR) access method and physical layer
specifications. | |
| [623] | IEEE Standard for Local and metropolitan area networks— Bridges and Bridged Networks. | |
| [624] | IEEE Standard for Local and metropolitan area networks— Bridges and Bridged Networks Amendment 23: Application Virtual Local Area Network (VLAN) Type, Length, Value (TLV). | |
| [625] | IEEE Standard for Local and Metropolitan Area Networks: Overview and Architecture. | |
| [626] | IEEE Standard for Local and metropolitan area networks—Media Access Control (MAC) Bridges and Virtual Bridged Local Area Networks— Amendment 20: Shortest Path Bridging. | |
| [627] | IEEE Standard for Management Information Base (MIB) Definitions for Ethernet. | |
| [628] | IEEE Standard for Metal-Clad Switchgear. | |
| [629] | IEEE Standard for Metal-Enclosed Interrupter Switchgear. | |
| [630] | IEEE Standard for Power-Line Carrier Line-Tuning Equipment (30 kHz to 500 kHz) Associated with Power Transmission Lines. | |
| [631] | IEEE Standard for Qualifying Class 1E Protective Relays and Auxiliaries for Nuclear Power Generating Stations. | |
| [632] | IEEE Standard for Relays and Relay Systems Associated with Electric Power Apparatus. | |
| [633] | IEEE Standard for Service Interoperability in Ethernet Passive Optical Networks (SIEPON). | |
| [634] | IEEE Standard for Substation Intelligent Electronic Devices (IEDs) Cyber Security Capabilities. | |
| [635] | IEEE Standard for Surge Withstand Capability (SWC) Tests for Relays and Relay Systems Associated with Electric Power Apparatus. | |
| [636] | IEEE Standard for Surge Withstand Capability (SWC) Tests for Relays and Relay Systems Associated with Electric Power Apparatus. | |
| [637] | IEEE Standard for Surge Withstand Capability (SWC) Tests for Relays and Relay Systems Associated with Electric Power Apparatus. | |
| [638] | IEEE Standard for Synchrophasor Data Transfer for Power Systems. | |
| [639] | IEEE Standard for Synchrophasor Data Transfer for Power Systems. | |
| [640] | IEEE Standard for Synchrophasor Measurements for Power Systems. | |
| [641] | IEEE Standard for Synchrophasor Measurements for Power Systems. | |
| [642] | IEEE Standard for Synchrophasor Measurements for Power Systems Amendment 1: Modification of Selected Performance Requirements. | |
| [643] | IEEE Standard for Synchrophasors for Power Systems. | |
| [644] | IEEE Standard for Synchrophasors for Power Systems. | |
| [645] | IEEE Standard for Test Methods and Preferred Values for Self-Restoring Current-Limiter Components Used in Telecommunication Surge Protection. | |
| [646] | IEEE Standard for the Electrical Protection of Communication Facilities Serving Electric Supply Locations Through the Use of On-Grid Isolation Equipment. | |
| [647] | IEEE Standard for the Electrical Protection of Communications Facilities Serving Electric Supply Locations—General considerations. | |
| [648] | IEEE Standard for Trip Systems for Low-Voltage (1000 V and below) AC and General Purpose (1500 V and below) DC Power Circuit Breakers. | |
| [649] | IEEE Standard for Withstand Capability of Relay Systems to Radiated Electromagnetic Interference from Transceivers. | |
| [650] | IEEE Standard Profile for Use of IEEE 1588™ Precision Time Protocol in Power System Applications. | |
| [651] | IEEE Standard Profile for Use of IEEE 1588™ Precision Time Protocol in Power System Applications. | |
| [652] | IEEE Standard Requirements for Instrument Transformers. | |
| [653] | IEEE Standard Requirements for Secondary Network Protectors. | |
| [654] | IEEE Standard Requirements, Terminology, and Test Code for Step-Voltage Regulators. | |
| [655] | IEEE Standard Terminology for Power and Distribution Transformers. | |
| [656] | IEEE Standard Terminology for Power and Distribution Transformers. | |
| [657] | IEEE Standard Terminology for Power and Distribution Transformers. | |
| [658] | IEEE Standard Test Code for Dry-Type Distribution and Power Transformers. | |
| [659] | IEEE Standard Test Code for Liquid-Immersed Distribution, Power, and Regulating Transformers. | |
| [660] | IEEE Standard Test Method for Use in the Evaluation of Message Communications Between Intelligent Electronic Devices in an Integrated Substation Protection, Control, and Data Acquisition System. | |
| [661] | IEEE Standard Test Method for Use in the Evaluation of Message Communications between Intelligent Electronic Devices in an Integrated Substation Protection, Control, and Data Acquisition System. | |
| [662] | IEEE Std 802.1. | |
| [663] | IEEE Trial-Use Standard for Optical AC Current and Voltage Sensing Systems. | |
| [664] | Impacts of Short Circuit Currents. | |
| [665] | Implementation and Testing of Directional Comparison Bus Protection Based on IEC61850 Process Bus. | |
| [666] | IMPLEMENTATION AND TESTING OF GOOSE MESSAGE ON IEC61850 BASED RELAY IEDs. | |
| [667] | IMPLEMENTATION GUIDELINE FOR DIGITAL INTERFACE TO INSTRUMENT TRANSFORMERS USING IEC 61850-9-2. | |
| [668] | An Implementation of FTTH based Home Gateway Supporting Various Services. | |
| [669] | Implementation of the SEL-49 Relay Line Thermal Protection in the SEL-421 Relays Using SELOGIC Equations. | |
| [670] | Implementing Vehicle-to-Grid (V2G) Technology With IEC 61850-7-420. | |
| [671] | Improve Protective Relaying Systems Reliability by Dynamic Testing. | |
| [672] | Improved operations and asset health using System 800xA with IEC 61850. | |
| [673] | Improving power system reliability through a focus on human factors. | |
| [674] | Improving the Quality of Multicast Networks by Using the OPNET Modeler. | |
| [675] | Inadvertent energization protection: ANSI 50/27. | |
| [676] | Increasing Efficiency with IEC 61850 Protection Parameters. | |
| [677] | Increasing uptime with complete solutions. | |
| [678] | Industrial Communication. | |
| [679] | Industrial Communication. | |
| [680] | Industrial Communication. | |
| [681] | INDUSTRIAL INFORMATION TECHNOLOGY. | |
| [682] | INDUSTRIAL POWER AND AUTOMATION LAB MANUAL. | |
| [683] | Industrial Remote Communication Efficient remote access to plants, machines, and mobile applications. | |
| [684] | Influence of The Equal and Unequal CT Ratios On The Setting of REL 350 Relays. | |
| [685] | Innovation on Medium Voltage Switchgear. | |
| [686] | Innovative Power Distribution in the Automotive Industry Cost-effective and reliable power distribution. | |
| [687] | Innovative Solutions for Substations. | |
| [688] | Installation and commissioning manual Busbar protection IED REB 670. | |
| [689] | Installation and commissioning manual Line distance protection IED REL 670. | |
| [690] | INSTRUCTION MANUAL DISTANCE RELAY WITH INTEGRAL DIGITAL COMMUNICATION GRZ100. | |
| [691] | INSTRUCTION MANUAL TRANSFORMER PROTECTION RELAY GRT100. | |
| [692] | INSTRUCTION MANUAL TRANSFORMER PROTECTION RELAY GRT100 – ∗∗∗C. | |
| [693] | INSTRUMENT HOOKUP. | |
| [694] | INSTRUMENT LIST. | |
| [695] | Integrated energy automation A sophisticated basis for ENEAS (Efficient Network and Energy Automation Systems). | |
| [696] | Integration of a New Standard. | |
| [697] | Integration of IEC 61850 GSE and Sampled Value Services to Reduce Substation Wiring. | |
| [698] | The Intelligent MV/LV substation an Important Module for Optimizing Distribution Grids. | |
| [699] | Interface Board Overview for CMC Test Sets. | |
| [700] | Interfacing with OPC, IEC61850, and IEC 60870-5-10x. | |
| [701] | INTERNSHIP REPORT USE OF IEC 61850 FOR ASSET MANAGEMENT IN LOW VOLTAGE MICROGRIDS. | |
| [702] | Interoperability and Performance Analysis of IEC61850 Based Substation Protection System. | |
| [703] | Interoperability and Performance Analysis of IEC61850 Based Substation Protection System. | |
| [704] | Interoperability Requirements for IEC 61850 System Configuration Tools. | |
| [705] | Intro to Protection Sys. | |
| [706] | Introduction and Overview of IEC 61850 Configuration and Diagnostics. | |
| [707] | Introduction TO CURRENT TRANSFORMER PERFORMANCE ANALYSIS. | |
| [708] | Introduction to Electrical Power Systems. | |
| [709] | INTRODUCTION TO SYSTEM PROTECTION. | |
| [710] | INVESTIGATION OF THE APPLICATION OF THE IEC61850 STANDARD IN DISTRIBUTION BUSBAR PROTECTION SCHEMES. | |
| [711] | IO LIST. | |
| [712] | IP and Ethernet Communication Technologies and Topologies for IED networks. | |
| [713] | IP and Ethernet Communication Technologies and Topologies for IED networks. | |
| [714] | Issues and Approaches on Extending Ethernet Beyond LANs. | |
| [715] | The IT earthing system (unearthed neutral) in LV. | |
| [716] | The J & P Transformer Book. | |
| [717] | Journal of Reliable Power. | |
| [718] | KBCH 120, 130, 140 Transformer Differential Protection Relay. | |
| [719] | L01-Introduction to Deregulation. | |
| [720] | Laboratory Investigation of IEC 61850-9-2-Based Busbar and Distance Relaying With Corrective Measure for Sampled Value Loss/Delay. | |
| [721] | Large Scale Grid Integration of Renewable Energy Sources – Way Forward. | |
| [722] | Leading the substation automation revolution 6. | |
| [723] | Leading the way to Digital Substations. | |
| [724] | Lecture 5a Substation Automation Systems. | |
| [725] | Lightning Protection. | |
| [726] | Line Constants. | |
| [727] | Line Differential Protection / 7SD52/53 SIPROTEC 4 7SD52/53 multi-end differential and distance protection in one relay. | |
| [728] | Line Differential Protection / 7SD61 SIPROTEC 4 7SD61 differential protection relay for two line ends. | |
| [729] | Line differential protection RED670 2.0 IEC Application Manual. | |
| [730] | Line differential protection RED670 2.0 IEC Commissioning Manual. | |
| [731] | Line differential protection RED670 2.0 IEC Technical Manual. | |
| [732] | Line differential protection RED670 Application manual. | |
| [733] | Line differential protection RED670 Installation and commissioning manual. | |
| [734] | Line differential protection RED670 Operator’s manual. | |
| [735] | Line differential protection RED670 Technical reference manual. | |
| [736] | Line Differential relay 7sd52. | |
| [737] | Line distance protection REL650 Product Guide. | |
| [738] | Line distance protection REL650 Technical Manual. | |
| [739] | Line distance protection REL670 Application manual. | |
| [740] | Line distance protection REL670 Technical reference manual. | |
| [741] | LINE PROTECTION SEMINAR. | |
| [742] | LINE PROTECTION TESTS USING PROCESS BUS IEC 61850-9-2 WITH NETWORK LOADING. | |
| [743] | Line-To-Ground Faults Neutral Treatment. | |
| [744] | Load flow. | |
| [745] | Locating Faults by the Traveling Waves They Launch. | |
| [746] | LOGIC DIAGRAM (CONTROL AND SYNCHRONIZING). | |
| [747] | Loss of field protection: ANSI 40 (for generator). | |
| [748] | LR-D OVERLOAD RELAYS. | |
| [749] | MAGNUM 6K FAMILY OF SWITCHES. | |
| [750] | Magnum 6KL Managed Edge Switch. | |
| [751] | Maintenance Testing of IEC 61850 Based Protection and Control Systems. | |
| [752] | MANUAL ON TRANSMISSION PLANNING CRITERIA. | |
| [753] | Mapping OPC to MMS for Non-IEC 61850-Compliant SEL Devices Using SISCO AX-S4 MMS. | |
| [754] | Mastering the digital substation. | |
| [755] | MBCI (Translay S) Technical Manual Differential Feeder and Transformer Feeder Protection. | |
| [756] | MCCB (MOULDED CASE CIRCUIT BREAKER). | |
| [757] | Medium voltage switching during faulty operation Fault localization. | |
| [758] | Meeting the NEC Selective Coordination Requirements. | |
| [759] | mem protectin course. | |
| [760] | Memory Requirements Analysis for PRP and HSR Hardware Implementations on FPGAs. | |
| [761] | Merging Unit 7SC805. | |
| [762] | MFAC 14/34 High Impedance Differential Relays Technical Manual. | |
| [763] | MiCOM Alstom P40. | |
| [764] | MiCOM C264. | |
| [765] | MiCOM P54x P543, P544, P545 & P546 Current Differential Relay. | |
| [766] | MiCOM P120/P121/P122/P123 Overcurrent Relays. | |
| [767] | MiCOM P120/P121/P122/P123 Overcurrent Relays Version 6 Technical Guide P12X/EN T/G75. | |
| [768] | MiCOM P124 Self & Dual Powered Overcurrent Relays. | |
| [769] | MiCOM P125, P126, P127 Series Directional/Non-Directional Relays. | |
| [770] | MiCOM P125/P126 & P127 Directional/Non-directional Relay Version 11 Technical Guide. | |
| [771] | MiCOM P132 Feeder Management and Bay Control. | |
| [772] | Micom p241 Motor Management Relay. | |
| [773] | MiCOM P441, P442 & P444 Numerical Distance Protection VC4.x, VC5.x, and VD1.x Technical Guide. | |
| [774] | MiCOM P441/P442 & P444 Numerical Distance Protection. | |
| [775] | MiCOM P441/P442/P444 Numerical Distance Protection P44x/EN T/G75 Version D3.0. | |
| [776] | MiCOM P543, P544, P545, P546 Technical Manual Current Differential Protection Relays. | |
| [777] | MiCOM P631, P632, P633, and P634 Transformer Differential Protection Devices. | |
| [778] | MiCOM P631, P632, P633, P634 Transformer Differential Protection. | |
| [779] | MiCOM P631/P632/P633/P634 Transformer Differential Protection Devices. | |
| [780] | MiCOM P632 Transformer Differential Protection Device P632/EN M/R-21-A. | |
| [781] | MiCOM P642, P643 & P645 Transformer Protection Relay Software version 02B Hardware suffix J (P642) Hardware suffix K (P643/5) Technical Data Sheet P64x/EN TDS/A21. | |
| [782] | MiCOM P741, P742, P743 Technical Manual Differential Busbar Protection Relay. | |
| [783] | MiCOM P821 Breaker Failure Protection. | |
| [784] | MiCOM P921/P922/P923 Voltage and Frequency Relays Version V2 Technical Guide. | |
| [785] | MiCOM Px4x-92LE Technical Manual IEC 61850-9-2LE Interface. | |
| [786] | MiCOMho P443 Fast Multifunction Distance Protection Software Version 0540 Hardware Suffix K Technical Manual. | |
| [787] | MICROPROCESSOR-BASED ADVANCED BUS PROTECTION SCHEME USING IEC 61850 PROCESS BUS (9-2) SAMPLED VALUES. | |
| [788] | Microgrid Protection. | |
| [789] | MICROPROCESSOR-BASED POWER SYSTEM PROTECTION NUMERICAL RELAYS. | |
| [790] | MIF Digital Feeder Protection Instruction manual GEK-106273L. | |
| [791] | MIFII Digital Feeder Protection with Recloser Instruction manual GEK-106237N. | |
| [792] | Migration of a legacy substation to a new system solution in Norway. | |
| [793] | MIGRATION PATHS FOR IEC 61850 SUBSTATION COMMUNICATION NETWORKS TOWARDS SUPERB REDUNDANCY BASED ON HYBRID PRP AND HSR TOPOLOGIES. | |
| [794] | Minutes of Pre-Bid Meeting of 400 KV Srinagar Substation ICB NO. 2-P/ADB/PTCUL/400 KV. | |
| [795] | mk232 earth fault relay. | |
| [796] | mk300 earth leakage relay. | |
| [797] | mk2200 combined overcurrent and earth fault. | |
| [798] | Model Implementation Conformance Statement (MICS) for IEC 61850 for the SEL Real-Time Automation Controllers. | |
| [799] | Model Implementation Conformance Statement for the IEC 61850 interface in SEL-351A. | |
| [800] | Model Implementation Conformance Statement for the IEC 61850 interface in SEL-351S. | |
| [801] | Model Implementation Conformance Statement for the IEC 61850 interface in SEL-2411. | |
| [802] | Model Implementation Conformance Statement for the IEC 61850 interface in SEL-2440. | |
| [803] | MODEL SETTING CALCULATIONS FOR TYPICAL IEDs LINE PROTECTION SETTING GUIDELINES PROTECTION SYSTEM AUDIT CHECKLIST RECOMMENDATIONS FOR PROTECTION MANAGEMENT. | |
| [804] | Modeling and Simulation of Data Flow for VLAN-Based Communication in Substations. | |
| [805] | Modeling of a Centralized Microgrid Protection System and Distributed Energy Resources According to IEC 61850-7-420. | |
| [806] | Modeling of Transmission Lines. | |
| [807] | Modeling and (Co-)simulation of power systems, controls, and components for analyzing complex energy systems. | |
| [808] | Modeling and Simulation for Performance Evaluation of IEC61850-Based Substation Communication Systems. | |
| [809] | Modern methods for commissioning hybrid substations using IEC 61850 and conventional signals wiring. | |
| [810] | Modern methods for commissioning hybrid substations using IEC 61850 and conventional signals wiring. | |
| [811] | Modernization of National Oil Industry in Mexico: Upgrading With IEC61850. | |
| [812] | Module 1: Fundamentals of Power System Protection Lecture 3: Protection Paradigms – System Protection. | |
| [813] | More Than Communication – the Engineering Approach of IEC 61850. | |
| [814] | Motor Protection Relay Setting. | |
| [815] | MU. | |
| [816] | MU320 Merging Unit. | |
| [817] | MU – AGILE XMU800. | |
| [818] | MU Agile AMU Technical Manual Analogue Merging Unit. | |
| [819] | Multiagent Smart Grid Automation Architecture Based on IEC 61850/61499 Intelligent Logical Nodes. | |
| [820] | Multifunctional Paralleling Devices 7VE6. | |
| [821] | Multi-Functional Protective Relays 7SJ61, 7SJ62, 7SJ64. | |
| [822] | A&N Electric Cooperative Smart Grid distribution feeder automation system improves service reliability. | |
| [823] | NET-1B CMC Reference Manual Appendix. | |
| [824] | NET-1B Option Upgrade Instructions for the NET-1B Option for the Test Sets CMC 256, CMC 256plus & CMC 356. | |
| [825] | NET-1C Option Upgrade Instructions for the NET-1C Option for the Test Sets CMC 256-6, CMC 256plus, CMC 353 & CMC 356. | |
| [826] | NET-2 Option Upgrade Instructions for the NET-2 Option for the Test Sets CMC 256-6, CMC 256plus, CMC 353, CMC 356 and CMC 310. | |
| [827] | Network Interactions and Performance of a Multifunction IEC 61850 Process Bus. | |
| [828] | Network Protection. | |
| [829] | Network Protection & Automation Guide. | |
| [830] | Network protection and Auto Guide. | |
| [831] | A network scheme for process bus in smart substations without using external synchronization. | |
| [832] | Networking with the CMC 256 & NET-1 Option. | |
| [833] | Neutral earthing in low voltage. | |
| [834] | Neutral Grounding. | |
| [835] | New Age of Electric Energy System brings a New Set of Challenges for Protection and Automation. | |
| [836] | New Age of Electric Energy System brings a New Set of Challenges for Protection and Automation. | |
| [837] | New General Method for Differential Protection of Phase Shifting Transformers. | |
| [838] | A New IED With PMU Functionalities For Electrical Substations. | |
| [839] | A New Method for Protection Zone Selection in Microprocessor-Based Bus Relays. | |
| [840] | A new traveling wave fault locating algorithm for line current differential relays. | |
| [841] | Newsletter. | |
| [842] | Next-generation substations. | |
| [843] | NGR DATA SHEET & DETAILS. | |
| [844] | Non-conventional instrument transformers Advanced GIS substations with IEC 61850-9-2 LE process bus. | |
| [845] | A Note on the Modeling of Transmission-Line Losses. | |
| [846] | NTG MULTIFUNCTION GENERATOR PROTECTION RELAY. | |
| [847] | Numerical Circuit Breaker Failure Protection SIPROTEC 7SV600. | |
| [848] | Object Modeling of Data and DataSets in the International Standard IEC 61850. | |
| [849] | OMICRON PTL Protection Test Template PTT Generator Protection AREVA P343 344 345 User Manual V1.001. | |
| [850] | OMICRON PTL Schweitzer SEL 421 R317 Line PTT User Manual. | |
| [851] | OMICRON PTL User manual. | |
| [852] | OMICRON PTL XRIO Converter AREVA P34x User Manual. | |
| [853] | OMICRON Test Universe Scheme Testing Tools. | |
| [854] | OMICRON Test Universe Scheme Testing Tools CommPro v1.5 User Manual. | |
| [855] | On the Use of IEEE 1588 in Existing IEC 61850-Based SASs: Current Behavior and Future Challenges. | |
| [856] | On-Board Products and Systems. | |
| [857] | ONE-LINE DIAGRAM SHOWING. | |
| [858] | One-Way Delay and PTP (IEEE 1588v2) Test Applications. | |
| [859] | Online Location of Faults on AC Cables in Underground Transmission. | |
| [860] | An Open Platform for Rapid-Prototyping Protection and Control Schemes With IEC 61850. | |
| [861] | Operating Programs. | |
| [862] | Operation Guide MiCOM P941, P942, P943 Frequency Relays. | |
| [863] | Operation of a Utility Connected Microgrid Using an IEC 61850-Based Multi-Level Management System. | |
| [864] | operation switching Sequences. | |
| [865] | The operation, Maintenance, and Field Test Procedures for Protective Relays and Associated Circuits. | |
| [866] | Operator’s manual Bay control IED REC 670. | |
| [867] | Operator’s manual Busbar protection IED REB 670. | |
| [868] | Operator’s manual Generator protection IED REG 670. | |
| [869] | Operator’s manual Line differential protection IED RED 670. | |
| [870] | Optimized Security Algorithm for IEC 61850 based Power Utility System. | |
| [871] | Optimizing substation with Digital technology. | |
| [872] | Out-of-Step Protective Functions and Challenges in Testing. | |
| [873] | Overall Differential Protection for Pump Storage Power Plant with Tapped-Delta Design of the Unit Transformer. | |
| [874] | Overcurrent and earth-fault relay. | |
| [875] | Overcurrent Coordination. | |
| [876] | OVERCURRENT COORDINATION GUIDELINES FOR INDUSTRIAL POWER SYSTEMS. | |
| [877] | Overcurrent Protection. | |
| [878] | Overcurrent Protection & Coordination for Industrial Applications. | |
| [879] | Overcurrent Protection & Coordination for Industrial Applications. | |
| [880] | Overcurrent Protection / 7SJ61 SIPROTEC 4 7SJ61 multifunction protection relay. | |
| [881] | Overcurrent Protection / 7SJ62 SIPROTEC 4 7SJ62 multifunction protection relay. | |
| [882] | Overcurrent Protection / 7SJ63 SIPROTEC 4 7SJ63 multifunction protection relay. | |
| [883] | Overcurrent Protection / 7SJ64 SIPROTEC 4 7SJ64 multifunction protection relay with synchronization. | |
| [884] | Overcurrent Protection / 7SJ600 SIPROTEC 7SJ600 numerical overcurrent, motor, and overload protection relay. | |
| [885] | Overcurrent Protection / 7SJ602 SIPROTEC 7SJ602 multifunction overcurrent and motor protection relay. | |
| [886] | Overcurrent Protection Lecture 16 PSM Setting and Phase Relay Coordination. | |
| [887] | Over-Current Relay Model Implementation for Real-Time Simulation & Hardware-In-the-Loop (HIL) Validation. | |
| [888] | Over fluxing protection: ANSI 24 (for generator). | |
| [889] | Overview of IEC 61850. | |
| [890] | Overview of IEC 61850. | |
| [891] | P40. | |
| [892] | Pac spring 2008. | |
| [893] | Pac winter 2008. | |
| [894] | PACiS Solutions for Substation Automation. | |
| [895] | Packet Tracer Network Simulator. | |
| [896] | The Parallel Redundancy Protocol for Industrial IP Networks. | |
| [897] | PCM 600. | |
| [898] | Performance Analysis of IEC 61850 Sampled Value Process Bus Networks. | |
| [899] | Performance assessment of an IEC 61850-9-2 based protection scheme for the mesh corner of a 400kV transmission substation. | |
| [900] | Performance Evaluation of Time-critical Communication Networks for Smart Grids based on
IEC 61850. | |
| [901] | Performance of IEC 61850-9-2 Process Bus and Corrective Measure for Digital Relaying. | |
| [902] | PERUSAHAAN LISTRIK NEGARA Experience on Implementing Power Swing Load Shedding Scheme in the Middle-South Systems of Sumatera. | |
| [903] | Phasor measurement based on IEC 61850-9-2 and Kalman–Filtering. | |
| [904] | PHENOMENA RELATED TO SYSTEM FAULTS AND THE PROCESS OF CLEARING FAULTS FROM A POWER SYSTEM. | |
| [905] | Pilot Project for IEC 61850 based SAS in Tepco. | |
| [906] | Plan Ahead for Substation Automation. | |
| [907] | Planning of Electric Power Distribution Technical Principles. | |
| [908] | Planning of electrical networks with PSS™SINCAL. | |
| [909] | Plc based sa and SCADA. | |
| [910] | Plug-in rapid-wire integrated. | |
| [911] | pmu. | |
| [912] | Pole slip protection: ANSI 78PS (for generator). | |
| [913] | Power Engineering Guide Transmission and Distribution. | |
| [914] | Power Monitoring Device and Class A Power Quality Recorder SICAM Q100 7KG95xx V1.20 Device Manual. | |
| [915] | Power network telecommunication PowerLink – power line carrier system. | |
| [916] | Power network telecommunication PowerLink – technical data. | |
| [917] | Power network telecommunication SWT 3000 Teleprotection. | |
| [918] | The power of IEC 61850. | |
| [919] | Power Plant _Monenco Book. | |
| [920] | Power quality measurement methods and calibration. | |
| [921] | Power System and Substation Automation. | |
| [922] | POWER SYSTEM MONITORING. | |
| [923] | POWER SYSTEM PHENOMENA AND THEIR IMPACT ON RELAY SYSTEM PERFORMANCE. | |
| [924] | POWER SYSTEM PROTECTION. | |
| [925] | Power System Protection. | |
| [926] | power system protection. | |
| [927] | POWER SYSTEM PROTECTION. | |
| [928] | Power System Protection 22 Setting of Distance Relays. | |
| [929] | Power System Protection Testing with the CMC Test System Training Agenda. | |
| [930] | Power system restructuring and deregulation. | |
| [931] | Power Systems Communications. | |
| [932] | Power Systems Modelling and Fault Analysis. | |
| [933] | Power Transformer Characteristics and Their Effect on Protective Relays. | |
| [934] | PQM Power Quality Meter™ INSTRUCTION MANUAL. | |
| [935] | PQMII Power Quality Meter™. | |
| [936] | A Practical and Open Source Implementation of IEC 61850-7-2 for IED Monitoring Applications. | |
| [937] | a practical application primer for protection engineers. | |
| [938] | Practical Applications of Ethernet in Substations and Industrial Facilities. | |
| [939] | PRACTICAL CHALLENGES AND SOLUTIONS FOR PROTECTION ENGINEERING. | |
| [940] | Practical Considerations for Ethernet Networking Within Substations. | |
| [941] | Practical Examples. | |
| [942] | Practical experience from multiterminal line differential protection installations. | |
| [943] | Practical Experience with Differential Protection for Converter Transformers. | |
| [944] | Practical Experience with IEEE 1588 High Precision Time Synchronization in Electrical Substation based on IEC 61850 Process Bus. | |
| [945] | Practical Extension of Protection Systems with IEC 61850 Based Communication at Minimal Configuration Effort. | |
| [946] | Practical Implementation Of IEC 61850 based Substation. | |
| [947] | Practical Introduction To Power System Protection And Control. | |
| [948] | Practical power system protection. | |
| [949] | Practical Power Systems Protection. | |
| [950] | Practical Synchronized Phasor Solutions. | |
| [951] | Precision Clock Synchronization. | |
| [952] | Precision Time Protocol. | |
| [953] | Principles of Differential Relaying. | |
| [954] | Probabilistic Reliability Analysis Supporting Distribution Network Expansion. | |
| [955] | Problems and Solutions for AC Transmission Line Protection under Extreme Conditions caused by Very Long HVDC Cables. | |
| [956] | Procedure for Testing P122, P123, P143, P643. | |
| [957] | <Procedure for Testing P123.pdf>. | |
| [958] | Process data analysis. | |
| [959] | Process Instrumentation and Analytics At the heart of your efficiency. | |
| [960] | Processes, Issues, Trends, and Quality Control of Relay Settings. | |
| [961] | Product Guide. | |
| [962] | Products for Totally Integrated Automation. | |
| [963] | Programming a LOCK Pushbutton in the SEL-421 Relay. | |
| [964] | Project Administration. | |
| [965] | PROPAGATION AND INTERACTION OF ETHERNET PACKETS WITH IEC 61850 SAMPLED VALUES IN POWER UTILITY COMMUNICATION NETWORKS. | |
| [966] | Protection. | |
| [967] | Protection. | |
| [968] | abb, “Protection and control devices.” | |
| [969] | Protection and Control IED Manager PCM600 Getting Started Guide. | |
| [970] | Protection and Control IED Manager PCM600 Getting Started Guide. | |
| [971] | Protection and Control IED Manager PCM600 Product Guide. | |
| [972] | Protection and Control IED Manager PCM600 Product Guide. | |
| [973] | Protection and Control System Upgrade Based on IEC- 61850 and PRP. | |
| [974] | PROTECTION AND CONTROL WITH IEC 61850. | |
| [975] | Protection and Substation Control. | |
| [976] | Protection Application. | |
| [977] | PROTECTION AUDIT OF GENERATION AND TRANSMISSION SYSTEM. | |
| [978] | protection course. | |
| [979] | Protection guide. | |
| [980] | protection guide. | |
| [981] | Protection lec 1 to lec 10. | |
| [982] | Protection lec 11 to lec 16. | |
| [983] | Protection lec 22 to lec 30. | |
| [984] | Protection lec 31 to lec 37. | |
| [985] | Protection of a Motor up to 200 kW. | |
| [986] | Protection of Electrical Networks. | |
| [987] | protection of industrial power systems. | |
| [988] | Protection of Medium and Low Voltage distribution systems. | |
| [989] | Protection of Medium and Low Voltage distribution systems. | |
| [990] | Protection of MV/LV substation transformers. | |
| [991] | Protection of Small to Large Motors – An Application Overview. | |
| [992] | Protection of Synchronous Generators. | |
| [993] | Protection Relay REX 521. | |
| [994] | Protection Relay REX 521. | |
| [995] | Protection Relay REX 521. | |
| [996] | PROTECTION scheme for bus bar/feeder. | |
| [997] | Protection Systems. | |
| [998] | Protection, Monitoring, and Control RE_ 5__. | |
| [999] | Protective Relay Coordination. | |
| [1000] | Protective Relay Settings. | |
| [1001] | Protective Relay Settings & Calculations Seminar. | |
| [1002] | Protective Relaying Principles And Applications Third Edition. | |
| [1003] | Protective Relays Numerical Protective Relays. | |
| [1004] | Protocol Implementation Conformance Statement (PICS) for IEC 61850 for the SEL Real-Time Automation Controllers. | |
| [1005] | PRP and HSR for High Availability Networks in Power Utility Automation: A Method for Redundant Frames Discarding. | |
| [1006] | PRP and HSR Version 1 (IEC 62439-3 Ed.2), Improvements and a Prototype Implementation. | |
| [1007] | PTL Consolidated knowledge The Protection Testing Library in practical use – an interview with a key user. | |
| [1008] | Raspberry Microcontroller. | |
| [1009] | RE_5_ _ Customer-Defined Event (EVENT230). | |
| [1010] | Real-Time Hardware-in-the-Loop Validation for WAMPAC: Power System Protection and Communication. | |
| [1011] | Real-Time Power System Control Using Synchrophasors. | |
| [1012] | The Real-Time Publisher/Subscriber Communication Model for Distributed Substation Systems. | |
| [1013] | REAL-TIME SYNCHROPHASOR APPLICATIONS IN POWER SYSTEM CONTROL AND PROTECTION. | |
| [1014] | Real-World Synchrophasor Solutions. | |
| [1015] | Reason RT411 Technical Manual Time Signal Distributor. | |
| [1016] | REB500/REB500sys Numerical Station Protection System Busbar Protection with integrated Breaker Failure, Line and Transformer Protection Operating Instructions. | |
| [1017] | Reducing Outages in Distribution by Testing Recloser Controls. | |
| [1018] | Redundancy in Substation LANs with the Rapid Spanning Tree Protocol (IEEE 802.1w). | |
| [1019] | regulator user manual. | |
| [1020] | REJ 521 Earth-Fault Relay. | |
| [1021] | REJ 523 Overcurrent Relay. | |
| [1022] | REJ 525 Combined Overcurrent and Earth-Fault Relay. | |
| [1023] | REJ 527 Directional or Non-Directional Earth-Fault Relay. | |
| [1024] | relay Ansi code7. | |
| [1025] | Relay Coordination Problem & Countermeasure. | |
| [1026] | Relay Protection. | |
| [1027] | Relay Protection 2. | |
| [1028] | Relay Selection Guide. | |
| [1029] | RELAY SETTING SAMPLE CALCULATION FOR DISTANCE RELAYING. | |
| [1030] | Relay setting study. | |
| [1031] | Relays for Various Protection Applications / 7VK61. | |
| [1032] | Reliable Calibration The CMC 256plus as a universal calibrator. | |
| [1033] | Reliable data networks for electric power systems. | |
| [1034] | Reliable data networks for electric power systems Robust industrial communication – from generation to distribution. | |
| [1035] | Relion® protection and control For a generation, transmission, and sub‑transmission applications. | |
| [1036] | Relion® protection and control Generation, transmission, and sub-transmission. | |
| [1037] | REM 54 Machine Terminal manual. | |
| [1038] | REPORT ON FAILURE OF 220 KV AND ABOVE VOLTAGE CLASS SUBSTATION EQUIPMENT. | |
| [1039] | REPORT ON FAILURE OF 220 KV AND ABOVE VOLTAGE CLASS SUBSTATION EQUIPMENT. | |
| [1040] | REQUIRED CLEARANCE FOR OPENING DOOR OF CONTROL PANEL. | |
| [1041] | Requirements for Ethernet Networks in Substation Automation. | |
| [1042] | Requirements for Voltage transformer for power quality monitoring and metering. | |
| [1043] | Residual Compensation Factors: K0 and RE/RL, XE/XL. | |
| [1044] | Restricted Earth-Fault Protection in REF 542plus. | |
| [1045] | RET Academy for International Journals of Multidisciplinary Research (RAIJMR) Dual Slope Differential Relay as an Effective Technique for Differential Protection of Y-Y Connected Power Transformer. | |
| [1046] | Reydisp Manager Relay configuration software. | |
| [1047] | Reyrolle 7SR18 Solkor. | |
| [1048] | RIO. | |
| [1049] | ROLE OF PHASOR MEASUREMENT UNIT (PMU) IN WIDE-AREA MONITORING AND CONTROL. | |
| [1050] | RP100. | |
| [1051] | RPV311 Digital fault recorder with fault location and PMU. | |
| [1052] | RT 430. | |
| [1053] | RTDS Applications Overview. | |
| [1054] | RTDS Simulation and Testing. | |
| [1055] | Rugged communications for intelligent transportation systems Complete connectivity solutions for today and tomorrow. | |
| [1056] | Rugged communications for railways Complete connectivity solutions for today and tomorrow. | |
| [1057] | RUGGEDCOM CROSSBOW. | |
| [1058] | RUGGEDCOM Multi-Service Platform Modular Managed Layer 2 / 3 Ethernet Switches, Routers, and Security Appliances. | |
| [1059] | RUGGEDCOM Network Infrastructure and Professional Services help rural electric utility manage seasonal loads to improve service, costs, and safety. | |
| [1060] | RUGGEDCOM Products at a Glance. | |
| [1061] | RUGGEDCOM RSG2488. | |
| [1062] | RUGGEDCOM RX1400. | |
| [1063] | RUGGEDCOM Software. | |
| [1064] | RUGGEDCOM WIN. | |
| [1065] | RX1500. | |
| [1066] | RX1501. | |
| [1067] | RX1510. | |
| [1068] | RX1512. | |
| [1069] | RXLK 2H and RALK Overexcitation relay and protection assemblies. | |
| [1070] | S120 Drive full Commissioning. | |
| [1071] | S&C IntelliRupter® testing package. | |
| [1072] | SA Hand Book. | |
| [1073] | Safety earthing. | |
| [1074] | SAM600 process bus. | |
| [1075] | The SAM600 process bus IO system integrates conventional instrument transformers into modern, IEC 61850-9-2
process bus substation automation, protection, and control systems. | |
| [1076] | Sampled Values. | |
| [1077] | SAS Application pictures. | |
| [1078] | SAS Tech specification. | |
| [1079] | SCADA and IP. | |
| [1080] | SCADA System Solutions. | |
| [1081] | SCADA Systems: Challenges for Forensic Investigators. | |
| [1082] | Schematic Diagrams of Incoming A&B, Buscoupler, Measurement & Riser Feeders (Power & Controls)(3S31-6KV). | |
| [1083] | Scheme Testing Tools. | |
| [1084] | Seamless communication. | |
| [1085] | Seamless redundancy. | |
| [1086] | Secure Remote Backup Protection of Transmission Lines Using Synchrophasors. | |
| [1087] | SEL-411L Relay Protection and Automation System. | |
| [1088] | SEL-421 Relay Protection and Automation System Instruction Manual. | |
| [1089] | SEL-451 Relay Protection, Automation, and Control System Instruction Manual. | |
| [1090] | SEL-487V Relay Capacitor Bank Protection, Automation, and Control. | |
| [1091] | SEL 451 +D184 | |
| [1092] | SEL Family of IEEE C37.94 Compatible Products. | |
| [1093] | Selecting, Designing, and Installing Modern Data Networks in Electrical Substations. | |
| [1094] | Selection Guide for SIPROTEC and Reyrolle Edition 4. | |
| [1095] | Selective coordination of power systems. | |
| [1096] | SEL-T400L Time-Domain Line Protection. | |
| [1097] | SENSITIVE TURN-TO-TURN FAULT PROTECTION FOR POWER TRANSFORMERS. | |
| [1098] | Sepam Ethernet Guide. | |
| [1099] | Sepam IEC 61850 communication. | |
| [1100] | Sepam series 10 presentation_EN_V7. | |
| [1101] | Sepam series 40. | |
| [1102] | Sepam series 40 Merlin Gerin. | |
| [1103] | Sepam series 80 Protection, metering, and control functions User’s manual 06/2008. | |
| [1104] | A setting guide for the distance protection function. | |
| [1105] | Short Circuit Calculations. | |
| [1106] | short circuit earth faults: calculation for protection, application judging fault consequences concerning the safety of people. | |
| [1107] | Short circuit temperature limits of electric cables with rated voltage of 1 kV. | |
| [1108] | Short-circuit currents – Calculation of effects – Part 2: Examples of calculation. | |
| [1109] | Short-circuit currents – Calculation of effects – Part 2: Examples of calculation. | |
| [1110] | SICAM – Power Quality and Measurements. | |
| [1111] | SICAM – Substation Automation. | |
| [1112] | SICAM – Substation Automation and RTUs Product Catalog · Edition 2.0. | |
| [1113] | SICAM Fault Collector Gateway V01.00 Manual E50417-. | |
| [1114] | SICAM Fault Sensor Indicator (FSI) The Guardian for your Overhead Line Networks. | |
| [1115] | SICAM FCG Device 6MD2340. | |
| [1116] | SICAM FRTU 6MD25 Version 2.0 The Intelligent Electronic Device for SMART Grids. | |
| [1117] | SICAM MMU Measurement and Monitoring Unit Catalog SR 10.4.2 · Edition 1. | |
| [1118] | SICAM PAS PQS Advanced Substation Automation and Power Quality System. | |
| [1119] | SICAM RTUs SICAM AK 3 System Description. | |
| [1120] | siemens academic. | |
| [1121] | Siemens Automation. | |
| [1122] | SIEMENS Automation System Part 1 of 3. | |
| [1123] | SIEMENS Automation System Part 2 of 3. | |
| [1124] | SIEMENS Distribution Feeder Automation (SDFA) Developed in the USA. | |
| [1125] | Siemens vacuum recloser 3AD. | |
| [1126] | SIMATIC ET 200 For distributed automation solutions Brochure · April 2012. | |
| [1127] | The SIMATIC PCS 7 Process Control System. | |
| [1128] | Simulation and testing of the over-current protection system based on IEC 61850 Process-Buses and dynamic estimator. | |
| [1129] | Simulation-Based Testing and Measurements – Experiences. | |
| [1130] | Simulation of Parallel Redundant WLAN with OPNET. | |
| [1131] | SINEAX CAM Parameterization of IEC61850 bus card. | |
| [1132] | Single Line Diagram of Substations. | |
| [1133] | SIPROTEC 4, SIPROTEC easy, SIPROTEC 600 Series, Communication, Accessories. | |
| [1134] | SIPROTEC 5 – Devices Protection, Automation, and Monitoring. | |
| [1135] | SIPROTEC 5 – Devices Protection, Automation, and Monitoring Catalog SIPROTEC 5.01 · Edition 3. | |
| [1136] | SIPROTEC 5 – DevicesProtection, Automation, and Monitoring Catalog SIPROTEC 5.01 · Edition 3. | |
| [1137] | SIPROTEC 5 Communication protocol IEC 60870-5-103. | |
| [1138] | SIPROTEC 5 Communication protocol IEC 60870-5-103. | |
| [1139] | SIPROTEC 5 Communication Protocol IEC 60870-5-104. | |
| [1140] | SIPROTEC 5 Communication protocol IEC 61850. | |
| [1141] | SIPROTEC 5 Distance Protection, Line Differential Protection, and Breaker Management for 1-Pole and 3-Pole Tripping 7SA87, 7SD87, 7SL87, 7VK87. | |
| [1142] | SIPROTEC 5 Distance Protection, Line Differential Protection, and Breaker Management for 1-Pole and 3-Pole Tripping
7SA87, 7SD87, 7SL87, 7VK87. | |
| [1143] | SIPROTEC 5 Distance Protection, Line Differential Protection, and Breaker Management for 1-Pole and 3-Pole Tripping
7SA87, 7SD87, 7SL87, 7VK87. | |
| [1144] | SIPROTEC 5 Engineering Guide DIGSI 5. | |
| [1145] | SIPROTEC 5 Engineering Guide DIGSI 5. | |
| [1146] | SIPROTEC 5 Fault Recorder 7KE85 V07.00 Manual. | |
| [1147] | SIPROTEC 5 Generator Protection 7UM85 V7.00 and higher Manual C53000-. | |
| [1148] | SIPROTEC 5 Hardware Description. | |
| [1149] | SIPROTEC 5 High-Voltage Bay Controller 6MD85/86. | |
| [1150] | SIPROTEC 5 Low-Impedance Busbar Protection 7SS85 V7.00 and higher. | |
| [1151] | SIPROTEC 5 Modbus. | |
| [1152] | SIPROTEC 5 Motor Protection 7SK82, 7SK85. | |
| [1153] | SIPROTEC 5 Motor Protection 7SK82/85 V7.00 and higher Manual. | |
| [1154] | SIPROTEC 5 Operation. | |
| [1155] | SIPROTEC 5 Overcurrent Protection 7SJ82/7SJ85. | |
| [1156] | SIPROTEC 5 Overcurrent Protection 7SJ82/7SJ85 V7.00 and higher Manual. | |
| [1157] | SIPROTEC 5 Process Bus. | |
| [1158] | SIPROTEC 5 Transformer Differential Protection 7UT82, 7UT85, 7UT86, 7UT87. | |
| [1159] | SIPROTEC 5 Transformer Differential Protection 7UT82, 7UT85, 7UT86, 7UT87. | |
| [1160] | SIPROTEC 5 Transformer Differential Protection 7UT82, 7UT85, 7UT86, 7UT87 V7.00, and higher Manual. | |
| [1161] | SIPROTEC 5 Transformer Differential Protection 7UT82, 7UT85, 7UT86, 7UT87 V7.00, and higher Manual C53000-. | |
| [1162] | SIPROTEC 5Communication protocol DNP3. | |
| [1163] | SIPROTEC 5Overcurrent Protection 7SJ82/7SJ85. | |
| [1164] | SIPROTEC 7SJ66 Overcurrent Protection Chapter for the Catalog SIP · Edition No. 8. | |
| [1165] | SIPROTEC 7SJ601 Numerical Overcurrent Relay. | |
| [1166] | Siprotec 7ST61 / 7ST63 Numerical overhead contact line protection for AC traction power supply. | |
| [1167] | SIPROTEC Compact 7SD80, 7SJ80, 7SJ81, 7SK80, 7SK81, 7RW80, 7SC80. | |
| [1168] | SIPROTEC Distance Protection 7SA6 V4.3 Manual. | |
| [1169] | SIPROTEC Fault Record Analysis SIGRA 4 V4.50 Manual. | |
| [1170] | SIPROTEC Feeder Protection 7SC80 V4.20 Manual. | |
| [1171] | SIPROTEC Line Differential Protection 7SD80 V4.6 Manual. | |
| [1172] | SIPROTEC Motor Protection 7SK80 V4.7 Manual. | |
| [1173] | SIPROTEC Multifunction High-Speed Busbar Transfer Device 7VU683 V4.70 User Manual. | |
| [1174] | SIPROTEC Numerical Protection Relays. | |
| [1175] | SIPROTEC Numerical Protection Relays – Protection Systems Catalog SIP · 2004. | |
| [1176] | SIPROTEC Overcurrent Time Protection 7SJ80 V4.7 Manual. | |
| [1177] | SIPROTEC Voltage and Frequency Protection 7RW80 V4.6 Manual. | |
| [1178] | SIPROTECMerging Unit 6MU805 V4.01 Manual. | |
| [1179] | SIVACON 8PS Busbar Trunking Systems. | |
| [1180] | Smart Grid – Technology and Applications by J. Ekanayake, N. Jenkins, K. Liyanage, J. Wu (2012). | |
| [1181] | SMART GRID COMMUNICATIONS AND MEASUREMENT TECHNOLOGY. | |
| [1182] | SMART GRID TECHNOLOGY AND APPLICATIONS. | |
| [1183] | Smart Grid testing. | |
| [1184] | smart grids. | |
| [1185] | The Smart Substatiion usiing IIEC 61850 Ediitiion 2. | |
| [1186] | Smart Switchgear & Cloud Service Remote, but close. | |
| [1187] | Solutions for Digital Substation. | |
| [1188] | SOLVING ELECTRICAL SUBSTATION TIMING PROBLEMS. | |
| [1189] | SPAF 140 C Frequency Relay User´s manual and Technical description. | |
| [1190] | SPAF 340 C Frequency Relay User´s manual and Technical description. | |
| [1191] | SPAU 341 C Voltage regulator User´s manual and Technical description. | |
| [1192] | Speed of Line Protection – Can We Break Free of Phasor Limitations?. | |
| [1193] | Stand Alone Merging Unit User Guide MGU010000. | |
| [1194] | Standard Function Blocks for Flexible IED in IEC 61850-Based Substation Automation. | |
| [1195] | Standard-Compliant Components for Photovoltaic Systems. | |
| [1196] | Standardization in Smart Grids Introduction to IT-Related Methodologies, Architectures and Standards. | |
| [1197] | Standardized Factory Acceptance Tests with OMICRON Control Center. | |
| [1198] | Standardized IEC 61850 Product Acceptance Procedure for Intelligent Electronic Devices: A Malaysian Power Utility’s Experience. | |
| [1199] | Static Compensators (STATCOMs) in Power Systems. | |
| [1200] | Substation Automation / 6MD61. | |
| [1201] | Substation Automation / 6MD63. | |
| [1202] | Substation Automation based on IEC 61850 with new process-close Technologies. | |
| [1203] | Substation Automation General Training Course. | |
| [1204] | substation automation IED integration and availability of information. | |
| [1205] | Substation Automation Solutions SAS 600 Series. | |
| [1206] | Substation Automation Systems. | |
| [1207] | Substation Automation Systems. | |
| [1208] | Substation Automation Systems. | |
| [1209] | Substation Automation Systems. | |
| [1210] | Substation Automation Systems Smart, IEC 61850- compliant solutions. | |
| [1211] | Substation Communication Networks Architecture. | |
| [1212] | Substation Communications. | |
| [1213] | Substation Controls Using Relays. | |
| [1214] | SUBSTATION DESIGN / APPLICATION GUIDE. | |
| [1215] | Substation High Voltage component. | |
| [1216] | SUBSTATION HIGH VOLTAGE COMPONENTS. | |
| [1217] | Substation Integration and Automation. | |
| [1218] | Substation Network Sentinel. | |
| [1219] | Substation protection & control. | |
| [1220] | A Survey of Communication Network Paradigms for Substation Automation. | |
| [1221] | A Survey of Ethernet LAN Security. | |
| [1222] | SWITCHES Modular Managed Ethernet Switch. | |
| [1223] | SWITCHGEAR OPTIMIZATION USING IEC 61850-9-2. | |
| [1224] | Switchgear Optimization Using IEC 61850-9-2 and Non-Conventional Measurements. | |
| [1225] | switchgear Type 8DJ10 up to 24 kV, Gas-insulated. | |
| [1226] | Switchgear Type 8DJH 36 for Secondary Distribution Systems up to 36 kV, Gas-Insulated. | |
| [1227] | Switchgear Type SIMOSEC up to 24 kV, Air-insulated, Extendable Medium-Voltage Switchgear. | |
| [1228] | Switchgear Type SIMOSEC, up to 24 kV, Air-Insulated, Extendable. | |
| [1229] | SYMAP®- Power Protection – Monitoring – Diesel Control – Power Management Appendix A3 Graphic. | |
| [1230] | SYMAP®- Power Protection – Monitoring – Diesel Control – Power Management Service Manual. | |
| [1231] | SYMAP®- Power Protection – Monitoring – Diesel Control – Power Management User’s Manual. | |
| [1232] | Symmetrical Components. | |
| [1233] | Symmetrical Components for Power Systems Engineering. | |
| [1234] | A synchronized generic substation event tripping circuit monitor for electric substation applications. | |
| [1235] | Synchronized Phasor Measurements and Their Applications. | |
| [1236] | Synchrophasor Measurements Under the IEEE Standard C37.118.1-2011 With Amendment C37.118.1a. | |
| [1237] | Synchrophasor Processor Detects Out-of-Step Conditions. | |
| [1238] | Synchrophasor Standards Development – IEEE C37.118 & IEC 61850. | |
| [1239] | Synchrophasor-Based Power System Protection and Control Applications. | |
| [1240] | Synchrophasors Applications for Power System Protection and Control. | |
| [1241] | SYNCHROTACT® 5 Operating Instructions SYN 5201 SYN 5202. | |
| [1242] | System 800xA IEC 61850 Connect Configuration. | |
| [1243] | System 800xA IEC 61850 Engineering Workflow. | |
| [1244] | System 800xA IEC 61850 Operation Library for Substation Equipment. | |
| [1245] | System Engineer Configures IEC 61850 Gateway to DNP3 Substation. | |
| [1246] | System-Level Tests of Transformer Differential Protection Using an IEC 61850 Process Bus. | |
| [1247] | T35 Transformer Management Relay UR Series Instruction Manual. | |
| [1248] | T35 Transformer Protection System UR Series Instruction Manual. | |
| [1249] | T60 Transformer Management Relay UR Series Instruction Manual. | |
| [1250] | T1000.Download | |
| [1251] | TCP/IP Protocol Suite. | |
| [1252] | Tech Spec 220kV_&_33ikV Circuit Breaker. | |
| [1253] | Technical Guide MiCOM P125/P126/P127. | |
| [1254] | Technical Guide Micom p220. | |
| [1255] | Technical Guide MiCOM P441 and P442 Distance Protection Relays. | |
| [1256] | Technical Guide MiCOM P921-P922-P923. | |
| [1257] | Technical Guide MiCOM P941, P942, P943 Frequency Relays. | |
| [1258] | Technical Guide TG8612B MiCOM P141, P142, P143 Feeder Management Relays. | |
| [1259] | Technical Guide TG8613B MiCOM P541, P542, P543, P544 Current Differential Relays. | |
| [1260] | Technical Guide TG8617A MiCOM P341 Interconnection Protection Relay. | |
| [1261] | Technical Guide Types MiCOM P342, P343 Generator Protection Relays. | |
| [1262] | Technical Requirements for DER Integration Architectures. | |
| [1263] | TECHNICAL SPECIFICATION 33kV CONTROL & RELAY PANELS. | |
| [1264] | Test method of End to End Test for protection relay and SIPS. | |
| [1265] | Test Universe Advanced Protection. | |
| [1266] | Test Universe Data Export Reference Documentation. | |
| [1267] | Test Universe Data Export Sample: Import into an Access 2003 Database. | |
| [1268] | Test Universe Data Export Sample: Import into Excel 2003. | |
| [1269] | Test Universe Data Export Sample:ReportingwithCrystalReportinVisualStudio2005. | |
| [1270] | Test Universe Measurements. | |
| [1271] | Test Universe NetSim. | |
| [1272] | Testing & Commissioning of ARC Detection. | |
| [1273] | Testing and Validation of Out-of-Step in Interconnected Areas. | |
| [1274] | Testing differential relay. | |
| [1275] | Testing of Ground Fault Relay Response during the Energization of Megawatt Range Electric Boilers in Thermal Power Plants. | |
| [1276] | Testing of Parameters of Sampled Values using a CMC 256 Relay Testing Set. | |
| [1277] | Testing of Protection IEDs and Automation Systems with IEC 61850 in High Traffic Mode. | |
| [1278] | Testing of the Saturation Detector Algorithm in FRTU. | |
| [1279] | Testing solutions of a special kind Integrated expert knowledge in the Protection Testing Library. | |
| [1280] | Testing the Interoperability of IEC 61850 Intelligent Electronic Devices: A Tenaga Nasional Berhad Experience. | |
| [1281] | TeSys T LTM R Modbus Motor Management Controller User Manual. | |
| [1282] | TI Designs Sensor Inputs AFE for Merging Unit and Protection Relays. | |
| [1283] | tiastar TM Motor Control Center Catalog and Application Guide. | |
| [1284] | Time selective protection. | |
| [1285] | Time Signal Distributor. | |
| [1286] | Time Synchronization (IEEE 1588) and Seamless Communication Redundancy (IEC 62439-3) Techniques for Smart Grid Substations. | |
| [1287] | Time Synchronized Low-Voltage Measurements for Smart Grids. | |
| [1288] | Time-synchronous recording with EnerLyzer. | |
| [1289] | Time-synchronous recording with EnerLyzer. | |
| [1290] | Toward Effective SA. | |
| [1291] | Towards Implementation of IEC 61850 GOOSE Messaging in Event-Driven IEC 61499 Environment. | |
| [1292] | Traffic Generation of IEC 61850 Sampled Values. | |
| [1293] | TRAINING OVERVIEW 2015 OPEN ENROLMENT COURSES. | |
| [1294] | Trans protection. | |
| [1295] | Transformer Differential Protection / 7UT6 SIPROTEC 4 7UT6 differential protection relay for transformers, generators, motors, and busbars. | |
| [1296] | TRANSFORMER DIFFERENTIAL PROTECTION IMPROVED BY IMPLEMENTATION OF NEGATIVE-SEQUENCE CURRENTS. | |
| [1297] | TRANSFORMER PROTECTION. | |
| [1298] | Transformer Protection. | |
| [1299] | TRANSFORMER PROTECTION. | |
| [1300] | TRANSFORMER PROTECTION. | |
| [1301] | Transformer Protection Open Lecture. | |
| [1302] | Transformer protection RET670 Application manual. | |
| [1303] | Transformer protection RET670 Customized Product Guide. | |
| [1304] | Transformer protection RET670 Customized Product Guide. | |
| [1305] | Transformer protection RET670 Relion® 670 series Ver. 1.2. | |
| [1306] | Transformer protection RET670 Technical reference manual. | |
| [1307] | Transformer protection RET670/650 Relion® 670 and 650 series. | |
| [1308] | Transformers. | |
| [1309] | Transforming Critical Communications Networks for Substation Automation Communications network infrastructure requirements and architectures. | |
| [1310] | Transient Behaviour of Conventional Current Transformers used as Primary Transducers and Input Elements in Protection IEDs and Stand Alone Merging Units. | |
| [1311] | Transient Behaviour of Conventional Current Transformers used as Primary Transducers and Input Elements in Protection IEDs and Stand Alone Merging Units. | |
| [1312] | Transmission and Distribution Electrical Engineering. | |
| [1313] | TRANSMISSION LINE MODELING FOR REAL-TIME SIMULATIONS. | |
| [1314] | Transmission Line Protection Using Digital Technology. | |
| [1315] | Transmission Lines. | |
| [1316] | Transmission Relay Loadability. | |
| [1317] | TransView. | |
| [1318] | Trip Circuit Supervision Relay (7PJ13) Better protection and more efficiency for your power system. | |
| [1319] | Tutorial on Distance and Over Current Protection. | |
| [1320] | Two Improvements Related to Overcurrent Functions for Bus Protection in Distribution Systems. | |
| [1321] | Type KAVS 100 Synchronism Check Relay Service Manual R8506F. | |
| [1322] | Typical diagram(Type 36A). | |
| [1323] | Typical diagram(Type 37A). | |
| [1324] | Typical diagram(Type 37B). | |
| [1325] | Typical diagram(Type 37C). | |
| [1326] | Typical diagram(Type 38). | |
| [1327] | Typical Protection Schemes. | |
| [1328] | Uncertainty in Transmission Line Parameters: Estimation and Impact on Line Current Differential Protection. | |
| [1329] | Underimpedance protection: ANSI 21B. | |
| [1330] | Understanding microprocessor-based technology applied to relaying. | |
| [1331] | Use of Precision Time Protocol to Synchronize Sampled-Value Process Buses. | |
| [1332] | User Experiences Implementing IEC61850 in Intelligent Electronic Devices. | |
| [1333] | A user-friendly implementation of IEC 61850 in a new generation of protection and control devices. | |
| [1334] | Using EtherNet/IP with IEC 61499 Communication Function Blocks. | |
| [1335] | Using IEC 61850 Analogue GOOSE Messages for OLTC Control of Parallel Transformers. | |
| [1336] | Using OPNET to Model and Evaluate the MU Performance Based on IEC 61850-9-2LE. | |
| [1337] | Utilizing IEC 61850, Ethernet, and IP Standards for Integrated Substation Communications. | |
| [1338] | VAMP RELAYS IEC 61850 interface Configuration instructions. | |
| [1339] | Video channel. | |
| [1340] | Virtual Power Plant for Grid Services using IEC 61850. | |
| [1341] | Voltage regulator TAPCON® 230 basic Operating Instructions 2117246/02. | |
| [1342] | Voltage regulator TAPCON® 260 Operating Instructions 1801003/05 Protocol description for IEC 61850. | |
| [1343] | Voltage Regulator TAPCON® Operating Instructions. | |
| [1344] | Voltage Stability and Distance Protection Zone3. | |
| [1345] | VSE 006 IEC 61850 interface module. | |
| [1346] | VSE 006 IEC 61850 interface module Configuration instructions. | |
| [1347] | WAVESysTM – An Innovative Wide Area Control Approach for Extending Power Utilities Generation Hosting Capacity. | |
| [1348] | A Web-Based Remote Access Laboratory Using SCADA. | |
| [1349] | What Is IEC 61850?. | |
| [1350] | What Protection Engineers Need to Know About Networking. | |
| [1351] | WHEN EXISTING RECOMMENDATIONS FOR PST PROTECTION CAN LET YOU DOWN. | |
| [1352] | White Paper on Standards for DER Communications Using IEC 61850. | |
| [1353] | WHY WE SHOULD MEASURE LINE IMPEDANCE?. | |
| [1354] | Wide area voltage protection. | |
| [1355] | Wide-Area Ethernet Network Configuration for System Protection Messaging. | |
| [1356] | Wide-Area Ethernet Network Configuration for System Protection Messaging. | |
| [1357] | Wide-Area Protection and Power System Utilization. | |
| [1358] | XRIO Automation Manual. | |
| [1359] | XRIO Filter Manual. | |
| [1360] | XRIO Reference Manual. | |
| [1361] | XRIO Reference Manual. | |
| [1362] | ZIV Integrated Protection, Control & Metering IED Instructions Manual. |
The most complete library for a protection engineer. Leave a comment here
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Save your time by using templates of Protection and Automation in your electrical CAD
Electrical CAD drawings and blocks for download in DWG or pdf formats for use with AutoCAD and other 2D and 3D design software.
A drawing template file is used to provide consistency in the drawings that you create by providing standard styles and settings.
To get more information and download the templates, contact us
Electrical CAD Drawings templates, Electrical Protection CAD Drawings templates.
The figures below show you the ABB 670 Relay series’s connection diagram with IEC symbols.
Relion 670, ABB Relion 670, ABB 670 Relay
ABB PCM 600 Video training: https://elec-engg.com/abb-pcm-600-training/
The Starter software helps you in commissioning, parameterizing, and troubleshooting the dive component where you can import all relevant data to the equipment. The software provides a graphical configuration interface for simple handling and generates the reports automatically.
This file contains the screenshot of S120 Drive full Commissioning with starter software.
- Installing DIGSI 4
- Managing Projects
- Working with the Devices
- Optimizing Parameterization
Sample page of the file:
The first step is to create a new project. The DIGSI Manager has been started, a project dialog box has not yet been opened.
Click File- New of the menu bar, enter a new project name and confirm with OK.
The project dialog box is displayed.
Names and symbols of all project containers are displayed in a hierarchical tree structure. To put it less complicated, we could say that containers are displayed. This pane is called a tree view. An opened folder is the first symbol to be displayed in this pane. The opened folder is designated as project 1 and represents the top level, the project itself.
The right pane of the window shows a folder-type object. If the DIGSI 4 Remote program is installed, a phone book type object and modem type object each are displayed in addition. Otherwise, this pane of the window continues to remain empty. This page serves to display further names of symbols of objects, which are contained in one of the selected containers of the tree view. To put it less complicated, we could say that this pane shows objects. Since the right pane of the window is represented as a list, this structure is called a list view.
Up to four objects are first automatically created within a new project of the tree view.
– Project (cannot be inserted manually)
– Folder (to structure a project)
– Phone Book (station addresses for a modem connection)
– Modem (for the communication SIPROTEC between your computer and the SIPROTEC 4 device
modem connection for the storage of modem profiles).
Phone Book and modem will be created automatically if the DIGSI 4 Remote component has been loaded.
The SIPROTEC 4 device object type represents a real SIPROTEC 4 device with all its setting values and process data.
The V3/V2 device object type serves to create shortcuts linked to the V3/V2 devices within the project structure. These device data are processed with DIGSI-V3.x.
The SIPOROTEC 4 version object type is created to document different parameter settings groups of a SIPROTEC 4 device. The device address (VD number) of the corresponding versions is identical to that of the original device.
The left window pane contains the names and symbols of all project containers in a hierarchical tree structure.
The right window pane displays the objects of the selected folders. The structure is designated as a list view.
Your first step to creating a system-specific project structure is to insert folder-type blank containers in the corresponding levels.
Click a folder object to insert a subordinate folder via the menu command ® Paste. A maximum of 9 levels is the permissible hierarchy depth.
Several objects can be juxtaposed in parallel.
The names of the folders can be renamed to easily adjust to the requirements of your operation.
As a first step, you create a new project. The DIGSI 4 Manager is started, no project window is open.
- Click File ® New in the menu bar.
- In the New dialog box, enter Project 1 as a name for the new project.
Don‘t modify any other settings. - Click OK.
The project window is now displayed in the working range. Put it to full size. - An object of the type Hierarchical level is inserted automatically upon creating a new project.
- Click this object and then click the selected name. Enter Region Nord as a new name.
- Right-click an existing hierarchical level and insert the lower-level hierarchical level via the context menu Insert new object ® Hierarchical level. Enter the new name.
- Click a hierarchical level, e.g. Feeder 1, and open the device catalog via the context menu.
- Select the device and draw it on the hierarchical level.
The Device Catalog shows all SIPROTEC 4 devices available (installed) in the DIGSI 4 Manager.
The device catalog is an independent item. When you open the catalog, a button is created in the taskbar by Windows. The device catalog can remain open while working with the DIGSI 4 Manager to install all required SIPROTEC 4 devices.
Select a folder type object and click View ® Device Catalog to open the Device Catalog window.
The device catalog has a structure. Clicking a plus sign or double-clicking a folder icon will open the subordinate level.
For example, if you double-click 7SJ (time overcurrent protection), all installed SIPROTEC 4 devices with the device type names and the variant numbers will be displayed.
Short technical information is displayed on the lower catalog border for each device selected.
Note: Devices cannot be placed directly underneath the project folder!
The MLFB tab serves to determine the order number of the selected SIPROTEC 4 device in DIGSI 4. The order number is the code for the type and variant of the SIPROTEC 4 device. The order number is called the MLFB number.
Order number determination in DIGSI 4 affects all further parameterization options. Identical MLFB numbers are necessary for the communication between the DIGSI 4 device operation and the connected SIPROTEC 4 device. This is checked when setting up the connection.
The MLFB tab contains several drop-down list boxes. The drop-down list boxes related to the selected SIPROTEC 4 device are activated, only. These drop-down list boxes serve to select the order numbers to define the SIPROTEC 4 design and type in DIGSI 4.
As a first step, create a new project. The DIGSI 4 Manager is started, no project window is open.
Click File ® New in the menu bar.
- In the New dialog box, enter Project 1 as a new project name.
Don‘t change any other settings. - Click OK.
The project window is now displayed in the working range. Put it to full size.
When creating a new project, an object of the type Hierarchical level is inserted automatically.
- Click this object and then click the selected name. Enter Region North as a new name.
- Right-click on an existing hierarchical level and insert a lower hierarchical level vie the context menu Insert new object ® Hierarchical level. Enter the new name.
- Click a hierarchical level, e.g. Feeder 1, and open the device catalog via the context menu.
- Select the device and draw it on the hierarchical level.
- As a first step, create a new project. The DIGSI 4 Manager is started, no project window is open. Click File ® New in the menu bar.
- In the New dialog box, enter Project 1 as a new project name.
Don‘t change any other settings. - Click OK.
The project window is now displayed in the working range. Put it to full size.
When creating a new project, an object of the type Hierarchical level is inserted automatically.
- Click this object and then click the selected name. Enter Region North as a new name.
- Right-click on an existing hierarchical level and insert a lower hierarchical level vie the context menu Insert new object ® Hierarchical level. Enter the new name.
- Click a hierarchical level, e.g. Feeder 1, and open the device catalog via the context menu.
- Select the device and draw it on the hierarchical level.
- In the New dialog box, enter Project 1 as a new project name.
Properties like object name, comment, or date of creation, have been assigned to all objects (General tab).
Some properties only refer to certain objects, for ex. the MLFB number for the SIPROTEC 4 devices or the device communication settings.
The values of the majority of the properties can be changed.
Select the object and click the View ® Details menu item to display the object properties. You can also open the Object Properties dialog box via the context menu or via the menu item Edit ® Object Properties.
If the property values are grayed, they cannot be changed. Depending on the entries you made in other text boxes, such text boxes may be activated. Property values in white/empty text boxes can be edited.
Sensor technologies have made an enormous impact on modern-day industries. There are many sensors available in the market and a lot of researches is currently undergoing the development of new, smart, efficient, and high-performance sensors. In the following section, the classification of sensors is discussed.
Download IoT and smart instruments package with only 50 RS
DIGSI 5 is the configuration and operation tool for all SIPROTEC 5 Protection relays. with DIGSI 5, you can create system topologies, configure hardware and communication networks, set function settings, and perform many further tasks.
You perform all configuration tasks offline from your PC without the need for a SIPROTEC 5 device. You transmit all data online to the SIPROTEC 5 device later on – for example, directly through a communication network. For communication, DIGSI 5 and SIPROTEC 5 are based on current standards such as IEC 61850 and proven technologies such as Ethernet.
There are 3 different variants of DIGSI 5:
- For simple applications using individual SIPROTEC 5 devices, select DIGSI 5 Compact. With this variant, you deal with most standard tasks such as setting parameters or reading out process data. In addition, this variant also includes the CFC editor and the DIGSI 5 test suite for testing SIPROTEC 5 devices and functions. CFC offline and online debugging is supported to verify the created logic before downloading it to the device.
- The DIGSI 5 Standard variant has an extended scope of functions. This variant includes, among others, a display editor which you can now also use to create your own symbols. With DIGSI 5 Standard, you simulate the topology of a system as a 1- 1-phase representation and you configure hardware and networks on a graphical basis. DIGSI 5 Standard offers full IEC 61850 support, including system configuration.
- DIGSI 5 Premium is the high-end variant of DIGSI 5. You analyze fault records with SIGRA and you use
the advantages of flexible engineering and functional naming for IEC 61850. You will find a detailed overview of the features of the 3 variants in the Help topic entitled Features of the Different DIGSI 5 Variants.
Training on DIGSI 4 and DIGSI 5 Training, contact us
Useful SIPROTEC 5 & DIGSI 5 Manuals
DIGSI 5 Software Description DIGSI 5 Software Description
SIPROTEC 5 Operation Manual SIPROTEC 5 Manual
SIPROTEC 5 Hardware Description Manual SIPROTEC 5 Hardware Description Manual
SIPROTEC 5 Engineering Guide DIGSI 5 Manual SIPROTEC 5 Engineering Guide DIGSI 5 Manual
Now DIGSI 5 V7.5 and DIGSI 5 V7.8 are also available on the SIEMENS website
DIGSI 5 Training contact us and reserve your seat.
- Background and Introduction
- New Energy
- Information Spectrum
- Global Trends
- Applications
- Battery Storage
- Challenges of the New Energy World
- New trends in power electronics for the integration of wind and photovoltaic
- Review of the appropriate storage-system technology
- Future trends in renewable energy systems based on reliability and maturity
- Microgrids and it’s working
- Stability analysis of Microgrids
- Microgrids and their Role in Smart Buildings and Smart cities
- Smart Grid and Power Electronics
- DC and Uninterrupted AC Power Supplied for Automation Application
- Electric Vehicles: Challenges and Opportunities
- Fundamentals of Grid-connected system
- Control and analysis for grid-connected solar inverter
South Australia Blackout of 28 September 2016 –was the cause due to the massive use of Renewables?
To download all of the above-mentioned topics, contact us.
Learning is a continuous process and enables us to be competitive in our field. Consistent with this belief and built on a strong experience in this field, we offer video training courses for practicing professionals in the area of Substation Automation and Protection relay. The material of each course is designed to help you to be a professional in the field.
we provide training courses at your site or online, please contact us for more information.
Power quality is simply the interaction of electrical power with electrical equipment. If electrical equipment operates correctly and reliably without being damaged or stressed, we would say that the electrical power is of good quality. On the other hand, if the electrical equipment malfunctions, is unreliable, or is damaged during normal usage, we would suspect that the power quality is poor.
As a general statement, any deviation from the normal voltage source (either DC or AC) can be classified as a power quality issue.
We can verify the power quality by installing a special type of high-speed recording test equipment to monitor the electrical power. This type of test equipment will provide information used in evaluating if the electrical power is of sufficient quality to reliably operate the equipment. The process is similar to a doctor using a heart monitor to record the electrical signals for your heart. Monitoring will provide us with valuable data, however, the data needs to be interpreted and applied to the type of equipment being powered.
- Introduction to Power Quality, Standards, and Monitoring
- Custom Power Devices
- Nonlinear loads, Passive and Active Power Filters
- IEEE Standard 519-2014
- Six-Pulse Rectifiers
- DC-Link Reactor –Current Source (SCR Drives)
- DC-Link Capacitor –Voltage Source (PWM Drives)
- Active Front End –Voltage Source (PWM Drives)
- Eighteen Pulse Rectifiers
- Multiple Transformers
- Single Transformers
- Harmonic Filters
- Passive Filters
- Active Filters
- New RR substation to be connected to utility 115 kV line
- Single-phase connection to harmonic loads
- Significant harmonic currents measured Is a harmonic filter needed If so, what type?
- Generation-Load mismatch large
- To fill the gap IPPs are encouraged
- Low investment high return may attract many people to participate in power generation
- Low power capacity and hence connected at low voltage
- Encourages renewable energy penetration
- cRooftop PV will be the future
To download the mentioned topics in the Power Quality package (ppt and pdf files) contact us.
- Representation of indications and measured values
- Retrieval of fault records with DIGSI 4
- The COMTRADE format
- Parameterization of fault record representation
- Definition of user profile
- Angle measuring
- Fourier analysis
- Impedance calculation
- Export of fault records
Sample pages:
The system program SIGRA 4 offers support when faults occur in your network. The data recorded during fault occurrence are graphically represented and further data on the basis of the measured values are calculated in addition, like impedance or effective values, which will facilitate the evaluation of the fault record for you.
The SIGRA 4 calculations are always on the basis of primary magnitudes.
The transformer ratings are entered in the COMTRADE file of the fault record by DIGSI for evaluation by SIGRA 4.
If you want to evaluate the fault records from third-party devices recording the measured magnitudes as secondary magnitudes, you must make sure that the magnitudes will be correctly converted into primary magnitudes via the transformer ratings. The dialog box Parameterize Channels serves to carry out this parameterization. Negative ratings will cause a measured signal rotation of 180°. Thus, compatibility with the definition of the SIGRA 4 arrow metering system is ensured.
The representation and display of metered values in the secondary system is always based on the compilation ratio between the primary current or principal voltage transformer.
If metered magnitudes are created via a measuring window, this window is always left of the observation time, for ex. The cursor position. The measuring window equals the length of a period interval of the rated frequency TN, 20 ms at 50 Hz for example. The calculated magnitudes are only valid if there is no change of status displayed in the measuring window, like fault occurrence or interruption. The magnitudes calculated by SIGRA 4 are identified by an asterisk in the name.
The Time Signal view serves to visualize signals as a time function.
This view serves to define any number of diagrams of the following type status diagrams:
- analog curve diagrams
- binary value diagrams
- and to assign any number of measured and calculated magnitudes, binary or status signals (time marking).
There is the option to display the values as current or root-mean-square values.
The status diagram serves to represent the fault recording trigger time as defined status.
If user-defined status signals have been set to select individual times, these times are displayed in the status diagram with the corresponding symbol.
In addition to the graphical representation, the values of individual signals can be read at defined times from a diagram, and the current position of Cursor 1 and Cursor 2 can be read from the time axis. If a cursor is moved in a view other than that of time signals, the cursor position in the time signal view is changed, as well.
The Vector Diagram view serves to visualize measured and calculated magnitudes as complex vectors at defined times.
The diagram on the left is clearly assigned to Cursor 1 and the diagram on the right to Cursor 2.
The vector of the measured magnitudes is r.m.s. values of the harmonic component
(nominal frequency TN.). The amount and angle of the vector are determined via a full-cycle DFT (Discrete Fourier Transformation).
The measuring window is always left of the reference time (cursor position) and has the length of a time of the nominal frequency TN (for ex., 50 Hz « 20 ms).
The vector angle refers to a standard vector rotating at a nominal frequency of (fN=nominal frequency).
As a supplement to the graphical representation, you can use a diagram to read the signal values at specified times and the corresponding position of Cursor 1 and Cursor 2 on the time axis. If a cursor is moved in one view, the current vector diagram is changed, as well.
NETA Handbook Series I
- NETA Handbook Series I, Protective Relay Vol 1
- NETA Handbook Series I, Protective Relay Vol 2
- NETA Handbook Series I, Protective Relay Vol 3
NETA Handbook Series II
- NETA Handbook Series II, Protective Relay Vol 1
- NETA Handbook Series II, Protective Relay Vol 2
Download PSCAD Software
PSCAD is a simulation tool for analyzing power system transients.
PSCAD is most suitable for simulating the time domain instantaneous responses, also popularly known as electromagnetic transients of electrical systems. The PSCAD Graphical Interface greatly enhances the power and efficiency of your simulation. It allows the user to schematically construct a circuit, run a simulation, analyze the results, and manage the data in a completely integrated graphical environment.
The PSCAD/EMTDC software comes with an excellent collection of example cases, which can be used as the starting point for many of your projects. They are also used as example cases to illustrate the usage of certain complicated models, which are described best using a working example. You can also copy parts of these examples to quickly assemble your own circuits. For details on available templates see the online help system. These cases are available in your PSCAD installation directory under Examples. There is also a set of Tutorial examples in this directory.
Download Template networks in PSCAD for a transient testing package
Type: PSCAD (.pscx)
Size: 18 MB
Download PSCAD
Type: Software
Size: 93 MB
Download PSCAD Full package (Download PSCAD + Download Template networks in PSCAD for the transient testing package)
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Learning is a continuous process and enables us to be competitive in the area of Substation Automation and Protection relay. Consistent with this belief and built on a strong experience in this field, we offer various services and education products such as video training packages, software training, remote technical support, providing relay settings and test sheets, remote relay testing, Online training, and training at the site. Browse our website – if there are any requests or ideas, then please contact us.
Video Training Packages: One of Elec-Engg’s main objects is providing video training packages. The possibilities of interactive training with video are endless. Such training can be accessed whenever and wherever it is needed, as often as is necessary. It is highly cost-effective, reduces travel, and is time-saving. We provide professional video training packages for practicing professionals in Substation Automation and Protection Relays. The material of each course is designed to help you in being a professional in that field.
Course definition
TARGETS
- Marketing function
- Protection technician
- Product Application Engineer (PAE)
- Application engineer
Objective:
- Able to understand and choose the protection functions available in the Sepam range offer in compliance with standards and industrial MV network applications. Theoretical introduction to Sepam series 20, 40, 80 bringing into operation.
Content
- Introduction of MV dist ibut ion networks, Generation, transmission and distribution systems, Substation, industrial and building environments, Typical loads and generators, The configuration of MV networks, faults, Neutral earthing systems. Introducing MV protection principles: The protection functions, The principles of discrimination, Measurement sensors. Study of an MV industrial network and use of the protection plan: Calculation/ verification of fault current, Choosing protection function according to the application (substation, busbar, transformer, etc …)
PDF Files:00-Sepam Protection Principles.
01-Plan_Network structures.
02-Plan_Network and machine faults.
03-Plan_Source of Isc.
04-Plan_Symmetrical components.
05-Plan_Calculation of Isc.
06-Plan_Calculation of Isc_exercises.
07-Plan_Earthing systems.
08-Plan_Earthing systems_exercises.
09-Plan_CTs.
10-Plan_CTs_exercises.
11-Plan_Irsd measurement.
12-Plan_LPCT.
13-Plan_VTs.
14-Plan_Vrsd measurement.
15-Plan_Prot funct general charact.
16-Plan_IDMT curves_exercises.
17-Plan_Discrimination.
18-Plan_ANSI 67.
19-Plan_ANSI 67N.
20-Plan_Differential_87.
21-Plan_ANSI 87M.
22-Plan_ANSI 87T.
23-Plan_ANSI 64REF.
24-Plan_ANSI 49RMS.
25-Plan_Network protection.
26-Plan_Busbar protection.
27-Plan_Transformer protection.
28-Plan_ANSI 24_transformer.
29-Plan_ANSI 26-63.
30-Plan_Motor protection.
31-Plan_ANSI 40_motor.
32-Plan_ANSI 78PS_motor.
33-Plan_Synchronous generator protection.
34-Plan_ANSI 21B.
35-Plan_ANSI 24_generator.
To download: contact us
The relay coordination and setting calculation for a case study substation is applied to clear the faulty feeder.
The simulation is done in ETAP software. Relay settings, coordination curves, and settings tables are discussed in detail. The excel sheet of the coordination settings also is attached.
SUBSTATION
A station in the power transmission system at which electric power is transformed to a conveniently used form. The station may consist of transformers, switches, circuit breakers, and other auxiliary equipment. Its main function is to receive energy transmitted at high voltage from the generating station, by either step-up or step-down the voltage to a value appropriate for local use and provide facilities for switching. Substations have some additional functions. Its provide points where safety devices may be installed to disconnect circuits or equipment in the event of trouble.
Some substations, such as power plant switchyards are simply switching stations where different connections can be made between various transmission lines.
Typical Components of a Power Plant Substation
BUSBAR
BUSBAR (or bus, for short) – is a term we use for a main bar or conductor carrying an electric current to which many connections may be made.
Buses are merely convenient means of connecting switches and other equipment into various arrangements. The usual arrangement of connections in most substations permits working on almost any piece of equipment without interruption to incoming or outgoing feeders. In the switchyard or substation, buses are open to the air. Aluminum or copper conductors supported on porcelain insulators, carry the electric energy from point to point.
DISCONNECTS
DISCONNECT – is an easily removed piece of the actual conductor of a circuit. The purpose of disconnects is to isolate equipment. Disconnects are not used to interrupt circuits; they are no-load devices. A typical use of disconnects is to isolate a circuit breaker by installing one disconnect on either side of the circuit breaker (in series with the breaker). Operation of disconnects is one of the most important and responsible jobs of a power plant operator. One error in isolation of equipment, or the accidental grounding of the line equipment, can be a fatal mistake.
CIRCUIT BREAKER
CIRCUIT BREAKER – is used to interrupt circuits while current is flowing through them. The making and breaking of contacts in an Oil type circuit breaker are done under oil, this oil serves to quench the arc when the circuit is opened. The operation of the breaker is very rapid when opening. As with the transformer, the high voltage connections are made through bushings. Circuit breakers of this type are usually arranged for remote electrical control from a suitably located switchboard.
Some recently developed circuit breakers have no oil, but put out the arc by a blast of compressed air; these are called air circuit breakers. Another type encloses the contacts in a vacuum or a gas (sulfur hexafluoride, SF6) which tends to self maintain the arc.
CURRENT TRANSFORMER
CURRENT TRANSFORMER – Current transformers are used with ammeters, wattmeters, power-factor meters, watt-hour meters, compensators, protective and regulating relays, and the trip coil of circuit breakers. One current transformer can be used to operate several instruments, provided that the combined burden does not exceed that for which the transformer is designed and compensated. The current transformer is connected directly in series with the line.
VOLTAGE TRANSFORMER
VOLTAGE TRANSFORMER – also known as a potential transformer, is used with volt-meters, wattmeters, watt-hour meters, power-factor meters, frequency meters, synchroscopes, and synchronizing apparatus, protective and regulating relays, and the no-voltage and over-voltage trip coils of automatic circuit breakers. One transformer can be used for several instruments at the same time if the total current taken by the instrument does not exceed that for which the transformer is designed and compensated. The ordinary voltage transformer is connected across the line, and the magnetic flux in the core depends upon the primary voltage
EARTHING SWITCH
EARTHING SWITCH – also known as ground disconnect, which is used to connect the equipment to a grid of electrical conductors buried in the earth on the station property. It is intended to protect people working on the grounded equipment. It does this by completing a circuit path, thereby reducing the voltage difference between the equipment and its surroundings. For safety reasons, it is important that ground disconnects and all associated connections have good contact and low resistance. It is also important that the protective ground not be accidentally removed, that is why all the earthing switches, disconnect switches, and circuit breakers are all interlocked to each other and proper/correct sequencing must be followed.
SURGE ARRESTOR
SURGE ARRESTOR – are devices used to provide the necessary path to ground for such surges, yet prevent any power current form following the surge. An ideal arrester must therefore have the following properties:
1. Ability to remove the surge energy from the line in a min. time.
2. High resistive to flow of power current.
3. A valve action automatically allows surge to pass and then close up so as not to permit power current to flow to the ground.
4. Always ready to perform.
5. Performance such that no system disturbances are introduced by its operation.
6. Economically feasible
OVERHEAD GROUND WIRE – by a ground wire is meant a wire, generally of steel, supported from the top of transmission-line towers and solidly grounded at each tower. It is considered a preventive device, but it does not entirely prevent the formation of traveling waves on a line. Furthermore, those lines which are not equipped with ground wires will be subjected to disturbances that produce surges that must be allowed to escape to the ground, or the apparatus connected to the line must be strong enough to reflect or absorb these surges until they are entirely damped out.
PREVENTIVE MAINTENANCE
- BUSBARS & OVERHEAD GROUND WIRE
At least once a year
- Visual Inspection & Examination of all wiring connectors.
- Check Insulator , clean or apply HVIC if necessary.
- Check the physical condition of bus (cables or bars)
- For ground wire, check or test the grounding system.
- DISCONNECT & EARTHING SWITCHES
At least once a month
- Visual Inspection.
- Check heating resistor located at its control panel for proper functioning.
At least once a year
- Clean contacts of disconnectors as well as earthing switches and apply electrical contact grease , if necessary.
- Check disconnectors and earthing switches, joints and bearings of the operating linkages for deformed bearing points.
- Check flexible connections of earthing switches.
- Check all screwed joints for tight fit.
- Clean insulators if necessary, when an excessive amount of dirt has accumulated.
- Carry-out the maintenance of operating mechanism.
- VOLTAGE TRANSFORMER
At least once a month
- Inspect the voltage divider to be sure that no oil leak or serious accumulation of soot, dust or salt composite is present.
- Inspect the intermediate voltage transformer and check the minimum permissible oil level.
At least once a year
- Check all screwed joints & contact for tight fit.
- Clean insulators if necessary, when an excessive amount of dirt has accumulated.
CURRENT TRANSFORMER
At least once a month
- Visual Inspection to check oil level and defects or possible oil leaks.
At least once a year
- Check all screwed joints & contact for tight fit.
- Clean insulators if necessary, when an excessive amount of dirt has accumulated.
- Check primary and secondary connectors and conduct necessary tightening.
Note: Never open a secondary winding of a CT while on service.
- SURGE ARRESTOR
At least once a year
- Visual Inspection & Examination of all wiring connectors.
- Check Insulator and metal circular ring, clean or apply HVIC if necessary.
- Check the physical condition of bus (cables or bars)
- For ground wire, check or test the grounding system.
Note: Arrestors should never be touched unless completely disconnected from all live lines and equipment and effectively connected to the ground at the line side of the arrestor.
DIGSI 4 is configuration software for SIPROTEC 4 and SIPROTEC compact relays. We provide good content to learn DIGSI 4.
For DIGSI 4 Training Just leave a comment on this post or contact us for a reservation
For DIGSI 4 and DIGSI 5 Online training, contact us
MV and LV Switchgear Test Procedure (SIMPPRIME, SIVACON)
The aim of this document is a description of the responsibilities of the test procedure during all stages related to the switchboard. This guide direction is prepared for related stages to the pre-commissioning and commissioning of switchgear.
Part I, Pdf, 400 pages
Part II, pdf, 100 pages
To Download, contact us
This course contains the following topics:
- Distance Protection for transmission lines: part 1
- Symmetrical Components
- Distance Protection: Earth-Faults and Fault Resistance
- Residual Compensation Factors: K0 and RE/RL, XE/XL
- Distance Protection for transmission lines: part 2
- Distance Protection: Earth-Faults in Isolated and Resonant Grounded Systems
- Distance Protection: Negative Sequence Direction measurement
- Distance Protection: Tele-Protection and weak infeed
- Distance Protection Power Swing
- Distance Protection Monitoring Functions
- Distance Protection Series Compensated Lines
- Fault locator with 2 ended measurement
- Earth Fault protection
- Auto Re-close and Sync Check
- Distance Protection OHL Setting Example
Large or small, every industrial, commercial, and institutional organization needs to understand how to protect their investment in their electric power systems.
The task of the electrical unit protection is to detect electrical failures and inadmissible operation of the generator, generator bus bar, excitation system, generator transformer, and another existing transformer (Station transformer, unit auxiliary transformer) and disconnect faulty circuits with speed and certainly without interference healthy circuits.
An automatic synchronizing unit is furnished for connecting the generator unit to the grid via the generator circuit breaker. It is also possible to connect via the circuit breakers in the HV substation if the generator circuit breaker is already closed.
The universal transducers allow the measurement of all electrical quantities occurring in any network in a single unit. Especially in power plants and substations, transducers are used to isolate electrical signals and further process measured values.
The following PDF is the course on Protection, synchronization, and measurement system in the generation station. This course is based on the Siemens project.
Type: PDF
Page: 120
Size: 21 MB
Generator Transformer Protection System full diagram based on SIPROTEC Siemens Relays
The task of the electrical unit protection is to detect electrical failures and inadmissible operation of the generator, generator bus bar, excitation system, generator transformer, and another existing transformer (Station transformer, unit auxiliary transformer) and disconnect faulty circuits with speed and certainly without interference healthy circuits. The mechanical turbine and generator protection are independent of electrical protection. The generator protection and synchronizing cubicles will be delivered in fully wired and tested cubicles, ready for connection. Each subcase contains a complete protection device with DC/DC converter for power supply, Potential, and current transformers, an A/D converter, computer chips, a watchdog circuit, and trip relays.
A numerical protection system (NPS) shall mean the protection terminals wherein the analog to digital conversion of the input variables takes place immediately after the input transformers and all further processing of the resulting numerical signals shall be performed by microprocessors and controlled by programs. NPS shall include all features of conventional relays, protective devices, relay panels for generator, generator transformer, unit transformer, and station transformer
The following course contains the diagram of the Generator and Transformer protection based on SIPROTEC 4 SIEMENS IEDs. Please contact us for more info and get this course.
Siemens Protection Devices Limited (SPDL)
SPDL – Reyrolle Product Introduction
The history of Reyrolle with over 100 Years of Experience
Reyrolle has been synonymous with electrical protection devices in the sectors of sub-transmission, distribution, and industrial applications for decades. Historically, Reyrolle relays, initially sold mainly in traditional markets, are now sold worldwide as part of the Siemens protection network.
Since its foundation, Reyrolle has been an innovation driver in product development – based on a strong focus on market, customer, and technology. Worldwide established brand names such as “Solkor” and “Argus” demonstrate this. But there is more: A wide range of Reyrolle products has determined technological firsts in the market.
The comprehensive range of Reyrolle products provides the total protection requirements of distribution markets – ranging from overcurrent protection via transformer protection and voltage control to a full spectrum of auxiliary and trip relays. The portfolio
includes many famous products such as “Argus”, “Duobias”, “Solkor”, “Rho”, etc.
To serve specific needs in industrial applications, a range of proven products such as “Argus overcurrent”, “Solkor line differential” and “Rho motor protection devices” is offered.
Through successive generations, Reyrolle numerical products have been developed to increase value to system operators.
This increase in value is the result of consistent development:
Siemens Protection Devices Limited (SPDL) Introduction – Portfolio Offering
Ease-of-use as a principle – our withdrawable product solutions allow flexible, easy operation through high user
friendliness.
One size fits all – the 4U housing height and the latest generation of numerical products features 1A/5A CT Input,
and some models are provided with universal DC supplies.
Learn once, know all – the new product generation provides a similar look and feels as earlier products. If Reyrolle numerical
devices have been previously used, there is a high consistency in both programming and interrogation.
With Reydisp Evolution, a comprehensive software support toolkit for relay setting, fault interrogation, and general
system information is provided. It is backward-compatible with all previous Reyrolle numerical devices.
.
7SR22 (Argus) Overcurrent Protection; directional
SIEMENS 7SR Virtual Relay
IEC 61850 library for Engineers
| {.pdf} | ⦁ | Time_Synch_IEC_61850_and_C37118_Harmonize. |
| {.pdf} | ⦁ | 615 series ANSI IEC 61850 Engineering Guide. |
| {.pdf} | ⦁ | 650 series IEC 61850 Communication Protocol Manual. |
| {.pdf} | ⦁ | 650 series IEC 61850 Communication Protocol Manual. |
| {.pdf} | ⦁ | 670 series 2.0 IEC IEC 61850 Edition 1 Communication Protocol Manual. |
| {.pdf} | ⦁ | 670 series 2.0 IEC IEC 61850 Edition 2 Communication Protocol Manual. |
| {.pdf} | ⦁ | 2013 IEC 61850 INTEROPERABILITY TEST Munich, Germany. |
| {.pdf} | ⦁ | 61850 easy. |
| {.pdf} | ⦁ | ABB AFS660 Switch High-availability Ethernet device based on new IEC-standard redundancy protocols PRP/HSR. |
| {.pdf} | ⦁ | ABB AFS660 Switch High-availability Ethernet device based on new IEC-standard redundancy protocols PRP/HSR. |
| {.pdf} | ⦁ | ABB is implementing the first commercial installation of IEC 61850-9-2 LE process-bus technology. |
| {.pdf} | ⦁ | ABB review Special Report IEC 61850. |
| {.pdf} | ⦁ | Advanced protection and control IEDs from ABB. |
| {.pdf} | ⦁ | AGILE DIGITAL SUBSTATIONS The complete guide. |
| {.pdf} | ⦁ | Analysis and implementation of the IEC 61850 standard. |
| {.pdf} | ⦁ | Application Considerations of IEC 61850/UCA 2 for Substation Ethernet Local Area Network Communication for Protection and Control. |
| {.pdf} | ⦁ | Applications of IEC 61850 Standard to Protection Schemes. |
| {.pdf} | ⦁ | Applications of Phasor Measurement Units. |
| {.pdf} | ⦁ | Applications of PMU measurements in the Belgian electrical grid. |
| {.pdf} | ⦁ | The Application-View Model of the International Standard IEC 61850. |
| {.pdf} | ⦁ | Approach to optimized process Bus architectures. |
| {.pdf} | ⦁ | Approach to optimized process Bus architectures. |
| {.pdf} | ⦁ | Automation at Protection Speeds: IEC 61850 GOOSE Messaging as a Reliable, High-Speed Alternative to Serial Communications. |
| {.pdf} | ⦁ | The Building Blocks of a Data-Aware Transport Network: Deploying Viable Ethernet and Virtual Wire Services via Multiservice ADMs. |
| {.pdf} | ⦁ | Calibration System for Electronic Instrument Transformers With Digital Output. |
| {.pdf} | ⦁ | Challenges and Integration of PV and Wind Energy Facilities from a Smart Grid Point of View. |
| {.pdf} | ⦁ | Challenges and Lessons Learned from Commissioning an IEC 61850-90-5 Based Synchrophasor System. |
| {.pdf} | ⦁ | Colombian electrical sector adopting high redundancy communication design on a new HV substation
⦁ COMMON REQUIREMENTS FOR ELECTRIC POWER EQUIPMENT. ⦁ Communication in Power application. ⦁ Communication Protocols and Networks for Power Systems- Current Status and Future Trends. ⦁ Communications network solutions for smart grids. ⦁ The concept of IEC 61850. ⦁ CT Standard. ⦁ D2-01_07_Meeting requirements in an IEC 61850 station bus SAS. ⦁ Data transport network. ⦁ Dealing with Packet Delay Variation in IEEE 1588 Synchronization Using a Sample-Mode Filter. ⦁ Design and Implementation of Packet Analyzer for IEC 61850 Communication Networks in Smart Grid. ⦁ Design and Performance Testing of a Multivendor IEC61850–9-2 Process Bus Based Protection Scheme. ⦁ Design, Development, and Commissioning of a Supervisory Control and Data Acquisition (SCADA) Laboratory for Research and Training. ⦁ DEVELOPING PROTECTIVE RELAY FACEPLATES. ⦁ Developing Real-Time PMU Applications for Smart Transmission Grids. ⦁ Development of IEC61850 Based Substation Engineering Tools with IEC61850 Schema Library. ⦁ Differential Protection RET 54_/Diff6T function Application and Setting Guide. ⦁ Digital umspannwerk. ⦁ Digitalization in Transmission and Distribution. ⦁ Direct Evaluation of IEC 61850-9-2 Process Bus Network Performance. ⦁ Distributed busbar protection REB500 including line and transformer protection Product Guide. ⦁ Distributed Multifunction Fault Recorder. ⦁ A Distributed PMU for Electrical Substations With Wireless Redundant Process Bus. ⦁ Duplicate and Circulating Frames Discard Methods for PRP and HSR (IEC62439-3). ⦁ Dynamic Testing of an IEC 61850 Based 110 kV Smart Substation Solution. ⦁ EC 61850 for Substations. ⦁ ECT Evaluation by an Error Measurement System According to IEC 60044-8 and 61850-9-2. ⦁ Efficient Energy Automation with the IEC 61850 Standard Application Examples Energy Automation. ⦁ Emerging Applications of Synchronous Ethernet in Telecommunication Networks. ⦁ Enabling digital substations. ⦁ Energy Management of Internet Data Centers in Smart Grid. ⦁ Engineering Perspective on IEC 61850. ⦁ Enhanced Engineering process SCL example. ⦁ Enhanced Engineering process SCL Files. ⦁ ERL 61850 IED Configurator. ⦁ ERL 61850 IED Configurator. ⦁ Ethernet & IEC 61850 Concepts, Implementation, Commissioning. ⦁ Ethernet in SAS. ⦁ Ethernet in SAS. ⦁ Ethernet in Substation Automation Applications – Issues and Requirements. ⦁ Ethernet Module EN100 for IEC 61850 with electrical/optical 100 MBit Interface Application Examples. ⦁ Ethernet Networks Redundancy With Focus On IEC 61850 Applications. ⦁ ETHERNET NETWORKS REDUNDANCY WITH FOCUS ON IEC 61850 APPLICATIONS. ⦁ Ethernet-Based Public Communication Services: Challenge and Opportunity. ⦁ Evaluation of IEC 61850-9-2 Samples Loss on Total Vector Error of an Estimated Phasor. ⦁ The Evaluation of Phasor Measurement Units and Their Dynamic Behavior Analysis. ⦁ Evaluation of Time Gateways for Synchronization of Substation Automation Systems. ⦁ Executive Summary (Introduction to MMS. ⦁ Feeder Protection and Control REF615 Application Manual. ⦁ Focus on the application – IEC 61850 experience with the third-party system configuration tool. ⦁ Generic IEC61850 IED Connectivity Package User‘s Guide. ⦁ Get on the digital bus to SA. ⦁ GOOSE AIR. ⦁ GOOSE Configuration Example. ⦁ Goose messages for automated testing: 765 kV transmission network. ⦁ Goose Messaging Determining its potential in a real case. ⦁ GOOSE IEC 61850 Test System. ⦁ GPS and IEEE 1588 synchronization for the measurement of synchrophasors in electric power systems. ⦁ Grid Automation REC615 and RER615 IEC 61850 Engineering Guide. ⦁ HardFiber. ⦁ Hidden Challenges in the Implementation of 61850 in Larger Substation Automation Projects. ⦁ IEC60076. ⦁ iec61850-8-1{ed1.0}en-2004. ⦁ IEC61850 Based Process Bus Protection Solution for Remote Located Power Transformers. ⦁ IEC61850 Modeling for Switch Management. ⦁ IEC 60870-5-101/104 Slave Technical. ⦁ IEC 60870-5-103 Communication Protocol Manual. ⦁ IEC 61400-25-2. ⦁ IEC 61850-3 and IEEE 1588. ⦁ IEC 61850-7-420 IEC 61850 Part 7-420 DER Logical Nodes. ⦁ IEC 61850-9-2 Based Process Bus. ⦁ IEC 61850-9-2 Process Bus and Its Impact on Power System Protection and Control Reliability. ⦁ IEC 61850-9-2 Process Bus Communication Interface for Light Weight Merging Unit Testing Environment. ⦁ IEC 61850 – Communication networks and systems in substations. ⦁ IEC 61850 – More Than Just GOOSE: A Case Study of Modernizing Substations in Namibia. ⦁ IEC 61850 Process Bus – It is Real!. ⦁ IEC 61850: COMMUNICATION NETWORKS AND SYSTEMS IN SUBSTATIONS. ⦁ IEC 61850 and Measurements. ⦁ IEC 61850 -Communication Networks and Systems in Substations: An Overview of Computer Science. ⦁ IEC 61850 driver FAQ. ⦁ IEC 61850 Enabled Automatic Bus Transfer Scheme for Primary Distribution Substations. ⦁ IEC 61850 General. ⦁ IEC 61850 GOOSE and IEEE C37.118 Synchrophasors Used for Wide-Area Monitoring and Control, SPS, RAS, and Load and Generation Management. ⦁ IEC 61850 Goose applications to distribution protection schemes. ⦁ IEC 61850 Goose applications to distribution protection schemes. ⦁ IEC 61850 MMS Client Driver Help. ⦁ IEC 61850 Model Expansion Toward Distributed Fault Localization, Isolation, and Supply Restoration. ⦁ IEC 61850 Process Bus – It is Real!. ⦁ IEC 61850 PROCESS CONNECTION – A SMART SOLUTION TO CONNECT THE PRIMARY EQUIPMENT TO THE SUBSTATION AUTOMATION SYSTEM. ⦁ IEC 61850 Protocol API User Manual. ⦁ IEC 61850 Qualifications. ⦁ IEC 61850 standard for SA. ⦁ The IEC 61850 standard for SA. ⦁ IEC 61850 standard for SA. ⦁ IEC 61850 Substation Configuration Language and Its Impact on the Engineering of Distribution Substation Systems. ⦁ IEC 61850 System Configurator. ⦁ IEC 61850 System Configurator. ⦁ IEC 61850 Technical Overview. ⦁ IEC 61850/61400 Model Designer. ⦁ IEC 61850: Role of Conformance Testing in Successful Integration. ⦁ IEC 61850: WHAT YOU NEED TO KNOW ABOUT FUNCTIONALITY AND PRACTICAL IMPLEMENTATION. ⦁ IEC 61850-Based Feeder Terminal Unit Modeling and Mapping to IEC 60870-5-104. ⦁ IEC 61850-Based Information Model and Configuration Description of Communication Network in Substation Automation. ⦁ IEC 62357: TC57 Architecture Part 1: Reference Architecture for Power System Information Exchange. ⦁ IEC 62439 PRP: Bumpless Recovery for Highly Available, Hard Real-Time Industrial Networks. ⦁ IEC Smart Grid Standardization Roadmap. ⦁ IED Configuration Guidelines. ⦁ IEEE-1588 Standard for a Precision Clock Synchronization Protocol for Networked Measurement and Control Systems. ⦁ IEEE 802.1AS and IEEE 1588. ⦁ IEEE 802.3ba 40 and100 Gigabit Ethernet Architecture. ⦁ IEEE 1547.2 IEEE Application Guide for IEEE Std 1547™, IEEE Standard for Interconnecting Distributed Resources with Electric Power Systems. ⦁ IEEE 1547.3 IEEE Guide for Monitoring, Information Exchange, and Control of Distributed Resources Interconnected with Electric Power Systems. ⦁ IEEE 1547.4 IEEE Guide for Design, Operation, and Integration of Distributed Resource Island Systems with Electric Power Systems. ⦁ IEEE 1547.6 IEEE Recommended Practice for Interconnecting Distributed Resources with Electric Power Systems Distribution Secondary Networks. ⦁ IEEE 1588. ⦁ IEEE 1588 Precision Time Protocol Time Synchronization Performance. ⦁ IEEE 1588 Precision Time Synchronization Solution for Electric Utilities. ⦁ IEEE 1588 Version 2. ⦁ IEEE 1615 IEEE Recommended Practice for Network Communication in Electric Power Substations. ⦁ IEEE Application Guide for IEEE Std 1547™, IEEE Standard for Interconnecting Distributed Resources with Electric Power Systems.” |
| {.pdf} | ⦁ | IEEE c37.118.1 IEEE Standard for Synchrophasor Measurements for Power Systems. |
| {.pdf} | ⦁ | IEEE c37.118.2 2011 IEEE Standard for Synchrophasor Data Transfer for Power Systems. |
| {.pdf} | ⦁ | IEEE Recommended Practice for Network Communication in Electric Power Substations. |
| {.pdf} | ⦁ | IEEE Standard for a Precision Clock Synchronization Protocol for Networked Measurement and Control Systems. |
| {.pdf} | ⦁ | IEEE Standard for Electric Power Systems Communications— Distributed Network Protocol (DNP3). |
| {.pdf} | ⦁ | IEEE Standard for Ethernet. |
| {.pdf} | ⦁ | IEEE Standard for Ethernet. |
| {.pdf} | ⦁ | IEEE Standard for Ethernet Amendment 1: Physical Layer Specifications and Management Parameters for Extended Ethernet Passive Optical Networks. |
| {.pdf} | ⦁ | IEEE Standard for Information technology— Telecommunications and information exchange between systems Local and metropolitan area networks— Specific requirements Part 17: Resilient packet ring (RPR) access method and physical layer specifications. |
| {.pdf} | ⦁ | IEEE Standard for Service Interoperability in Ethernet Passive Optical Networks (SIEPON). |
| {.pdf} | ⦁ | IEEE Standard for Synchrophasor Data Transfer for Power Systems. |
| {.pdf} | ⦁ | IEEE Standard for Synchrophasor Measurements for Power Systems. |
| {.pdf} | ⦁ | IEEE Standard Profile for Use of IEEE 1588™ Precision Time Protocol in Power System Applications. |
| {.pdf} | ⦁ | IEEE Std 802.1. |
| {.pdf} | ⦁ | Impact of IEC 61850-9-2 Standard-Based Process Bus on the Operating Performance of Protection IEDS: Comparative Study. |
| {.pdf} | ⦁ | IMPLEMENTATION GUIDELINE FOR DIGITAL INTERFACE TO INSTRUMENT TRANSFORMERS USING IEC 61850-9-2. |
| {.pdf} | ⦁ | An Implementation of FTTH based Home Gateway Supporting Various Services. |
| {.pdf} | ⦁ | Implementing New Generation Protective Relay Schemes based on IEC61850 Standard for Substation Communication in the Eskom 765kV Transmission Network. |
| {.pdf} | ⦁ | Implementing Vehicle-to-Grid (V2G) Technology With IEC 61850-7-420. |
| {.pdf} | ⦁ | Industrial & Plant Communication. |
| {.pdf} | ⦁ | Industrial automation systems Manufacturing Message Specification. |
| {.pdf} | ⦁ | Industrial Communication. |
| {.pdf} | ⦁ | INDUSTRIAL INFORMATION TECHNOLOGY. |
| {.pdf} | ⦁ | Installation and commissioning manual Line distance protection IED REL 670. |
| {.pdf} | ⦁ | INSTRUCTION MANUAL DISTANCE RELAY WITH INTEGRAL DIGITAL COMMUNICATION GRZ100. |
| {.pdf} | ⦁ | INSTRUCTION MANUAL TRANSFORMER PROTECTION RELAY GRT100. |
| {.pdf} | ⦁ | The Integrated Energy and Communication Systems Architecture. |
| {.pdf} | ⦁ | AN INTEGRATED PMU AND PROTECTION SCHEME FOR POWER SYSTEMS. |
| {.pdf} | ⦁ | Integration of a New Standard. |
| {.pdf} | ⦁ | Integration of IEC 61850 GSE and Sampled Value Services to Reduce Substation Wiring. |
| {.pdf} | ⦁ | Integration of IEC 61850 GSE and Sampled Value Services to Reduce Substation Wiring. |
| {.pdf} | ⦁ | INTERNSHIP REPORT USE OF IEC 61850 FOR ASSET MANAGEMENT IN LOW VOLTAGE MICROGRIDS. |
| {.pdf} | ⦁ | Interoperability and Performance Analysis of IEC61850 Based Substation Protection System. |
| {.pdf} | ⦁ | Interoperability Requirements for IEC 61850 System Configuration Tools. |
| {.pdf} | ⦁ | Introduction and Overview of IEC 61850 Configuration and Diagnostics. |
| {.pdf} | ⦁ | IP and Ethernet Communication Technologies and Topologies for IED networks. |
| {.pdf} | ⦁ | Issues and Approaches on Extending Ethernet Beyond LANs. |
| {.pdf} | ⦁ | Kalki SCL Manager. |
| {.pdf} | ⦁ | Laboratory Investigation of IEC 61850-9-2-Based Busbar and Distance Relaying With Corrective Measure for Sampled Value Loss/Delay. |
| {.pdf} | ⦁ | Large Scale Grid Integration of Renewable Energy Sources – Way Forward. |
| {.pdf} | ⦁ | Leading the way to Digital Substations. |
| {.pdf} | ⦁ | Lecture 5a Substation Automation Systems. |
| {.pdf} | ⦁ | LINE PROTECTION TESTS USING PROCESS BUS IEC 61850-9-2 WITH NETWORK LOADING. |
| {.pdf} | ⦁ | Logical nodes. |
| {.pdf} | ⦁ | MAGNUM 6K FAMILY OF SWITCHES. |
| {.pdf} | ⦁ | Magnum 6KL Managed Edge Switch. |
| {.pdf} | ⦁ | Memory Requirements Analysis for PRP and HSR Hardware Implementations on FPGAs. |
| {.pdf} | ⦁ | MiCOM Px4x-92LE Technical Manual IEC 61850-9-2LE Interface. |
| {.pdf} | ⦁ | MiCOM Px4x-92LE Technical Manual IEC 61850-9-2LE Interface. |
| {.pdf} | ⦁ | MIGRATION PATHS FOR IEC 61850 SUBSTATION COMMUNICATION NETWORKS TOWARDS SUPERB REDUNDANCY BASED ON HYBRID PRP AND HSR TOPOLOGIES. |
| {.pdf} | ⦁ | Model Implementation Conformance Statement (MICS) for IEC 61850 for the SEL Real-Time Automation Controllers. |
| {.pdf} | ⦁ | Model Implementation Conformance Statement for the IEC 61850 interface in SEL-351A. |
| {.pdf} | ⦁ | Model Implementation Conformance Statement for the IEC 61850 interface in SEL-351S. |
| {.pdf} | ⦁ | Model Implementation Conformance Statement for the IEC 61850 interface in SEL-2411. |
| {.pdf} | ⦁ | Model Implementation Conformance Statement for the IEC 61850 interface in SEL-2440. |
| {.pdf} | ⦁ | Modeling and (Co-)simulation of power systems, controls, and components for analyzing complex energy systems. |
| {.pdf} | ⦁ | Modeling and Simulation for Performance Evaluation of IEC61850-Based Substation Communication Systems. |
| {.pdf} | ⦁ | The move to IEC61850 what and when will it be delivered?. |
| {.pdf} | ⦁ | MU. |
| {.pdf} | ⦁ | MU320 Merging Unit. |
| {.pdf} | ⦁ | MU Agile AMU Technical Manual Analogue Merging Unit. |
| {.pdf} | ⦁ | Network Interactions and Performance of a Multifunction IEC 61850 Process Bus. |
| {.pdf} | ⦁ | A network scheme for process bus in smart substations without using external synchronization. |
| {.pdf} | ⦁ | A New IED With PMU Functionalities For Electrical Substations. |
| {.pdf} | ⦁ | Next-generation substations. |
| {.pdf} | ⦁ | Non-conventional instrument transformers Advanced GIS substations with IEC 61850-9-2 LE process bus. |
| {.pdf} | ⦁ | A Novel Communication Network for Three-Level Wide Area Protection System. |
| {.pdf} | ⦁ | Object Modeling of Data and DataSets in the International Standard IEC 61850. |
| {.pdf} | ⦁ | Offprint of an article published in PAC World, Fall 2008 Standard IEC 61850 – Network Redundancy using IEC 62439. |
| {.pdf} | ⦁ | On the Use of IEEE 1588 in Existing IEC 61850-Based SASs: Current Behavior and Future Challenges. |
| {.pdf} | ⦁ | One-Way Delay and PTP (IEEE 1588v2) Test Applications. |
| {.pdf} | ⦁ | Optimal Integration of Disparate C37.118 PMUs in Wide-Area PSS With Electromagnetic Transients. |
| {.pdf} | ⦁ | Overview of IEC 61850. |
| {.pdf} | ⦁ | Overview of IEC 61850. |
| {.pdf} | ⦁ | Packet Tracer Network Simulator. |
| {.pdf} | ⦁ | The Parallel Redundancy Protocol for Industrial IP Networks. |
| {.pdf} | ⦁ | Performance Analysis of IEC 61850 Sampled Value Process Bus Networks. |
| {.pdf} | ⦁ | Performance assessment of an IEC 61850-9-2 based protection scheme for the mesh corner of a 400kV transmission substation. |
| {.pdf} | ⦁ | Performance Evaluation of Time-critical Communication Networks for Smart Grids based on IEC 61850. |
| {.pdf} | ⦁ | Performance of IEC 61850-9-2 Process Bus and Corrective Measure for Digital Relaying. |
| {.pdf} | ⦁ | Phasor measurement based on IEC 61850-9-2 and Kalman–Filtering. |
| {.pdf} | ⦁ | Plan Ahead for Substation Automation. |
| {.pdf} | ⦁ | Plc-based SA and SCADA. |
| {.pdf} | ⦁ | Plug-in rapid-wire integrated. |
| {.pdf} | ⦁ | pmu. |
| {.pdf} | ⦁ | A PMU for the Measurement of Synchronized Harmonic Phasors in Three-Phase Distribution Networks. |
| {.pdf} | ⦁ | The PMU Interface using IEC 61850. |
| {.pdf} | ⦁ | PMU Interoperability, Steady-State, and Dynamic Performance Tests. |
| {.pdf} | ⦁ | PMU-based Voltage Instability Detection through Linear Regression. |
| {.pdf} | ⦁ | Power network telecommunication PowerLink – power line carrier system. |
| {.pdf} | ⦁ | Power network telecommunication PowerLink – technical data. |
| {.pdf} | ⦁ | Power network telecommunication SWT 3000 Teleprotection. |
| {.pdf} | ⦁ | The power of IEC 61850. |
| {.pdf} | ⦁ | The power of IEC 61850. |
| {.pdf} | ⦁ | POWER SYSTEM MONITORING. |
| {.pdf} | ⦁ | Power Systems Communications. |
| {.pdf} | ⦁ | a practical application primer for protection engineers. |
| {.pdf} | ⦁ | Practical Applications of Ethernet in Substations and Industrial Facilities. |
| {.pdf} | ⦁ | Practical Considerations for Ethernet Networking Within Substations. |
| {.pdf} | ⦁ | Practical Experience with IEEE 1588 High Precision Time Synchronization in Electrical Substation based on IEC 61850 Process Bus. |
| {.pdf} | ⦁ | Precision Clock Synchronization. |
| {.pdf} | ⦁ | Precision Time Protocol. |
| {.pdf} | ⦁ | PROPAGATION AND INTERACTION OF ETHERNET PACKETS WITH IEC 61850 SAMPLED VALUES IN POWER UTILITY COMMUNICATION NETWORKS. |
| {.pdf} | ⦁ | Protection and Control System Upgrade Based on IEC- 61850 and PRP. |
| {.pdf} | ⦁ | Protocol Implementation Conformance Statement (PICS) for IEC 61850 for the SEL Real-Time Automation Controllers. |
| {.pdf} | ⦁ | PRP and HSR for High Availability Networks in Power Utility Automation: A Method for Redundant Frames Discarding. |
| {.pdf} | ⦁ | PRP and HSR Version 1 (IEC 62439-3 Ed.2), Improvements, and a Prototype Implementation. |
| {.pdf} | ⦁ | The Real-Time Publisher/Subscriber Communication Model for Distributed Substation Systems. |
| {.pdf} | ⦁ | Reason RT411 Technical Manual Time Signal Distributor. |
| {.pdf} | ⦁ | Redundancy in Substation LANs with the Rapid Spanning Tree Protocol (IEEE 802.1w). |
| {.pdf} | ⦁ | Reliable data networks for electric power systems. |
| {.pdf} | ⦁ | Requirements for Ethernet Networks in Substation Automation. |
| {.pdf} | ⦁ | Resilience technologies in Ethernet. |
| {.pdf} | ⦁ | ROLE OF PHASOR MEASUREMENT UNIT (PMU) IN WIDE-AREA MONITORING AND CONTROL. |
| {.pdf} | ⦁ | SA Hand Book. |
| {.pdf} | ⦁ | SAM600 process bus. |
| {.pdf} | ⦁ | The SAM600 process bus IO system integrates conventional instrument transformers into modern, IEC 61850-9-2
⦁ process bus substation automation, protection, and control systems. |
| {.pdf} | ⦁ | Sampled Values. |
| {.pdf} | ⦁ | SAS Application pictures. |
| {.pdf} | ⦁ | SCADA and IP. |
| {.pdf} | ⦁ | SCADA Systems: Challenges for Forensic Investigators. |
| {.pdf} | ⦁ | Seamless redundancy. |
| {.pdf} | ⦁ | Selecting, Designing, and Installing Modern Data Networks in Electrical Substations. |
| {.pdf} | ⦁ | Selection Guide / Ethernet Switches. |
| {.pdf} | ⦁ | Sepam Ethernet Guide. |
| {.pdf} | ⦁ | Sepam IEC 61850 communication. |
| {.pdf} | ⦁ | SICAM A8000 Serie CP-8000 Master Modul mit I/O. |
| {.pdf} | ⦁ | SICAM A8000 Series. |
| {.pdf} | ⦁ | SICAM A8000 Series Wherever energy flows Protection Technology / Substation Automation / Power Quality and Measurements. |
| {.pdf} | ⦁ | SICAM A8000 Series CP-8000, CP-8021, CP-8022 User Manual. |
| {.pdf} | ⦁ | SICAM A8000 Series Operation, telecontrol, and automation in the smallest spaces. |
| {.pdf} | ⦁ | Simulation and testing of the over-current protection system based on IEC 61850 Process-Buses and dynamic estimator. |
| {.pdf} | ⦁ | Simulation of Parallel Redundant WLAN with OPNET. |
| {.pdf} | ⦁ | SINEAX CAM Parameterization of IEC61850 bus card. |
| {.pdf} | ⦁ | SIPROTEC 4, SIPROTEC easy, SIPROTEC 600 Series, Communication, Accessories. |
| {.pdf} | ⦁ | SIPROTEC 5 Communication protocol IEC 60870-5-103. |
| {.pdf} | ⦁ | SIPROTEC 5 Communication Protocol IEC 60870-5-104. |
| {.pdf} | ⦁ | SIPROTEC 5 Communication protocol IEC 61850. |
| {.pdf} | ⦁ | SIPROTEC 5 Modbus. |
| {.pdf} | ⦁ | SIPROTEC 5 Process Bus. |
| {.pdf} | ⦁ | SIPROTEC 5Communication protocol DNP3. |
| {.pdf} | ⦁ | SIPROTEC 7SC805. |
| {.pdf} | ⦁ | SIPROTECMerging Unit 6MU805 V4.01 Manual. |
| {.pdf} | ⦁ | SMART GRID COMMUNICATIONS AND MEASUREMENT TECHNOLOGY. |
| {.pdf} | ⦁ | smart grids. |
| {.pdf} | ⦁ | The Smart Substatiion usiing IIEC 61850 Ediitiion 2. |
| {.pdf} | ⦁ | Solutions for Digital Substation. |
| {.pdf} | ⦁ | SOLVING ELECTRICAL SUBSTATION TIMING PROBLEMS. |
| {.pdf} | ⦁ | Stand Alone Merging Unit User Guide MGU010000. |
| {.pdf} | ⦁ | A Study on GOOSE Communication based on lEC61850 using MMS Ease Lite. |
| {.pdf} | ⦁ | Substation Automation Process Bus. |
| {.pdf} | ⦁ | Substation Automation Systems. |
| {.pdf} | ⦁ | A Survey of Communication Network Paradigms for Substation Automation. |
| {.pdf} | ⦁ | A Survey of Ethernet LAN Security. |
| {.pdf} | ⦁ | SWITCHGEAR OPTIMIZATION USING IEC 61850-9-2. |
| {.pdf} | ⦁ | Switchgear Optimization Using IEC 61850-9-2 and Non-Conventional Measurements. |
| {.pdf} | ⦁ | Synchronized Phasor Measurements and Their Applications. |
| {.pdf} | ⦁ | Synchrophasor Standards Development – IEEE C37.118 & IEC 61850. |
| {.pdf} | ⦁ | System 800xA IEC 61850 Connect Configuration. |
| {.pdf} | ⦁ | System 800xA IEC 61850 Engineering Workflow. |
| {.pdf} | ⦁ | System Engineer Configures IEC 61850 Gateway to DNP3 Substation. |
| {.pdf} | ⦁ | System-Level Tests of Transformer Differential Protection Using an IEC 61850 Process Bus. |
| {.pdf} | ⦁ | TCP/IP Protocol Suite. |
| {.pdf} | ⦁ | Technical Requirements for DER Integration Architectures. |
| {.pdf} | ⦁ | Teleprotection over an IP/MPLS Network. |
| {.pdf} | ⦁ | Testing a SIPROTEC GOOSE bus protection scheme using an OMICRON CMC. |
| {.pdf} | ⦁ | Time Signal Distributor. |
| {.pdf} | ⦁ | Time Signal Distributor. |
| {.pdf} | ⦁ | Time Synchronization (IEEE 1588) and Seamless Communication Redundancy (IEC 62439-3) Techniques for Smart Grid Substations. |
| {.pdf} | ⦁ | Time Synchronized Low-Voltage Measurements for Smart Grids. |
| {.pdf} | ⦁ | Towards Implementation of IEC 61850 GOOSE Messaging in Event-Driven IEC 61499 Environment. |
| {.pdf} | ⦁ | Traffic Generation of IEC 61850 Sampled Values. |
| {.pdf} | ⦁ | Transforming Critical Communications Networks for Substation Automation Communications network infrastructure requirements and architectures. |
| {.pdf} | ⦁ | Two Improvements Related to Overcurrent Functions for Bus Protection in Distribution Systems. |
| {.pdf} | ⦁ | Use of IEEE 1588–2008 for a Sampled Value Process Bus in Transmission Substations. |
| {.pdf} | ⦁ | Use of Precision Time Protocol to Synchronize Sampled-Value Process Buses. |
| {.pdf} | ⦁ | User Experiences Implementing IEC61850 in Intelligent Electronic Devices. |
| {.pdf} | ⦁ | A user-friendly implementation of IEC 61850 in a new generation of protection and control devices. |
| {.pdf} | ⦁ | Using OPNET to Model and Evaluate the MU Performance Based on IEC 61850-9-2LE. |
| {.pdf} | ⦁ | Utilization of GOOSE in MV Substation. |
| {.pdf} | ⦁ | Utilizing IEC 61850, Ethernet, and IP Standards for Integrated Substation Communications. |
| {.pdf} | ⦁ | VAMP RELAYS IEC 61850 interface Configuration instructions. |
| {.pdf} | ⦁ | The Virginia Tech Calibration System. |
| {.pdf} | ⦁ | Virtual Power Plant for Grid Services using IEC 61850. |
| {.pdf} | ⦁ | VSE 006 IEC 61850 interface module. |
| {.pdf} | ⦁ | VSE 006 IEC 61850 interface module Configuration instructions. |
| {.pdf} | ⦁ | A Web-Based Remote Access Laboratory Using SCADA. |
| {.pdf} | ⦁ | What Is IEC 61850?. |
| {.pdf} | ⦁ | What Protection Engineers Need to Know About Networking. |
| {.pdf} | ⦁ | White Paper on Standards for DER Communications Using IEC 61850. |
| {.pdf} | ⦁ | Wide area voltage protection. |
| {.pdf} | ⦁ | Wide-Area Ethernet Network Configuration for System Protection Messaging. |
| {.pdf} | ⦁ | Wide-Area Ethernet Network Configuration for System Protection Messaging. |
| {.pdf} | ⦁ | Wide-Area Protection and Power System Utilization. |
| {.pdf} | ⦁ | (2003). “Communication networks and systems in substations – Part 1: Introduction and overview.” |
| {.pdf} | ⦁ | (2003). “Communication networks and systems in substations – Part 2: Glossary.” |
| {.pdf} | ⦁ | (2003). “Communication networks and systems in substations – Part 3: General requirements.” |
| {.pdf} | ⦁ | (2003). “Communication networks and systems in substations – Part 4: System and project management.” |
| {.pdf} | ⦁ | (2003). “Communication networks and systems in substations – Part 5: Communication requirements for functions and device models.” |
| {.pdf} | ⦁ | (2003). “COMMUNICATION NETWORKS AND SYSTEMS IN SUBSTATIONS Part 10: Conformance Testing.” |
| {.pdf} | ⦁ | (2003). “IEEE Standard Test Method for Use in the Evaluation of Message Communications Between Intelligent Electronic Devices in an Integrated Substation Protection, Control, and Data Acquisition System.” |
| {.pdf} | ⦁ | (2005). “Communication networks and systems in substations – Part 7-3: Basic communication structure for substation and feeder equipment – Common data classes.” |
| {.pdf} | ⦁ | (2005). “Communication networks and systems in substations – Part 7-4: Basic communication structure for substation and feeder equipment – Compatible logical node classes and data classes.” |
| {.pdf} | ⦁ | (2005). “Communication networks and systems in substations – Part 9-1: Specific Communication Service |
| {.pdf} | ⦁ | Mapping (SCSM) – Sampled values over a serial unidirectional multidrop point to point link.” |
| {.pdf} | ⦁ | (2007). “Communication networks and systems in substations – Part 7-1: Basic communication structure for substation and feeder equipment – Principles and models.” |
| {.pdf} | ⦁ | (2009). “Communication networks and systems for power utility automation – Part 7-420: Basic communication structure – Distributed energy resources logical nodes.” |
| {.pdf} | ⦁ | (2010). “Communication networks and systems for power utility automation – Part 7-2: Basic information and communication structure – Abstract communication service interface (ACSI).” |
| {.pdf} | ⦁ | (2010). “Communication networks and systems for power utility automation – Part 90-1: Use of IEC 61850 for the communication between substations.” |
| {.pdf} | ⦁ | (2011). “Communication networks and systems for power utility automation – Part 8-1: Specific communication service mapping (SCSM) – Mappings to MMS (ISO 9506-1 and ISO 9506-2) and ISO/IEC 8802-3.” |
| {.pdf} | ⦁ | (2011). “Communication networks and systems for power utility automation – Part 9-2: Specific communication service mapping (SCSM) – Sampled values over ISO/IEC 8802-3.” |
| {.pdf} | ⦁ | (2012). “Communication networks and systems for power utility automation – Part 6: Configuration description language for communication in electrical substations related to IEDs.” |
| {.pdf} | ⦁ | (2012). “Communication networks and systems for power utility automation – Part 90-5: Use of IEC 61850 to transmit synchrophasor information according to IEEE C37.118.” |
| {.pdf} | ⦁ | (2013). “Communication networks and systems for power utility automation – Part 90-7: Object models for power converters in distributed energy resources (DER) systems.” |
| {.pdf} | ⦁ | (2013). “IEEE c37.242 IEEE Guide for Synchronization, Calibration, Testing, and Installation of Phasor Measurement Units (PMUs) for Power System Protection and Control.” |
| {.pdf} | ⦁ | (2014). “IEEE Recommended Practice for Network Communication in Electric Power Substations.” |
| {.pdf} | ⦁ | on an electric power substation, Internet protocol (IP) networks are provided. For the power |
| {.pdf} | ⦁ | engineer new to IP networking, this document provides an introduction to the concepts that need |
| {.pdf} | ⦁ | to be mastered as well as specific recommendations to follow when deploying the technologies. |
| {.pdf} | ⦁ | For equipment manufacturers and system integrators, it provides direction and requirements to |
| {.pdf} | ⦁ | facilitate interoperable electric utility information networks |
| {.pdf} | ⦁ | Ali, I., and M. S. Thomas (2011). GOOSE-based protection scheme implementation & testing in a laboratory. Innovative Smart Grid Technologies (ISGT), 2011 IEEE PES. |
| {.pdf} | ⦁ | Almas, M. S., et al. (2014). Synchrophasor network, laboratory, and software applications developed in the STRONg<sup>2</sup>rid project. PES General Meeting | Conference & Exposition, 2014 IEEE. |
| {.pdf} | ⦁ | Antonova, G., et al. (2011). Communication redundancy for substation automation. Protective Relay Engineers, 2011 64th Annual Conference for. |
| {.pdf} | ⦁ | Apostolov, A., et al. (2006). A Distributed Recording System Based on IEC 61850 Process Bus. Power Systems Conference: Advanced Metering, Protection, Control, Communication, and Distributed Resources, 2006. PS ’06. |
| {.pdf} | ⦁ | Apostolov, A. and B. Vandiver (2011). IEC 61850 GOOSE applications to distribution protection schemes. Protective Relay Engineers, 2011 64th Annual Conference for. |
| {.pdf} | ⦁ | Astarloa, A., et al. (2013). System-on-Chip implementation of Reliable Ethernet Networks nodes. Industrial Electronics Society, IECON 2013 – 39th Annual Conference of the IEEE. |
| {.pdf} | ⦁ | Atienza, E. (2010). Testing and troubleshooting IEC 61850 GOOSE-based control and protection schemes. Protective Relay Engineers, 2010 63rd Annual Conference for. |
| {.pdf} | ⦁ | Bhardwaj, V., et al. (2014). A review of various standards for the digital substation. Green Computing Communication and Electrical Engineering (ICGCCEE), 2014 International Conference on. |
| {.pdf} | ⦁ | Bonfiglio, A., et al. (2013). The smart microgrid pilot project of the University of Genoa: Power and communication architectures. AEIT Annual Conference, 2013. |
| {.pdf} | ⦁ | Castello, P., et al. (2014). Improving the availability of distributed PMU in electrical substations using wireless redundant process bus. Instrumentation and Measurement Technology Conference (I2MTC) Proceedings, 2014 IEEE International. |
| {.pdf} | ⦁ | Chao, Z., et al. (2009). An integrated PMU and protection scheme for power systems. Universities Power Engineering Conference (UPEC), 2009 Proceedings of the 44th International. |
| {.pdf} | ⦁ | Dan, Z., et al. (2010). A new scheme of control and protection based on utilizing phasor measurement technique. Control and Decision Conference (CCDC), 2010 Chinese. |
| {.pdf} | ⦁ | Darby, A. B., et al. (2014). Experience using PRP Ethernet redundancy for Substation Automation Systems. Developments in Power System Protection (DPSP 2014), 12th IET International Conference on. |
| {.pdf} | ⦁ | Das, N., et al. (2013). Process-to-bay level peer-to-peer network delay in IEC 61850 substation communication systems. Power Engineering Conference (AUPEC), 2013 Australasian Universities. |
| {.pdf} | ⦁ | De Dominicis, C. M., et al. (2010). Experimental evaluation of synchronization solutions for substation automation systems. Instrumentation and Measurement Technology Conference (I2MTC), 2010 IEEE. |
| {.pdf} | ⦁ | Dolezilek, D. (2010). Case Study Examples of Interoperable Ethernet Communications within Distribution, Transmission, and Wide-Area Control Systems. Communications Workshops (ICC), 2010 IEEE International Conference on. |
| {.pdf} | ⦁ | Dutra, C. A., et al. (2014). Process bus reliability analysis. Developments in Power System Protection (DPSP 2014), 12th IET International Conference on. |
| {.pdf} | ⦁ | Feuerhahn, S., et al. (2011). Comparison of the communication protocols DLMS/COSEM, SML, and IEC 61850 for smart metering applications. Smart Grid Communications (SmartGridComm), 2011 IEEE International Conference on. |
| {.pdf} | ⦁ | Gajic, Z., et al. (2010). Using IEC 61850 analog goose messages for OLTC control of parallel transformers. Developments in Power System Protection (DPSP 2010). Managing the Change, 10th IET International Conference on. |
| {.pdf} | ⦁ | GE “Communiicatiion Protocolls.” |
| {.pdf} | ⦁ | Georg, H., et al. (2013). Performance evaluation of time-critical communication networks for Smart Grids based on IEC 61850. Computer Communications Workshops (INFOCOM WKSHPS), 2013 IEEE Conference on. |
| {.pdf} | ⦁ | Gonzalez-Redondo, M. J., et al. (2013). IEC 61850 GOOSE transfer time measurement in the development stage. Industrial Electronics (ISIE), 2013 IEEE International Symposium on. |
| {.pdf} | ⦁ | Hakala-Ranta, A., et al. (2009). Utilizing possibilities of IEC 61850 and goose. Electricity Distribution – Part 1, 2009. CIRED 2009. 20th International Conference and Exhibition on. |
| {.pdf} | ⦁ | Hoga, C. (2011). Seamless communication redundancy of IEC 62439. Advanced Power System Automation and Protection (APAP), 2011 International Conference on. |
| {.pdf} | ⦁ | Huu-Dung, N., et al. (2014). An improved High-availability Seamless Redundancy (HSR) for dependable Substation Automation System. Advanced Communication Technology (ICACT), 2014 16th International Conference on. |
| {.pdf} | ⦁ | Hyo-Sik, Y., et al. (2007). Communication Networks for Interoperability and Reliable Service in Substation Automation System. Software Engineering Research, Management & Applications, 2007. SERA 2007. 5th ACIS International Conference on. |
| {.pdf} | ⦁ | Ingram, D. M. E., et al. (2011). Multicast traffic filtering for sampled value process bus networks. IECON 2011 – 37th Annual Conference on IEEE Industrial Electronics Society. |
| {.pdf} | ⦁ | Ingram, D. M. E., et al. (2012). “Use of Precision Time Protocol to Synchronize Sampled-Value Process Buses.” Instrumentation and Measurement, IEEE Transactions on 61(5): 1173-1180. |
| {.pdf} | ⦁ | Ingram, D. M. E., et al. (2013). “Network Interactions and Performance of a Multifunction IEC 61850 Process Bus.” Industrial Electronics, IEEE Transactions on 60(12): 5933-5942. |
| {.pdf} | ⦁ | Janssen, M. C., et al. (2011). Bringing IEC 61850 and Smart Grid together. Innovative Smart Grid Technologies (ISGT Europe), 2011 2nd IEEE PES International Conference and Exhibition on. |
| {.pdf} | ⦁ | Khan, R. H., et al. (2013). Pilot protection schemes over a multi-service WiMAX network in the smart grid. Communications Workshops (ICC), 2013 IEEE International Conference on. |
| {.pdf} | ⦁ | Kirrmann, H., et al. (2011). Seamless and low-cost redundancy for substation automation systems (high availability seamless redundancy, HSR). Power and Energy Society General Meeting, 2011 IEEE. |
| {.pdf} | ⦁ | Martin, K. E., et al. (2014). “An Overview of the IEEE Standard C37.118.2— Synchrophasor Data Transfer for Power Systems.” Smart Grid, IEEE Transactions on 5(4): 1980-1984. |
| {.pdf} | ⦁ | Mekkanen, M., et al. (2013). Reliability evaluation and comparison for next-generation substation function based on IEC 61850 using Monte Carlo simulation. Communications, Signal Processing, and their Applications (ICCSPA), 2013 1st International Conference on. |
| {.pdf} | ⦁ | Mekkanen, M., et al. (2014). Analysis and methodology for measuring the IEC61850 GOOSE messages latency: Gaining interoperability testing. Computer Applications and Information Systems (WCCAIS), 2014 World Congress on. |
| {.pdf} | ⦁ | Mo, J., et al. (2010). Evaluation of process bus reliability. Developments in Power System Protection (DPSP 2010). Managing the Change, 10th IET International Conference on. |
| {.pdf} | ⦁ | Ouellette, D. S., et al. (2010). Using a real-time digital simulator to affect the quality of IEC 61850 GOOSE and sampled value data. Developments in Power System Protection (DPSP 2010). Managing the Change, 10th IET International Conference on. |
| {.pdf} | ⦁ | Parikh, P., et al. (2013). Fault location, isolation, and service restoration (FLISR) technique using IEC 61850 GOOSE. Power and Energy Society General Meeting (PES), 2013 IEEE. |
| {.pdf} | ⦁ | Ptaszynski, M., and P. Wronek (2014). Mikronika’s new solutions for power substations with the process of bus technology. Signals and Electronic Systems (ICSES), 2014 International Conference on. |
| {.pdf} | ⦁ | Ransom, D. L., and C. Chelmecki (2014). “Using GOOSE Messages in a Main– Tie– Main Scheme.” Industry Applications, IEEE Transactions on 50(1): 17-24. |
| {.pdf} | ⦁ | Selga, J. M., et al. (2013). “Solutions to the Computer Networking Challenges of the Distribution Smart Grid.” Communications Letters, IEEE 17(3): 588-591. |
| {.pdf} | ⦁ | Seung-Ho, Y., et al. (2012). Performance analysis of IEC 61850 based substation. Advanced Communication Technology (ICACT), 2012 14th International Conference on. |
| {.pdf} | ⦁ | Sichwart, N., et al. (2013). Transformer Load Taps Changer control using IEC 61850 GOOSE messaging. Power and Energy Society General Meeting (PES), 2013 IEEE. |
| {.pdf} | ⦁ | Sidhu, T., et al. (2011). Configuration and performance testing of IEC 61850 GOOSE. Advanced Power System Automation and Protection (APAP), 2011 International Conference on. |
| {.pdf} | ⦁ | Sidhu, T. S., et al. (2010). Packet scheduling of GOOSE messages in IEC 61850 based substation intelligent electronic devices (IEDs). Power and Energy Society General Meeting, 2010 IEEE. |
| {.pdf} | ⦁ | Skendzic, V., and A. Guzma (2006). Enhancing Power System Automation Through the Use of Real-Time Ethernet. Power Systems Conference: Advanced Metering, Protection, Control, Communication, and Distributed Resources, 2006. PS ’06. |
| {.pdf} | ⦁ | Song, Y., et al. (2010). Analysis of the reliability of IED and GOOSE network in 500kV substation based on IEC61850 standard. Computer Application and System Modeling (ICCASM), 2010 International Conference on. |
| {.pdf} | ⦁ | Sun, X., and M. Redfern (2011). Process Bus Configurations for Protection Schemes in the Digital Substation: IEC 61850. Universities’ Power Engineering Conference (UPEC), Proceedings of 2011 46th International. |
| {.pdf} | ⦁ | Sykes, J., et al. (2006). Implementation and Operational Experience of a Wide Area Special Protection Scheme on the SRP System. Power Systems Conference: Advanced Metering, Protection, Control, Communication, and Distributed Resources, 2006. PS ’06. |
| {.pdf} | ⦁ | Thanos, D., et al. (2012). P& C engineering concepts applied to the cyber security of the power grid. Protective Relay Engineers, 2012 65th Annual Conference for. |
| {.pdf} | ⦁ | Thomas, M. S., and I. Ali (2010). “Reliable, Fast, and Deterministic Substation Communication Network Architecture and its Performance Simulation.” Power Delivery, IEEE Transactions on 25(4): 2364-2370. |
| {.pdf} | ⦁ | Viet Phong, T., et al. (2013). Real-time modeling and model validation of synchronous generator using synchrophasor measurements. North American Power Symposium (NAPS), 2013. |
| {.pdf} | ⦁ | Xiaoqun, L., et al. (2011). Design and Realization of FTU Message Transmission Process Based on GOOSE Communication Mechanism. Intelligent Human-Machine Systems and Cybernetics (IHMSC), 2011 International Conference on. |
| {.pdf} | ⦁ | Xiaosheng, L., et al. (2014). The research on reliability and real-time of the scheme of process layer GOOSE network in smart substation based on artificial cobweb topology structure. Power Electronics Conference (IPEC-Hiroshima 2014 – ECCE-ASIA), 2014 International. |
| {.pdf} | ⦁ | Xiaosheng, L., et al. (2014). “A High-Reliability and Determinacy Architecture for Smart Substation Process-Level Network Based on Cobweb Topology.” Power Delivery, IEEE Transactions on 29(2): 842-850. |
| {.pdf} | ⦁ | Yang, C.-W., et al. (2014). Towards the implementation of IEC 61850 GOOSE messaging in an event-driven IEC 61499 environment. Emerging Technology and Factory Automation (ETFA), 2014 IEEE. |
| {.pdf} | ⦁ | Yang, L., et al. (2009). A synchronized event logger for substation topology processing. Power Engineering Conference, 2009. AUPEC 2009. Australasian Universities. |
| {.pdf} | ⦁ | Yarza, J. M., and R. Cimadevilla (2014). Advanced tap changer control of parallel transformers based on IEC 61850 GOOSE service. T&D Conference and Exposition, 2014 IEEE PES. |
| {.pdf} | ⦁ | Zhen, W., et al. (2014). Fault information and diagnosis modeling of the online communication monitoring system for the digital substation. PES General Meeting | Conference & Exposition, 2014 IEEE. |
Practical Training Course on IEC 61850, Contact Us
Electrical Protection Course Materials (Basic)
Electrical Protection Course Materials (Basic)
The UCA is implementing changes to the IEC 61850 certification testing program to follow IEC requirements that only one revision of a standard can be valid at one time. Edition 1 was officially withdrawn by the IEC in December 2012 when Edition 2 became the current revision of the IEC 61850 standard. The UCA has therefore decided to phase out the issuing of Edition 1 only certificate and transition to Edition 2 conformance test certificates. The new Edition 2 conformance tests will include an option for certifying backward compatibility for Edition 1. This will allow new test certificates to cover both Edition 1 and 2 as required by utilities that install new equipment into existing Edition 1 systems or mixed systems (containing Ed. 1 and 2 devices).
The end-of-life date for Edition 1 conformance testing and certification is targeted for December 31, 2020. However, the actual date may change depending on when updates to Edition 2 conformance tests are published with procedures for testing Edition 1 backward compatibility. Please read the official press release from the UCA for many more details
Announcement of End-of-Life for IEC 61850 Edition 1 Certification
The IEC 61850 testing groups, within the UCA IUG, have concluded that the UCA IUG must enforce testing by the IEC position that there is one valid revision of a standard at any given time. Testing to a withdrawn standard is not consistent with the IEC position and would lead to supporting testing and certification of Edition 1, Edition 2, Edition 3, etc.
Simultaneously long into the future. In the review of the current IEC 61850 QAP Addendum, it has become clear that this was never the intent. Furthermore, the testing groups recognize that an abrupt and immediate transition of testing from one version to another would be very disruptive to all impacted parties. The current IEC 61850 QAP Addendum is lacking adequate guidance for the process of updating the conformance testing procedures in synchronization with the standard. Therefore, to ensure a timely transition to new versions of standards while supporting a stable and growing market for IEC 61850 devices and applications the IEC 61850
QAP Addendum is being updated to define a migration path for how testing procedures are synchronized to new versions of the standards as follows:
- A guaranteed minimum period from the publication of a major revision of the IEC 61850 standard. Since the IEC process for releases is a 5-year interval, the current proposal is that conformance testing of a specific major release of 61850 should be guaranteed to be no less than 10 years. It is thought that this guidance allows utility stability for project planning.
- Upon the publication of a new release, which causes the withdrawal of the previous IEC standard, the conformance test procedures will need to be updated to not only test the conformance to the new standard but also backward compatibility to the previous standard and thereby provide utilities the assurance that new devices can be integrated into older systems protecting utility investment.
- Once the revised test procedures are available, and the 10-year minimum has been achieved, the UCA Conformance Testing for the older standard would cease
- Conformance certificates shall indicate if the certificate is being issued based on withdrawn standards.
Edition 1 Conformance Testing is currently outside of these criteria being proposed because the withdrawal date of Edition 1 of the standard was December 2012 and the publication date of Edition 1 was May 2005. The end-of-life for UCA Edition 1 Only Conformance Testing andCertification is targeted for December 31, 2020, and would still require that the backward.
compatibility testing is available thereafter.
This announcement is being provided so that the information needed for utility project planning and to protect utility investment in deployments is based upon older versions of the standard. What is being proposed does not mean that older versions of devices would not be available, only that newer versions would be conformance tested to the current version and for compatibility with the older version.
Reference: (http://www.ucaiug.org)
Save your time using templates in Protection and Automation in your electrical CAD.
230 / 132kV Substation
Panel Layouts
Diagram
230/132kV Substation Panel Layouts Diagram
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A real-world representation of the shading from surrounding objects is extremely important for precisely calculating yields. You’re therefore looking for a program that takes shading into account as analytically as possible? PV*SOL does just that! You can visualize all roof-integrated or mounted systems – even on the ground – with up to 5,000 modules in 3D and calculate shading based on 3D objects.
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PVsyst
PVsyst is a PC software package for the study, sizing, simulation, and data analysis of complete PV systems. PVsyst is designed to be used by architects, engineers, and researchers. It is also a very useful educative tool. It includes a detailed contextual Help menu that explains the procedures and models that are used and offers a user-friendly approach with a guide to developing a project. PVsyst can import meteo data from many different sources, as well as personal data. PVsyst presents results in the form of a full report, specific graphs, and tables, and data can be exported for use in other software.
Management of the project: For a given project (a defined site and meteo), you can construct several variations for your system (“calculation versions”).
System design board: The system design is based on a quick and simple procedure:
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Specialized tools are also provided for the evaluation of the wiring losses (and other losses like the module quality), the mismatch between modules, soiling, thermal behavior according to the mechanical mounting, system unavailability, etc.
Simulation and results report: The simulation calculates the distribution of energies throughout the year.
Main results:
1. The total energy production [MWh/y] is essential for the evaluation of the PV system’s profitability.
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3. The specific energy [kWh/kWp] is an indicator of production based on the available irradiation (location and orientation).
A powerful tool for a quick analysis of the system’s behavior, and potential improvements in the design.
RETScreen Expert
The RETScreen Clean Energy Management Software (usually shortened to RETScreen) is a software package developed by the Government of Canada. RETScreen is a Clean Energy Management Software system for energy efficiency, renewable energy, and cogeneration project feasibility analysis as well as ongoing energy performance analysis. RETScreen Expert, an advanced premium version of the software, is available in Viewer mode completely free of charge.
Providing Electric Power System Protection:
Increase efficiency and avoid costly mistakes by keeping yourself and your company’s employees trained on the protection of equipment.
Elec-Engg provides training materials on designing electrical protection schemes including the studies, programming, and integration of protective relays and their peripheral systems. Our training materials can be distributed in several ways.
Products: (https://elec-engg.com/category/products/)
Training Course: (https://elec-engg.com/category/training-course/)
Training course materials: (https://elec-engg.com/category/course/)
Our customers include large and small utilities, industrial plants, construction companies, project developers, system integrators, contractors, consultants, and electric transmission companies.
The training contains the INCOMING & COUPLING WIRING & TERMINATION DIAGRAM.
This article is planned to be a guideline for secondary protection practices basic calculations and setting procedures for DEMA MCR 310 Electronic Overcurrent Protection Relay. To form a basis for the calculations, a sample project /with the single line diagram on the left is created. When evaluating the project, it must be noted that;
- The project and single line diagram are completely fiction,
- The component ratings are given as sample values and may not necessarily represent any component ratings in the market,
- The component selections are not based on engineering fundamentals and thus must not be translated as selection suggestions or templates.
The following pdf contains calculations, estimations, and graphics that show the fundamentals of protection for a power transformer by using the DEMA MCR 310 Electronic Overcurrent Protection Relay.
Functional description for TCS relay 7PA30
RELAY 7PA30*2-1AA00
The 7PA30 relay is designed to supervise the trip circuit for one trip coil of a circuit breaker. The trip circuit wiring is supervised from the positive supply to the negative supply whilst the circuit breaker is open or closed.
FEATURES
- The 7PA30 relay monitors the trip supply and correct state of fuses or miniature circuit breakers of the circuit. It will initiate an alarm if the supply voltage falls below the assigned drop-out voltage
- With the CB in the open and closed position, the 7PA30 supervises:
• The trip circuit wiring
• The CB’s trip coil
• The CB’s 52a and 52b auxiliary contacts
The supervision is done with a small current that flows through the supervision-circuit in series with the trip coil of the circuit breaker. The supervision current is always less than 1.4 mA. This makes the 7PA30 relay suitable for the supervision of circuit breakers with low power consumption down to 4.5 W. Therefore external current limiting resistors are not needed because these resistors are installed inside the 7PA30 TCS relay.
- Indicates if the trip coil fails to respond to a trip command. The operation time of the circuit breaker must be less than 150 ms. If it is longer, the 7PA30 will drop off and indicate a circuit failure.
- Correct operation is shown via:
– An illuminated green LED.
– Two potential-free change-over contacts
Both contacts and the LED are in series and therefore synchronized. In normal conditions, the 7PA30 cannot produce an unwanted trip due to the high impedance of its supervision circuit. Measures are taken to avoid a short circuit in the supervision module by integrating a component that melts in this case, avoiding an unwanted operation.
- The 7PA30 allows a latched protection trip contact (trip contact from a lock-out relay).
FUNCTIONAL DIAGRAM
The connection diagram below shows the 7PA30 with the complete trip circuit up to the trip coil of the circuit breaker.
The contacts in the diagram above are shown without an auxiliary supply.
OPERATION
The LED is on and both contacts are in close position (terminal 5-9 and 6-10) whenever the trip circuit is healthy. The supervision is performed under the 4 possible conditions described in the following pages.
- Supervision with CB closed
The supervision circuit is indicated (via K1, 52a, and the CB coil). K2 is not energized.
Different situations that can occur:
1.- If the trip supply falls below the assigned drop-off voltage, the drop-off voltage control module will detect it. Therefore K5 will drop-off and this will lead to the de-energization of K6 and K3 after 150ms. This will result in a trip circuit supervision alarm.
2.- In case of a broken connection in the supervision circuit, K1 will drop off and this will lead to the de-energization of K6 and K3 after 150ms. This will result in a trip circuit supervision alarm.
- Supervision during Trip
In this situation, the trip contact of the protection relay and the circuit breaker is closed. The supervision circuit is indicated (via 52a and the CB coil). K1 and K2 are not energized.
The operation time of the CB must be less than 150 ms, in order to avoid the drop-off of the relay. K6 is kept energized with an internal capacitor and therefore also the LED and K3 remain energized. This will avoid an unwanted alarm during operation.
- Supervision with CB open and protection trip contact closed
Trip contact is still closed in this situation although the CB has already opened. The supervision circuit is indicated (via K2, 52b, and the CB coil). K1 is not energized.
In this situation, the trip contact can remain closed, e.g. if the protection relay trip contact belongs to a lock-out relay.
In this case, the trip contact remains closed until the trip will be recognized and the lockout relay will be reset.
- Supervision with CB open
In this situation the trip contact of the protection relay and the circuit breaker is open. The supervision circuit is indicated. K1 and K2 are energized.
The following table resumes the four situations explained before:
SELECTION AND ORDER NUMBER
Download PSCAD file:
- single and three-phase line with the fault
- Parallel Line and Parallel Line Ground with fault
- Series Capacitance
- Power swing testing
- CT Saturation
- Busbar Protection
- Inrush Current
- and much more …
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DIgSILENT has set standards and trends in power system modeling, analysis, and simulation for more than 25 years. The proven advantages of the PowerFactory software are its overall functional integration, its applicability to the modeling of generation-, transmission-, distribution- and industrial grids, and the analysis of these grids’ interactions. With PowerFactory Version 15, DIgSILENT presents a further step towards seamless integration of functionality and data management within a multi-user environment.
DIgSILENT PowerFactory is the most economical solution, as data handling, modeling capabilities, and overall functionality replace a set of other software systems, thereby minimizing project execution costs and training requirements. The all-in-one PowerFactory solution promotes a highly-optimized workflow. DIgSILENT PowerFactory is easy to use and caters to all standard power system analysis needs, including high-end applications in new technologies such as wind power and distributed generation and the handling of very large power systems. In addition to the stand-alone solution, the PowerFactory engine can be smoothly integrated into GIS, DMS, and EMS supporting open system standards.
Here are some key features of “DIgSILENT PowerFactory”:
- Geographic Diagrams and enhanced tools for visualizing topological network structures
- Optimal Power Supply Restoration functions
- Enhanced Reliability Assessment for balanced and unbalanced networks
- Voltage Profile optimization for bi-directional power flows
- Arc-Flash calculation (IEEE1584, NFPA 70E) incl. label printing
- Automatic Cable Sizing (IEC 60364-5-52, NF C15-100, NF C13-200, BS 7671, etc.)
- Static Motor Starting simulation
- Simulation Scan module
- Techno-Economic Evaluation of grid expansion strategies
- New and improved electrical models (MV load, secondary substations, single-phase static generator, PLL model, CVT, improved cable parameter calculation, etc.)
- Database offline mode with local caching and re-synchronization, automatic rule-based database housekeeping
- Revised user interface with tools for customization through user profiles
- New comprehensive real-world application examples with video presentations
Template networks in Digsilent to test the transient state package
- 2Bus: Parallel Line
- 9Bus: Example Digsilent: Power Swing
- Single Line
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IEC 61850 System Configurator V5.40
The IEC 61850 System Configurator enables you to configure and set parameters for IEC 61850 stations (Edition 1 and Edition 2). This tool allows you to manage sub-networks, network communicators, and their IP addresses and to connect the information items of different communicators.
The IEC 61850 standard has been defined in cooperation with manufacturers and users to create a uniform, future-proof basis for the protection, communication, and control of substations.
The advantages of using this protocol are as follows:
- Interoperability: With IEC 61850, you will not encounter protocol diversity and integration problems.
- Simpler Engineering: From engineering to implementation, from operation to service, it saves time and costs on configuration, commissioning, and maintenance.
- Reduction of costs: IEC 61850 replaces wiring among feeders, control switches, and signaling devices.
- Reliability: It uses only one communication channel for all the real-time data synchronized using Ethernet.
The IEC 61850 System Configurator is an application whose functionality has been designed especially for the following operating systems:
- Microsoft Windows 7 Professional and Enterprise/Ultimate 32-bit and 64-bit with Service Pack 1
- Microsoft Windows 8.1 Professional and Enterprise
- Microsoft Windows Server 2012 R2 64-bit with Service Pack 1 as a workstation computer
- Microsoft Windows 10 Professional and Enterprise 32-bit and 64-bit
- VMware support for virtual machines
Do you face the error ” Siemens IEC 61850 System Configurator has not been tested for this operating system”?
Do you face the error ” Siemens IEC 61850 System Configurator requires at least an earlier version of SYS-CON installed in the PC”?
These spreadsheets below will make your endless calculations much easier!
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- Calculation model for thermal relay Siemens 7SJ6
- Motor Protection Relay Selection Curves
- Over-current protection – INVERSE TIME O/C PROTECTION CALC – 51(N) – Directional OC
- Filter Design Calculation
- P63x Differential CurrentsCalculation MiCOM P634/P633/P632
- Calculating the operation current in Bias Differential Relays MiCOM P633
- POINT-TO-POINT METHOD OF SHORT CIRCUIT CALCULATIONS
- SLOPE CALCULATION OF LINE DIFF RELAY P543
- TMS Calculate
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Different technology has been used to implement protection functions that properly detect disturbances in the power systems and initiate the disconnection of the faulted components. Despite the developments of complex algorithms for implementing protection functions, microprocessor-based relays were marketed in the 1980s. Those relays performed essential functions, took advantage of the hybrid analog and digital techniques, and offered good economical solutions. The performance of these relays, however, was only adequate but their introduction did a lot of good to the highly conservative work of power system protection. Continuous advances in electronics, combined with extensive research conducted in microprocessor-based systems, led to a few applications in which a microprocessor relay performed multiple functions.
The following PDF is the report of the relaying practices subcommittee.
Download Understanding microprocessor-based technology applied to relaying
File Type: PDF
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The solutions from Siemens for energy automation offer a multitude of standardized configurations and functions for many typical tasks. These default settings allow the use of flexible products but at the same time is open for more challenging and customized applications. The acquisition of all kinds of data, computing, and automation functions, as well as versatile communication, can be very flexibly combined to create special solutions and to make integration into the existing system environment possible.
The process and visualization system SICAM SCC (SICAM Substation Control Center) is an important component of power automation solutions. Independent of the utilized substation, SICAM SCC can be used with both the power automation system.
SICAM PAS and also with the products of the SICAM RTU family. SICAM SCC can communicate directly with bay and protection devices that support the communications standard IEC 61850 and can be used for this as a cross-device HMI system. SICAM SCC is scalable for individual applications and supports efficient engineering for energy automation solutions of power utilities and industry.
Download SIEMENS Substation Automation System Part I (Practical)
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Download SIEMENS Substation Automation System Part II (Practical)
There are two sections in “Mapping\PAS_FS1\PASCC\PASCC1_Interface\HMI “. One is “Information-Monitoring Direction” and the other one is “Information-Command Direction”.
In “Information-Command Direction” we should select “ION\EMA “and check the parameters which we want to use in our system.
MODBUS-PASCC (EMA)
In “SICOM PAS CC \\ HMI\Graphic Designer “, we should create a window to show the parameters and double click on that.
If the text is bold, it means that there are some changes to that. So click on the bold icon.
If the item has value, we can right-click on that and select the tag. Then from “HMI\ION_EMA”, we can select the values.
IEC61850-PAS (REG-DA)
For the other manufacturer which supports IEC61850, they should provide relevant IEC61850 with the equipment. Here, for “REG-DA”, the IEC61850 file is “eberle35.icd”.
There are two options to add “REG-DA” in the Siemens Automaton System. One is with DIGSI and the other one is UI-Configuration.
DIGSI
We should import the IEC61850 file in our project.
A file with the name of “*.icd” with creating automatically. If the number of “REG-DA” is more than one, we should change the “REGS1” to “REGS2”. To do this, we can open “eberle35.icd” with notepad and edit the file accordingly.
The PC operating program DIGSI 4 is the user interface to all Siemens protection devices, up to and including SIPROTEC 4 and
SIPROTEC Compact. It has a simple and intuitive user interface. Using DIGSI 4, the parameters for the SIPROTEC devices are set
and evaluated – it is a tailor-made program for industrial and energy supply systems.
SICAMPAS/PQS has been designed as a modular system with open communication interfaces. It thus meets the requirements of state-of-the-art substation control and protection systems and the power management systems required for industrial manufacturing plants. Functions for power quality evaluation complement its versatile fields of application. The system component SICAM PAS UI – Configuration is responsible for:
• Configuration and parameterization of your plant
• Exchange of configuration data
IEC 61850 – Design a feeder
Example: Design a bay (one-and-half breaker) with distance and differential relays.
- The differential relay has a control LCD. So we want to control Q02 and Q03 with the relay.
- The diagram should be shown in LDC.
- Alarms and other parameters should send by the differential relay (GOOSE messages) and receive by the distance relay.
- Control from the control room
Configuration in DIGSI
At first, we should create the relays with relative MLFB. Add a Control Device group in the configuration matrix.
For simplicity, add Control Device 2 and Control Device 3 for CutOff2 and CutOff 3 respectively.
In Control Device2, select insert information for Q2. We want to control the Q2 form S=system and the position of Q2 with Binary Input (BI) 13 and 14.
If one of the inputs is true, it is open or closed. And if both of the BIs are true or false, it means an intermediate state.
From the list, select the Double point with zero states. Edit the name of the signal in Display text and Long text.
In the DP_I row (Dual Point indication), select BI 13 and 14 for Q2.
The source of the signal is System, so check the related box and set a name for that, here is Q2 and in switch type, select Disconnector.
Note: when we select the source for the signals, the Destination signals for BO with checked automatically. It means the signal will send to the system automatically.
In Control Device2, select insert information for Q02. We want to control the Q02 form S=system and the position of Q02 with Binary Input (BI) 11 and 12.
If one of the inputs is true, it is open or closed. And if both of the BIs are true or false, it is intermediate.
From the list, select the Double point with zero states. Edit the name of the signal in Display text and Long text.
In the DP_I row (Dual Point indication), select BI 11 and 12 for Q02.
The source of the signal is System, so check the related box and set a name for that, here is Q2, and in switch type, select Circuit Breaker.
For a circuit breaker, we want to add the counter to count the number of open and closed positions. So form the signal list, select Value Indication (VI), and add it to the system.
For the source signal select Circuit Breaker for the switch type. And for the Cycle counter select the signal which is selected in Value Indication (VI).
Note: when we select the source for the signals, the Destination signals for BO with checked automatically. It means the signal will send to the system automatically.
One of the common applications of GOOSE messages is to implement a ‘fast bus’ or ‘reverse interlocking’ bus protection scheme. In its most basic form, a directional overcurrent relay is installed on the incomer. If a fault is detected towards the bus the incomer relay will trip unless any of the feeder relays send it a blocking signal indicating that the fault is external to the bus.
Ideally, this type of scheme should be tested by primary or secondary injection into both the incomer and feeder relay at the same time. However, there are often cases when access to only a single relay at once is possible. Since IEC61850 is an international standard, the use of a third-party test tool is possible. One such test tool is the OMICRON CMC.
Method
The relay-relay GOOSE application is created in DIGSI IEC 61850 System Configurator. The pickup (‘start’) of the overcurrent elements in each of the feeder relays is mapped to a GOOSE input in the incomer relay. The configuration is via drag and drop – DIGSI automatically takes care of the necessary low-level details of the protocol.
DIGSI IEC 61850 System Configurator
If the GOOSE mapping has already been created in DIGSI, then getting this information into the OMICRON is as simple as exporting the Substation Configuration Description (SCD) file from DIGSI and importing it into the OMICRON GOOSE Configuration software. (Export DIGSI SCD file, and Import in to OMICRON GOOSE Configuration)
By connecting the OMICRON into either the subnet or directly into a relay, the OMICRON software allows the CMC to either simulate or subscribe to any of the stations. Again, the configuration of this is via drag and drop – the relevant goose data-set item is selected and mapped to a binary input or output of the CMC. These are then available for use as standard binary inputs/outputs in other parts of the Test Universe software.
GOOSE data set mapping in omicron
By use of the Omicron secondary injection combined with its GOOSE functions each of the SIPROTEC relays in the fast-bus scheme can be tested individually.
Test 1: Testing a feeder relay:
Testing of the feeder relay is to confirm that as soon as its overcurrent element picks up it transmits a suitable GOOSE blocking message. The Omicron is connected to inject a secondary current into the relay above the element pickup threshold. The Omicron is set to subscribe to the ‘Start’ GOOSE message expected to be transmitted by the relay. Since the SCD file was directly imported from DIGSI, all the protocol details of the GOOSE message will automatically be checked during the testing for conformance with what the incomer relay is expecting.
An Omicron test is created and executed to record the time taken from the injection of current to receipt of the GOOSE message. Typically times expected will be the pickup time of the relay element plus just a few milliseconds.
Test 2: Testing the incomer relay
The incomer relay is tested to confirm that when it receives a blocking message via GOOSE that its directional overcurrent element does not issue a trip (Figure 7). The OMICRON is configured to simulate the GOOSE message that would come from one of the feeder relays. For testing, activation of this GOOSE transmission is via any of the mapped binary output functions of the Test Universe application (Figure 6).
Using the State Sequencer, the first state can be set to inject voltage and current into the relay without any GOOSE message transmission. After a short time delay (to match that recorded in Test 1) the second state should keep the analog signals on, but activate the GOOSE message transmission by turning the relevant binary output on. A successful test is where the relay element does not trip.
Using a binary output to generate blocking GOOSE message
Testing Incomer blocking with received GOOSE message
Within DIGSI, the difference between being “devices” and “variants” may not be obvious or significant, until the need for remote engineering access is considered. Each time a new device object is created within a DIGSI Project, a unique VD address is assigned as part of the setting file. Thus DIGSI ensures each “device” in a project has a unique VD address (“variants” don’t have a unique VD address and retain the VD address from when the file was created).
One of the purposes of the VD address is to provide an added level of security to remote engineering access. When connecting a DIGSI session via the rear remote service interface, the original setting file is needed in DIGSI to permit the connection to the relay. DIGSI compares the VD address of the setting file to the VD address in the remote device, to help ensure the correct “remote” relay is actually being connected to.
(VD address = Virtual Device address)
Object (setting file) VD address is reported and can be changed in Properties
This document provides general information. You should follow your own network standard practices which may have specific procedures for the handling of device and variant files and assignment of VD addresses etc to support your specific commissioning/maintenance and remote engineering regimes. This is especially important where SICAM systems or IEC 61850 Protocols are used.
Note that the VD address is only ‘reported’ within the setting file “Interface Setting” section.
The VD address can be located and changed in the setting file via the Object Properties dialog. The VD address of the relay can be found via the LCD display using the appropriate front panel keys [Main Menu -> Settings (4) -> Setup/Extras (10) -> Device-ID (5)]
LOCAL & REMOTE CONNECTIONS
FRONT INTERFACE CONNECTIONS, PLUG & PLAY
When in front of a SIPROTEC 4 relay, the assumption is that you are an authorized person (by virtue of having access to the building), and that you have identified by panel labeling that you are connecting to the correct relay. Therefore, DIGSI permits connection to the relay front interface via “Plug & Play”.
What is Plug & Play?
Plug & Play is used to connect to a SIPROTEC device without the need to have a saved setting file (nor the need to know the relays VD address). Any setting file downloaded is of a SIPROTEC “variant” type.
Note that with Plug & Play, while you don’t need the original setting file, you must first have the matching parameter set installed on your PC. Parameter sets (DIGSI Device Drivers) are installed as part of the normal installation of DIGSI, during the “DIGSI Devices” installation phase, or as a subsequent download of a specific (updated) parameter set.
Plug & Play is the method recommended by HV Power for Technicians to capture copies of “as found” and “as left” setting files during any local work on a SIPROTEC 4 relay.
Other front panel connections:
Connection using a stored setting file by going “online” is also permitted (The VD address in the file is compared to that in the relay before allowing connection).
REAR SERVICE INTERFACE CONNECTIONS
Commonly the rear Service Interface on SIPROTEC relays are RS-485 ports (in systems other than those using IEC 61850 protocols). These rear Service Interfaces are normally daisy-chained, allowing one remote connection to be used to communicate to any SIPROTEC relay at the site.
To connect DIGSI via the rear service interface, you need the original setting file, as the connection is only permitted when the VD address of the file matches the intended relay. Note that if there are parameter value differences, such as old/new settings, provided the VD addresses match, the connection will occur, but with the choice to use either the relay data or the PC setting data given.
Plug & Play connection is not permitted over the rear Service Interface, as if remote, there would be no visual confirmation that you are connecting to the correct relay.
DEVICES & VARIANTS
With DIGSI setting files a SIPROTEC “device” is an object (setting file) with a unique VD address. A “variant” is an object (setting file) that is a copy of a “device” that has the same VD address as the original device.
Variants are identified in DIGSI Manager by the Var suffix in the name.
Variants are normally used where a temporary change to a setting file is required, such as creating an alternative setting (for the same relay) to be used when a line or transformer rating needs to be temporarily changed due to network maintenance, etc.
CREATING DEVICES & VARIANTS:
Insert new device: When inserting a new SIPROTEC device into a project (using the Device Catalogue), a “device” is created, and DIGSI automatically assigns a VD address that is unique to the project.
Plug & Play: Files created by Plug & Play will be of the variant type.
Copying Devices: Copy and Pasting a device in the DIGSI manager will create a new device (same settings, but with a different VD address). However, Copy and Pasting a variant will create another variant.
Create Variant: This command creates a variant file of an existing device or variant.
Import: When importing an object (setting file) into DIGSI, you are given the option to import as a variant or as a device.
Importing as a variant or device.
In general, if you are supplied a setting file to undertake work on a relay, such as for a setting change:
- Import it as a “variant” as this will not alter the VD address, thus an online connection to the relay will be possible. Future remote engineering connections should not be affected, as the VD address remains unchanged.
- Do not import the setting file as a “device” as this may cause DIGSI to reassign the VD address, thus an online connection to the relay will not be possible. You may need to change the VD address, or re-initialize the relay (see below cautions)
File >Reorganise
“Reorganising” a project (to clear free DIGSI memory) may cause the VD addresses within DIGSI to be changed.
Refer to the System Manual for notes on variants with regard to SICAM control center, IRC combinations, or process bus.
THE ROLE OF INITIALISING THE RELAY
A relay must be initialized at least once to allow communication with it. Normally relays are initialized by HV Power as part of our pre-delivery checks. Initialising is the process where a complete parameter set (a setting file) is loaded to the relay. This includes a VD address, thus providing a level of security for future remote engineering connections.
Warnings:
- Initialising clears any pre-existing device settings, fault records, and logs, etc from the relay, and
the relay is restarted - Initialization can only be done via the front interface connection
You will need to initialize the relay in the field only once during its first commissioning in order to load the designer’s intended setting file (with the specific intended VD address). Be aware of the above warnings and do not attempt to use Initialisation as a simple remedy for latter connection problems, without being aware of the implications.
By changing a VD address, depending upon your network’s remote engineering architecture, you may impact others’ ability to remotely connect to the relay, if they do not have access to the new VD address, or setting file.
A VD address in a relay can only be changed by the initialization/re-initialization process. It cannot be changed by the front panel keys; it cannot be changed by downloading a setting file with a modified VD address during plug & play connection, or via rear Service Interface. As relays cannot be initialized via the rear Service Interface, the VD address cannot be changed using the rear interface connection either.
VD & other addresses
With DIGSI and SIPROTEC 4 relays, there are actually several types of addresses including:
DIGSI4 VD address: This is the address given to the specific instance of DIGSI 4, The automatically assigned address is normally sufficient. The only time this would need to be changed is where simultaneous communication to both the front and rear service interfaces was required.
SIPROTEC-VD-addresses (VD, Mirror-VD, and redundant Mirror-VD): These are the VD addresses referred to in this document, controlled by the DIGSI Manager and transmitted to the SIPROTEC device to permit communication with the DIGSI Device Editor.
The Mirror-VD address and redundant Mirror-VD address are used for connection to control centers such as SICAM PAS.
SIPROTEC-T103 VD address: This address is used by IEC 103 communications to the System Interface (SCADA interface)
SICAM-Proxy VD Address: Used by SICAM Substation Management Systems for unique identification of SIPROTEC devices
IEC Link address: For front interface connections, this is 1. For rear Service Interface connections, if a star-coupler
is used, a unique IEC Link address has to be assigned to each SIPROTEC device (1 to 254)
For more information on VD addresses and communications, refer to Section 7 of the SIPROTEC System Description Manual
RS-485 Addressing & Star Couplers (IEC Link address)
The VD address should not be confused with the RS-485 address, which is different and additional. Where rear Service Interfaces are daisy-chained RS-485 circuits, each interface must be given a unique address. Figure 4 shows the “Address” field which should be set to a unique number (1 – 254) for each relay on a multi-drop connection to allow DIGSI to address a specific device. The same unique addressing requirement exists for connection of the Service Interface to Siemens star-coupler
RS-485 Daisy Chain Index
The Operator Interface Settings also has an “Address” setting similar to the Service Interface. Normally this is “1” as only one direct connection is made to this port at a time. However, it is possible to connect to multiple SIPROTEC Service Interfaces using Star-couplers and media converters, and thus this port can be given a unique address for DIGSI communications. In this case, all devices will “hear” the interrogation from DIGSI, but only the device with the matching DTE address (IEC Link address) will respond.
This provides a general overview of the process of setting/modifying DNP 3.0 maps in Siemens SIPROTEC 4 series Protection Relays, using DIGSI 4.
DNP 3.0 mapping information is part of the DIGSI “.dex” file information. It is not a separate file. The map is loaded/updated as part of the relay settings.
Mapping is achieved by routing items in the I/O matrix to/from the System Interface. (“System Interface” is Siemens term for the SCADA interface).
Note that if creating a setting file from a blank template, make sure the selected MLFB for the target relay includes a DNP protocol card, otherwise the points on the Matrix will not be able to be assigned to the DNP interface. [Right click to view the Properties on the setting file, prior to opening the file].
To set/change mapping, use the I/O Matrix
- Ensure the filter is selected to allow you to see Commands, Indications, or Measured Values, etc as required.
- Right-click and assign with “X” the desired items to be routed to the System Interface (S) – In the Source Colum for items to be controlled by SCADA, and the in Destination Colum for items to be output to SCADA
- Right-hand click in the left-hand columns (Number, Display text, Long Text, Type) and select Properties to access the dialog to change the DNP index points and scaling, etc
To print a copy of the DNP map
- Close the I/O Matrix
- Select File/Print, then select “Configuration – Short”, then “System Interface”
Notes/Warnings:
In the “Interfaces” object (below), the “Additional protocols at device” is used to set general SCADA parameters. Note that the below example shows “<see module-specific settings>” which indicates that the DNP map has been changed from the manufacturer’s standard. If you change this selection back to “DNP Map Standard…..”, all your DNP settings in the I/O matrix will be lost!
While the below appears to be a text report file, you can actually overwrite the settings to change the SCADA baud rate and other settings.
For further information:
- The SIPROTEC “System Manual” provides information about the common features across the entire SIPROTEC 4 range. This is a useful reference document.
- The Product Specific manual, e.g. 7SD610 Manual, refers to the specific hardware and protection functions of the specific relay variant.
- The Communication Manual, of which there are versions for each of the different Protocols supported, and also different versions for different SIPROTEC relays, gives the specific DNP mapping/protocol information.
All three manuals contain different information about DNP mapping.
Learning the fundamentals of relay testing, on your schedule. Learn how to efficiently test overcurrent, distance, and transformer differential relays with the OMICRON Test Universe. Our Training course provides you with relevant background information and takes your specific questions into account during the training. The material of the protective relay testing course is designed to help you to be a professional in this field.
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- Basics of Protection
- Power System Faults & Numerical Relay Fundamentals
- Feeder protection and relay coordination
- Basic Transformer protection
- Distance protection theory and application
- Power Swing and out of step testing
- Protection schemes Testing
- Advanced Differential protection
- IEC61850 Introduction
- IEC 61850 Process bus introduction
- Testing IEC 61850 based protection system
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Numerical Distance Protection: Principles and Applications by Gerhard Ziegler
Distance protection provides the basis for network protection in transmission systems and meshed distribution systems. This book covers the fundamentals of distance protection and the special features of numerical technology. The emphasis is placed on the application of numerical distance relays in distribution and transmission systems. This book is aimed at students and engineers who wish to familiarise themselves with the subject of power system protection, as well as the experienced user, entering the area of numerical distance protection. Furthermore, it serves as a reference guide for solving application problems. For this fourth edition all contents, especially the descriptions of numerical protection devices and the very useful appendix have been revised and updated.
Electromagnetic Transient Analysis and Protective Relaying Techniques for Power Transformers
by Xiangning Lin, 2015
An advanced level examination of the latest developments in power transformer protection This book addresses the technical challenges of transformer malfunction analysis as well as protection. One of the current research directions is the malfunction mechanism analysis due to the nonlinearity of the transformer core and comprehensive countermeasures for improving the performance of transformer differential protection. Here, the authors summarize their research outcomes and present a set of recent research advances in electromagnetic transient analysis, and the application of power transformer protections, and present a more systematic investigation and review in this field. This research area is still progressing, especially with the fast development of Smart Grid. This book is an important addition to the literature and will enhance significant advancement in research. It is a good reference book for researchers in power transformer protection research and a good textbook for graduate and undergraduate students in electrical engineering. Chapter headings include: Transformer differential protection principle and existing problem analysis; Malfunction mechanism analysis due to the nonlinearity of transformer core; Novel analysis tools on operating characteristics of Transformer differential protection; Novel magnetizing inrush identification schemes; Comprehensive countermeasures on improving the performance of transformer differential protection advanced level examination of the latest developments in power transformer protection presents a new and systematic view of power transformer protection, enabling readers to design new models and consider fresher design approaches offers a set of approaches to optimize the power system from a microeconomic point of view.
Protective Relaying Theory and Applications
by Walter A. Elmore
Targeting the latest microprocessor technologies for more sophisticated applications in the field of power system short circuit detection, this revised and updated source imparts fundamental concepts and breakthrough science for the isolation of faulty equipment and minimization of damage in power system apparatus–clearly describing key procedures, devices, and elements crucial to the protection and control of power system function and stability.
Protective Relaying: Principles and Applications, Third Edition
by Domin, Thomas J.
Technological advances and structural changes within the electric utility industry mandate that protection engineers develop a solid understanding of the related new technologies as well as of power system operations and economics to function proficiently. Continuing in the bestselling tradition of the previous editions by the late J. Lewis Blackburn, Protective Relaying: Principles and Applications, Third Edition retains the fundamentals of protection relays and power system protection while incorporating new developments in the field. Thoroughly updated and revised, this third edition focuses on technological changes in the design of protective systems, the practical concerns of power system protection encountered by users, and the techniques for protecting typical facilities used in modern power systems. New to the Third EditionExpanded coverage of the requirements for generator intertie protection, generator protection, and generator excitation systems latest technologies in microprocessor applications, including digital-based devices and designs protection issues, such as capacitor bank protection, under frequency and Undervoltage load shedding, special protection schemes, DC tripping scheme designs, fault location, and event reports building on the excellence of the preceding editions, this book will continue to serve as a basic reference for newcomers to the area as well as for experienced engineers. By sharing his first-hand experience with protection practices, the author offers a valuable realistic insight into this field.
Protective Relaying: Principles and Applications
by J. Lewis Blackburn
Technological advances and structural changes within the electric utility industry mandate that protection engineers develop a solid understanding of the related new technologies as well as of power system operations and economics to function proficiently. Continuing in the bestselling tradition of the previous editions by the late J. Lewis Blackburn, Protective Relaying: Principles and Applications, Third Edition retains the fundamentals of protection relays and power system protection while incorporating new developments in the field. Thoroughly updated and revised, this third edition focuses on technological changes in the design of protective systems, the practical concerns of power system protection encountered by users, and the techniques for protecting typical facilities used in modern power systems. New to the Third Edition· Expanded coverage of the requirements for generator intertie protection, generator protection, and generator excitation systems· The latest technologies in microprocessor applications, including digital-based devices and designs· Protection issues, such as capacitor bank protection, under frequency and Undervoltage load shedding, special protection schemes, DC tripping scheme designs, fault location, and event reports Building on the excellence of the preceding editions, this book will continue to serve as a basic reference for newcomers to the area as well as for experienced engineers. By sharing his first-hand experience with protection practices, the author offers a valuable realistic insight into this field.
Protective relaying of power systems using mathematical morphology
by Q.H. Wu
The basic operating principles of the most common types of protection relays have not changed for more than half a century. However, the calculations used to measure power system fault signals continue to cause problems with relay performance. As a result, there is a need for developing the next generation of protection relays that are more accurate, more reliable, and faster than conventional relays. Protective Relaying of Power Systems Using Mathematical Morphology discusses the development of novel protective relaying algorithms using Mathematical Morphology (MM). MM is a nonlinear signal processing technique derived from set theory and geometry. It analyses signals in terms of shape by retrieving the features of the signals using a pre-defined structuring element. The book introduces the fundamental principles and brings together the applications of MM to develop new protective relaying algorithms for the protection of a variety of power system components (including transmission lines, buses, and power transformers), as well as for the distorted waveform detection and compensation which are required for the operation of many conventional relays. Protective Relaying of Power Systems Using Mathematical Morphology is an ideal source of information for researchers or postgraduates in the fields of power and engineering, as well as for power engineers.
Protective relaying for power generation systems
by Donald Reimert, CRC/Taylor & Francis
Protective relaying for power generation systems
by Donald Reimert
Protective Relaying Principles And Applications
by J Lewis Blackburn
Protective Relaying – Principles and Applns
by J. Blackburn
The Art and Science of Protective Relaying
by C. Russell Mason
IEEE Guide for the Application of Current Transformers Used for Protective Relaying Purposes
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Similar: eBooks – Protection Engineer- Pack I
- Commissioning offline to prepare Sepam protection and parameter settings
- Load, unload, and modify Sepam protection and parameter settings
- Obtain all measurements and useful information during commissioning
- Manage the protection system
- Monitor the status of the electrical network
- Run diagnostics on any incidents affecting the electrical network
- Configuration of Sepam and optional modules
- Enabling/disabling of functions and entry of protection settings
- Adaptation of predefined control and monitoring functions
- Creation of personalized mimic diagrams for local display
- Access to all functions available in unconnected mode, after entering the password
- Transfer of Sepam parameter and protection setting file, prepared in offline mode, protected by the password
- Display of all measurements and useful information during commissioning
- Display of logic input, logic output, and LED status
- Test of logic outputs
- The setting of configuration bits, timers, etc.
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DIgSILENT Power Factory software is one of the most powerful network analysis software that is used in all the areas of generation, transmission, and distribution. DIgSILENT stands for DIgital SImuLation and Electrical NeTwork calculation program.
The purpose of this training is to acquaint engineers with the process of analyzing power systems to carry out research, industrial and other projects. Using this software, almost any power network can be modeled and calculations such as load flow, short circuit, transient analysis, optimal capacitor placement, cable size optimization, etc. can be provided in the form of various functions. In addition, other features such as programming in DPL language and defining DSL models provide the flexibility for the user to perform the desired analysis on the power system and the equipment that is not available in the software library.
- Trainers: Dr. Alireza Sobbouhi and Dr. Saeed Roostaee
- Pre-recorded videos with online access
- Free updates
- Free certification
- Free technical support
- After registering, we will add you to the DIGSILENT WhatsApp group. In this group, supporting files and related materials are sent, and you can also ask your technical questions where many group members and the course instructor will answer your questions.
DIGSILENT Training Course Contents – Basic
General introduction and software capabilities
- Discussing basic capabilities and comparison with other network analysis programs
- Create Username and Password
- Introducing different parts, windows, and menus of the software
- Introducing Digsi commands input window
- Discussing the basic calculations in the power system study
- building a new project
- Importing/exporting of the project
- Drawing single diagram and data entrance
- Introducing the capabilities of DIGSILENT communication with other programs
- Describing graphic, display, and coloring settings
- Describing the network drawing, text, and custom shapes inserting
- Definition of area, zone, owner, and operator
- Creating case study, variation, and scenario
Equipment modeling
- Modeling of the external grid
- Modeling of transmission lines in various methods
- Modeling of the bus, switch, and circuit breaker
- Modeling of different types of transformers
- Modeling of the induction motor and generator
- Modeling of the synchronous motor and generator
- Modeling of the capacitive banks and reactors in series or parallel connection
- Introducing renewable energy sources models: Solar and Wind
Load-flow study
- Reviewing the concept of load-flow study and application
- Describing load-flow calculation methods and settings
- Discussing the process of equations solve
- Reporting the results of the study
- Specifying the special outputs
- Describing graphic considerations
- Checking the errors and equations divergence
- Executing multiple instances
- Investigating how to correct network problems like voltage drop, lines, and transformers overload
Single contingency (N-1) study
- Reviewing the concept of single contingency study and application
- Creating different contingency definitions and settings
- determining and checking the study results
- Describing graphic considerations
- Executing multiple instances
Short-circuit study
- Reviewing the concept and application of short-circuit studies
- Overviewing of the IEC-60909 standard
- Defining different types of the short-circuit studies
- Discussing short-circuit settings
- Describing graphic considerations
- Investigating the effect of earthing type on the short-circuit study
- Executing multiple instances
Transient stability study
- Reviewing the concepts of transient stability
- Overviewing the theory of electromagnetic and electromechanical transient studies
- Defining AVR, Governor, and PSS for synchronous generators and other dynamic models of equipment
- Defining online tap changer (OLTC)
- Introducing of DSL
- Defining different types of events
- Determining the appropriate parameters to create the output
- Drawing different types of curves and outputs
- Reviewing the available dynamic models in the software library
- Executing multiple samples and calculating CCT
DIGSILENT Training Course Contents – Advanced
Voltage stability study and capacitor placement
- Reviewing the concepts of voltage stability and assessment methods
- Drawing P-V and Q-V curves
- Executing multiple instances
Power quality and harmonics
- Reviewing and importance of the power quality
- Modeling harmonic sources
- Harmonic power flow
Load modeling
- Reviewing and importance of the load modeling
- Introducing the various load models
- Applying the load model in the software
- Executing multiple instances
Modal analysis
- Reviewing the modal analysis of the concepts
- performing modal analysis and its settings
- Checking the controllability and visibility of the system
- Graphic considerations
- Executing multiple instances
- Introduce methods to eliminate dynamic instability
Protection study
- Review the protection concepts
- Definition of different relays types
- Definition of CT and PT
- Apply protection settings
- Check the relay’s static performance
- Check the relay’s dynamic performance
- Check the protective coordination
- Drawing the relays curves
- Describing graphic considerations
- Reviewing the available relay models in the software library
- Executing multiple instances
Reliability study
- Reviewing the objectives of reliability studies and important indicators of such as SAIFI, SAIDI
- Applying inputs and extracting reliability outputs
- Checking the settings for conducting a reliability study
- Executing multiple instances and changing the network restructure to improve the reliability indicators
DPL Introducing
- Reviewing objectives and capabilities of programming in the software studies
- Introducing the DPL environment
- Defining variables, constants, commands, functions, inputs, and outputs
- Accessing to SLD equipment and data
- Accessing software computational functions such as load-flow and short-circuit commands.
- Calling a DPL command by another DPL
- Reviewing the available DPLs in the software library
- Executing multiple instances
Main Training:
- P 01 (6 min, April 08, 2022): Course Contents and details
- P 02 (11 min, April 08, 2022): Introducing DIgSILENT
- P 03 (06 min, April 08, 2022): Comparision of common power system study software
- P 04 (07 min, April 08, 2022): Brief overview of DIgSILENT environment
- P 05 (11 min, April 08, 2022): DIgSILENT menu
- P 06 (13 min, April 08, 2022): DIgSILENT menu
- P 07 (17 min, April 08, 2022): Study tools in DIgSILENT
- P 08 (08 min, April 08, 2022): Creating a simple 3-bus system in DIgSILENT
- P 09 (17 min, April 08, 2022): Line / cable modeling and parameters
- P 10 (08 min, April 08, 2022): Generator modeling and parameters
- P 11 (07 min, April 08, 2022): Transformer modeling and parameters
- P 12 (09 min, April 08, 2022): Loads and busbar modeling and parameters
new videos will be added soon!
Supplementary files:
- DIgSilent PowerFactory 15 User Manual
- Load Flow Analysis in DIgSILENT PowerFactory
- Load Flow and Dynamic Simulation with the Palau Grid
- Load Flow and Short Circuit Calculation(Training Material)
- Load flow Calculations(Training Course)
- DIgSILENT Programming Language(DPL)
- DPL Tutorial
- Distance Protection Tutorial
- Detailed Modelling of HV Single-Core Cale Systems
- Compatibility Issues in Time Domain Simulations with DIgSILENT PowerFactory and SIEMENS PSSE
- Cable Modelling Tutorial
- Relay Modelling
- DPL Function Reference
- Dynamic Modelling Tutorial
- Advanced Smart Grid Functionalities Based on PowerFactory
- Short-Circuit Calculations(Training Course)
- Dynamic Wind Turbine Models in Power System Simulation tool DIgSILENT
- Grid Connection of WindFarms
- Implementation of the Model of a Solar Inverter
- Improving the Photovoltaic Model in PowerFactory
- Exercises for the Power System Stability
- Grid Compatibility of Wind Generators with Hydro-Dynamically Controlled Gearbox with German Grid Codes
- DIgSILENT PowerFactory Model Documentation IEC 61400-27-1 WTG Models
- Multicore Simulation of Power System Transients
- Over-Current Protection Tutorial
- Power System Stability on Island Networks
- Power Systems Electromagnetic Transients Simulation
- PowerFactory Applications for Power System Analysis(Springer)
- Python Advanced Tutorial
- Synchronous Generator(Training Course)
- Transients in Power Systems by Lou van der Sluis
This document provides the DIgSILENT PowerFactory Relay library of various manufacturers.
- ABB DIgSILENT Relay Library
- AEG DIgSILENT Relay Library
- Alstom DIgSILENT Relay Library
- Areva DIgSILENT Relay Library
- Beckwith DIgSILENT Relay Library
- Cooper Power Systems DIgSILENT Relay Library
- GE DIgSILENT Relay Library
- Generic relays DIgSILENT Relay Library
- Merlin Gerin DIgSILENT Relay Library
- Reyrolle DIgSILENT Relay Library
- Schneider DIgSILENT Relay Library
- Schweitzer DIgSILENT Relay Library
- Siemens DIgSILENT Relay Library
- Sprecher DIgSILENT Relay Library
- Toshiba DIgSILENT Relay Library
- VAMP DIgSILENT Relay Library
- Westinghouse DIgSILENT Relay Library
- ZIV DIgSILENT Relay Library
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F21 Distance Polygonal RX.dz
F21 Distance Polygonal.dz
F24 Overflux.dz
F27 Phase undervoltage.dz
F27D Positive sequence Undervoltage.dz
F32_F37 Under-_Over-Power.dz
F40 Loss of field.dz
F46 Unbalance overcurrent.dz
F47 Unbalance overvoltage.dz
F49 Thermal image.dz
F50_F51 Phase overcurrent.dz
F50BF Breaker failure.dz
F50N_F51N Neutral overcurrent.dz
F50V_F51V Voltage restraint overcurrent.dz
F59 Phase overvoltage.dz
F59D Positive sequence overvoltage.dz
F59N Neutral overvoltage.dz
F650.dz
F67 Phase directional.dz
F67_F50_F51 Phase directional overcurrent.dz
F67N Neutral directional.dz
F67N_F50N_F51N Neutral directional overcurrent.dz
F68 OOSPower Swing.dz
F78V Vector jump.dz
F79 Recloser.dz
F81 Frequency.dz
F81R Rate of Frequency change.dz
F87L Line Differential (angular 1 phase).dz
F87L Line Differential (angular 3 phase).dz
F87L Line Differential (magnitude).dz
F87REF Restricted Earth Fault.dz
F87T Transformer Differential.dz
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SACE TMAX T1-T7.dz
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Siemens 3WN1_3WS.dz
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Solkor M.dz
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SPAD 346.dz
SPAF 140C.dz
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Traditional protective relay books are written by engineers as a resource for engineers to use when modeling the electrical system or creating relay settings, and they often have very little practical use for the test technician in the field. The Relay Testing Handbook is a practical resource written by a relay tester for relay testers; it is a comprehensive series of practical instructional manuals that provide the knowledge necessary to test most modern protective relays. The complete handbook combines basic electrical fundamentals, detailed descriptions of protective elements, and generic test plans with examples of real-world applications, enabling you to confidently handle nearly any relay testing situation. Practical examples include a wide variety of relay manufacturers and models to demonstrate that you can apply the same basic fundamentals to most relay testing scenarios.
This Package contains five handbooks:
- No. 1. Principles and Practice (PDF – 214 Pages)
- No. 2. End-to-End Testing (PDF – 100 Pages)
- No. 3. Principles and Practice (PDF – 660 Pages)
- No. 4. Creating and Implementing Test Plans (PDF – 102 Pages)
- No. 5. Testing Voltage Protection (59/27/81) (PDF – 66 Pages)
power system protection enclosure:
power system protection enclosure
This picture shows a power transformer in an HV substation
Line Protection with GE relay
Hardware failure for CMC 356: Warning! The hardware self-test identified that the following current generators are out of tolerance or defective:
Current output / Group
The affected group will be disabled now. All generators of the non-affected groups can still be used.
Caution! Although the affected groups are disabled now they might carry dangerous currents! might carry dangerous currents!
If the problem persists it is highly recommended to send in the test set for repair. Online operation is enabled anyhow.
Areva or Schneider Electric relays in a cubicle
Substation Automation system and SEL relays in a substation
Microelecttrica sciendtifica Milano Italia
Philosophy of good relay protection settings for machines and plants – on photo: ABB Protection relay REF 542 Plus
SIEMENS SIPROTEC 4 Relay
SIEMENS SIPROTEC 5 Relay
Online SIEMENS SIPROTEC 5 relay
SIGRA 4 needs a serial number to activate; you can register your DIGSIwith a valid serial number along with SIGRA 4 software
How to create a new CFC Chart
In the DIGSI 4 Manager first, you must open a device (offline or online). Afterward, a new window appears.
first view after opening a device parameter set
Click on the icon Settings. Now all folders of the domain Settings will appear. Click on the CFC chart and you will see the already existent CFC charts. Different devices have different default CFC charts.
Folders in domain Settings
If you want to create a new chart go to the Insert menu in the menu bar of the window where you see the folder Settings. In the Insert menu is one option available called CFC chart. If you click on it a new CFC chart will appear in the right window. The computer will name it with the default name CFC1. The name can be changed by clicking with the right mouse button on the new chart and choosing the item object properties. There the name can be typed again. With double-clicking on the inserted chart, you can open this new chart. If you do not want to have already existent CFC charts you can simply delete them by the right mouse button and choose the deleted item or directly from the delete button on the PC keypad.
After insert of a new CFC chart
Easy Interlocking
A simple example of the interlocking feature in SIPROTEC 4 devices is explained using the following sample application:
The circuit breaker (Q0) is only permitted to close when the disconnector (Q1) is closed and the ground switch (Q8) is opened.
Refer to the input/output matrix. In the group control device, the commands for the switching devices are indicated. Each command occupies two lines.
The commands in the input/output matrix
For example, the first line of the disconnector switch contains the command information which is routed to the output contacts. The second line is for the feedback signals which are derived via binary inputs.
Two binary inputs for feedback are required for double point indication i.e. if:
- the switch device is opened=off (first used binary input : high(1), second low (0))
- the switch device is closed=on (first used binary input : low (0), second high(1))
- the switch device is in an intermediate / not valid position (either 00 or 11).
Controls without feedback can also be used, in this case, interlocking will not be possible. For interlocking, the feedback signals are the most important information. In this example, the interlocking must check the status of the disconnector (Q1) and the ground switch (Q8) before releasing a close command to the circuit breaker Q0. In picture 2 the CFC chart is shown. The status of the disconnector and ground switch is decoded with DI_TO_BOOL gates.
application of interlocking in CFC
The first DI_TO_BOOL gate decodes the closed position of the disconnector switch (Q1). The 2nd DI_TO_BOOL gate decodes the open position of the ground switch (Q8). If both these conditions are valid, the AND gate will generate the signal for releasing the
circuit breaker close command. The default settings already contain signals for interlocking (internal single point annunciations, see picture 1). For user-defined signals, these must first be created in the I/O matrix and routed to source CFC. Otherwise, these will not be available for selection later.
Ultimately the interlocking condition of the circuit breaker command must be allocated to the release signal derived with the logic. In the input/output matrix you have to click with the right mouse button on the circuit breaker and choose the object properties-item. The release signal Control Device 52 Close is responsible for the switching ON the circuit breaker.
Object properties of the circuit breaker
For the control functions such as circuit breaker OFF or other devices, the same procedure must be carried out with the relevant interlocking conditions. The default settings of SIPROTEC 4 devices always contain a CFC chart with standard interlocking functions.
Extended CFC chart for interlocking of several switching devices
SIPROTEC 5 and DIGSI 5 Training
By: Dr. Saeed Roostaee
Training can take place at your company.
Thirty hours of training will be provided for the SIPROTEC, DIGSI, and IEC 61850 configuration.
For more information and reservation, please contact us.
The link to know details of this course: https://elec-engg.com/digsi-5-training/
The Australian Protection Symposium is a forum for discussion and sharing of knowledge and first-hand experiences from Australia and around the world, whether it fundamentals, new approaches, technology developments and standards, strategies and implementation experiences, or even failure case studies, there will be a discussion that will benefit you and your organization in the area of protection, automation, and control.
Fundamental Principles and Requirements of Protection Systems
The purpose of this paper is to provide as clear a statement as possible of the functionality that Power System Protection has to fulfill to be considered ‘fit for purpose, and the requirements that this places on the concepts, design, components, and circuitry of protection systems. The statement of functionality is made in such a way as to form the basis of concepts and designs irrespective of the particular technology or combination of technologies used for its delivery. The Electrical Protection of power systems is an essential and critical function. The level of dependability and security required is the highest of any of the secondary circuit functions used in substations. The requirements are stated in a way that is independent of the technology used, to avoid restricting the development of new technology or applications. This approach is in the spirit of IEC 61850 in providing base rules and a framework for developing solutions without restricting the development of new solutions and improved functionality. The content includes key objectives of protection, basic principles applying to any scheme, all of the components involved (not just the relays), primary and backup principles (Remote BU and Local BU), and their implications. It deals with the requirements of secondary isolations of individual schemes required to permit safe work on a scheme while the remainder of the substation is in service, and with the requirements for simulated functional proving of protection schemes, again in a live substation. Segregation principles are also covered.
There are two aspects to the functional requirements:
- (a) The requirements that the protection has to fulfill to perform its functions of protecting the power system and people,
- (b) The requirements that the protection system places on whatever technology or a mix of technologies is used in the delivery of these functions.
Protection is a specialized discipline and requires people qualified or appropriately trained and competent in the discipline to carry out the various protection functions such as protection planning, system analysis, design and specification of relay systems, circuit design, relay settings, testing, installation, and commissioning.
Calculation of Loadability Limits of Modern Numerical Relays
Conventional calculation of load-ability limits of distance relays for different characteristics, such as Mho and Lenz, is based on determining the minimum permissible load impedance which is equivalent to maximum load current so that it does not encroach on the last forward zone reach of distance relay with a safety factor. In this paper it is shown that this philosophy, which is still used in some utilities for the calculation of relay load limit (RLL), does not apply to modern numerical relays due to utilizing the following elements for EHV transmission lines:
- a) load encroachment element (LE)
- b) power swing blocking (PSB).
The functionality of LE is to block the relay under normal loading conditions as long as the load impedance is within the LE characteristic. Its characteristic consists of a circle cut by straight lines which represents the load angle. The radius of the circle represents the magnitude of minimum load impedance. Bearing in mind that LE responds only to balancing positive current, it is shown that LE characteristic does not need to grade with any forward zones as long as the maximum load angle is less than the line angle with sufficient margin.
The main objective of PSB is to block the operation of phase distance elements for stable swing. Its characteristic consists of two blinders or circles, one inner and one outer. The inner blinder/circle should encompass the outermost zone of phase distance protection that has been selected for blocking. The outer blinder/circle should be set so that the closest minimum load impedance locus is outside the outer blinder/circle characteristic for all loading conditions.
In this paper, it is shown that the load-ability limit of distance relays of numerical relays should be calculated based on the outer blinder/circle characteristics of PSB rather than the conventional method of the last forward zone, otherwise the functionality of PSB will be ineffective and relay may trip on stable swings. With this concept mathematical equations for the calculation of RLL are developed for two cases, one with a blinder and one with circular characteristics for PSB. In addition to impedance relays, a methodology for the calculation of RLL for current differential and overcurrent protection of new numerical relays is given. Finally, the results of an analysis of system disturbances that have occurred under normal system loading conditions due to wrong relay settings, design errors, relay failures, and human errors during testing are discussed. It will be shown how these disturbances could have been prevented if the correct design philosophy and test procedures had been implemented.
Download full papers at the end of this page
An Overview of D.C Traction Protection Systems
DC electrical traction systems consist of fixed components that enable power to be supplied to trains and trams for their traction and auxiliary operations. The purpose of the system is to supply electric power to rolling stock for traction and auxiliaries. It may also accept power back to the network when regenerated through breaking by the train or tram. The electrical interface is the interaction of the traction supply with vehicle-based systems and components. Key factors that influence the effect on the DC protection system are:
- · Magnitude of electrical load – stationary and moving including the type of train, the current required for powering, the current required for auxiliaries, the number of trains operating, the timetable, and the speed of operation.
- · Traction system capacity including fault levels, protection types, and rate of rising of current.
This paper describes the DC protection system on the traction substation and the limitations and implications of the traction system.
The Digital Substation – Principles, Functions, and Benefits
The IEC 61850 standard for Communication Networks and Systems for Utility Automation allows utilities to consider new designs for substations applicable for both new substations and refurbishments. The levels of functional integration and flexibility of communications-based solutions bring significant advantages in costs in all stages of a project. This integration affects not only the design of the substation but almost every component and/or system in it such as protection, monitoring, and control by replacing the hardwired interfaces with communication links. Furthermore, the design of the high voltage installations can be reconsidered regarding the number and the location of switchgear components necessary to perform the primary function of a substation in a high voltage network. The use of highspeed
peer-to-peer communications using Generic Substation Event (GSE) messages and sampled values from non-conventional or conventional sensors allows the development of distributed applications. In addition, the use of optical local area networks leads in the direction of copper-less substations.
The paper focuses on the definitions of the digital substation communication busses such as the station bus for the communication at the station level and between bays as well as the process bus for the communication between the high voltage process and components interacting with it. It analyses the substation communications architectures in substations with full implementation of IEC 61850, i.e. with station and process bus.
The different types of devices required for digital substations are described. Merging units that provide the interface between the current and voltage sensors and the intelligent electronic devices at the equipment, bay, or substation level are described, as well as the distribution of signal and data processing functions between the different devices for both architectures, which are analyzed. Some specific substation applications based on GOOSE and Sampled Analogue Values are described later in the paper and demonstrate the advantages of the new technology. Improvements in functionality, combined with practical elimination of performance or safety issues are covered in the paper.
Download full papers at the end of this page
Impact of IEC61850 ed2 on Protection GOOSE
GOOSE itself brings many benefits that can be utilized for various protection signals, however, isolation and testing are critical considerations that are often seen as deficiencies in edition 1 (ed1) of the IEC61850 standard. A key driver for edition 2 (ed2) was to overcome these limitations. This paper looks at various isolation and test methods used for edition 1 and compares them to using edition 2. A major drawback of edition 1 was the inability to use online simulation. This limitation was not obvious and care is needed to ensure simulated or test messages are not used on a live system. This paper looks at the new simulation modes available in edition 2 which greatly improves this situation. The edition 2 simulation mode is quite powerful and this paper also looks at how this functionality can be used in a practical application. One of the stated objectives of edition 2 is to create solutions that can incorporate edition 1 relays. This paper also looks at the practicality of doing this.
Download full papers at the end of this page
Case Study: Implementation of IEC61850 in Generator and Transformer Protection System in NSW Power Stations
Reliability, Efficiency, and Safety are the key objectives of any modern power system, and these can be achieved by the implementation of fully automated systems. The IEC61850 standard has revolutionized the automation process by standardizing system specifications, configuration language, naming convention, communication protocol, and conformance testing. The use of IEC61850 compliant devices can simplify the engineering design process, increase flexibility, and reduce engineering costs. To operate and maintain IEC61850-based systems, plant engineers must acquire knowledge about communication protocols, computer networks, classes, objects, etc. In New South Wales (NSW), the protection systems of the large turbo-generators (660MW units and above) and associated generator transformers have reached the end of their operating life. Most NSW generating companies have already implemented a program for replacing these generator and generator transformer protection systems. The new protection systems used IEC61850 compliant protection relays with an optical, peer-to-peer communication messaging system known as “GOOSE”. Being a protection retrofitting project to existing generating units, there were some difficult choices and design considerations in selecting the levels of IEC61850 implementation to these new protection systems. This paper looks at the extent of IEC61850 implementation in these retrofitted generator and generator transformer protection systems in NSW. It also provides a discussion on the impacts of the IEC61850 system on the operation and maintenance of these protection systems and possible future improvements.
COMTRADE Analysis to Visualize Protection Operations
This paper discusses methods of analyzing waveform recordings from numerical relays to diagnose power system events and confirm relay operations. COMTRADE format recordings often only capture the physical analog and digital signals wired to the relay, while internal protection functions will use algorithms to manipulate these signals before determining a trip condition. With a basic understanding of the relay algorithms, the operating quantity can be derived from the recording and compared to an operating characteristic to verify settings and confirm relay operations.
Examples presented include analysis of harmonic content of inrush waveforms, trip locus of differential and impedance-based characteristics, high impedance-based protection trips, and fault finding installation and application issues.
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Verification of Distance Protection Scheme of double circuit transmission line using power disturbance records
The Channel Island Power Station is the major generation source for the Darwin-Katherine region. Power delivery to the greater Darwin region is via two 132kV overhead lines to Hudson Creek Substation which are installed on separate towers sharing a common corridor. Figure 1 below is a simplified network diagram used in the model to study the impacts of the influencing factors including source impedance ratio, load-flow, mutual coupling, fault impedance, single-pole tripping, auto reclosing, and current reversal. The first part of this paper describes the selection of the proposed replacement system. The second part describes the evaluation of the combined effects of the influencing factors and the last part describes verification using available power system disturbance records and the test scenarios generated by RelaySimTest.
RelaySim Test Scenarios for verification of the protection
Cygnus Atratus, and How it Causes Problems
Protection systems deal with two different types of faults, ones we expect and faults that are unique and had not been considered. This paper describes black swan events, and how we as protection people should make our system black swan tolerant. It looks at several events, not all within the power industry, and describes how different thinking may have prevented incidents from occurring. It describes the effect of outliers on fault analysis and black swan recognition. The author has been involved in a black swan style theory for many years. As a book by Nassim Nicholas Taleb has created the terms used nowadays, those terms are used throughout this paper.
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Application of the Line Differential Protection Scheme for Radial Transmission Lines
Modern communication networks have dramatically increased the implementation of the line differential scheme as one or both primary protection for transmission lines. The transmission network usually meshes which also provides fault current contribution from both ends of the line. Considering the ongoing need to reduce CAPEX investment, it is expected that the supply to specific loads, for instance, mining in rural zones of Australia, the transmission network could be expanded radially with single or double circuit applications. In a radial system, in the event of a fault, fault current contribution is drawn mainly from the source side. This scenario could potentially create issues with the operation of supervisory elements of the line differential relay at the remote end. This paper reviews this specific application with particular attention to solutions that balance the need for security, speed, and dependability of the line differential protection scheme.
Modeling and Testing of High Impedance Differential Scheme Using Numerical Relays
A high impedance (HiZ) differential protection scheme has been used for busbar protection over many decades. The basic idea used in this scheme avoids problems related to CT saturation through faults by connecting high impedance in series with the operating relay. Relay with high impedance burden and CT’s are connected in parallel to force the false differential currents (caused by CT saturation) to go through the saturated CT’s rather than through the relay. As long as the voltage across the summation point required to operate the relay is higher (with a certain margin) than the
maximum voltage developed during maximum through fault, the scheme provides adequate security. This requirement is usually easy to satisfy and very few utilities ever had an issue with scheme security caused by CT saturation. On the other hand, tripping for internal faults relies on CTs’ ability to provide enough secondary current through a very high impedance of the relay branch during an internal fault. Under an internal fault condition, at least one CT with primary current drives secondary current into high resistance of the relay branch. This creates a high voltage across CT terminals. This voltage usually exceeds the knee point voltage of the CT and eventually saturates (from the second terminal side) other CTs connected into a high impedance scheme. The low impedance of saturated CTs reduces the burden on source CTs but also allows spill current to flow into saturated CT’s not into the relay. As a consequence, in steady-state, the current through the relay flows only during short periods when the voltage across the summation point is below the knee point voltage of CT with the lowest knee point voltage – i.e. periods before the smallest CT saturates. Early schemes had been implemented using high (usually nonlinear) impedance voltage relays. These relays were extremely fast because the very sensitive operating coil in these relays (usually 5mA – 10mA) would operate almost instantaneously when voltage increases over the knee point of internal nonlinear resistors used to set the voltage pickup. Over time, the voltage relays had been replaced with electromechanical (EM) instantaneous overcurrent relays (usually armature type) and burden resistors. More recently, EM relays have been replaced with solid-state and numerical overcurrent relays. The general understanding is that the HiZ scheme performance is expected to remain satisfactory as long as few original design “rules of thumb” are met. At the same time requirements for smaller CT have been intensified due to switchgear size reduction. This paper presents methods and findings of modeling and simulation of an HiZ differential scheme. Relay performance under internal fault conditions was studied. Conclusions and some recommendations for scheme improvements based on these findings are presented.
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New Design of Distance Protection for Smart Grid Applications
Smart grids of the future will have new challenging requirements for the protection elements regarding selectivity and dependability. The load flow will be increasing, the magnitude and direction of load flow may frequently be changing, and even the network topology will be more complex than today. This paper presents a new design of distance protection that perfectly fits the requirements of the smart grid of the future.
The impedance measurement is based on the calculation of the load compensated fault reactance X and from the line, resistance separated fault resistance. This method is applied for the phase to the ground as well as phase-to-phase faults. Separation of the fault resistance improves the accuracy of the impedance calculation. The method reduces the negative influence of fault resistance during high load flow and minimizes the risk of the wrong pickup during high load conditions. Once a fault is detected, it is very crucial to select the faulted loop to calculate the impedance to the fault. For complicated faults in the complex network of a smart grid, this can be a challenging task with a certain risk of non-selective fault clearance. In the past, the loop selection was done by a so-called decision tree, in which several criteria were applied sequentially to find the faulted loop. Thereby, only the result from one criterion selects the faulted loop. The new approach is different. Several criteria are based on magnitudes of voltages and currents, changes in voltages and currents, symmetrical components, or impedances are applied in parallel. The results of every single criterion are weighted and combined to get a final result for the selection of the faulted loop. With this principle, the efficiency of the loop selection has been optimized to different network topologies by changing the weights of each criterion. The same principle is applied to the directional element. Multiple criteria based on actual voltages, memorized voltages, symmetrical components, or delta quantities are applied in parallel. The final result is obtained as a weighted combination of the result of every single criterion.
Communication Aided Protection Schemes and their Implementation and Testing with State-of-the-Art Technologies
Electrical power systems and the related protection and control systems evolve. Systems get extended, and the existing parts have to be adapted to the new configuration. While extending the primary system is more straightforward in most cases, the adaption of the protection system can be more challenging if the topology of the primary system is essentially changed. The adaption of protection settings is not sufficient to cope with such situations. New protection concepts or improved information exchange between protection relays may be required. This paper describes an electrical power system with five terminals that evolved and how recent technologies were applied for upgrading the protection system and how the testing of the system was performed.
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Implementation of Multi-Intertripping Protection Schemes in a Complex EHV Industrial Substation
This paper describes the design, installation, and commissioning of new numerical protection and control and inter-tripping schemes at an EHV substation. The substation supplies a critical and large industrial plant (paper mill). The connection consists of two radial 110 kV transmission lines connecting four 25 MVA, 110/6.6 kV transformers, two of which are dual wounds. Each transmission line is directly connected to a transformer. The 6.6 kV sides of the transformers are connected to different busbars via circuit breakers. For a fault on the 110 kV lines or the transformers, the remote end 110 kV circuit breaker and appropriate 6.6 kV circuit breakers must open.
This arrangement required complex inter-tripping schemes between the protection devices of the transformers within the substation and between the protection of the local substation and remote substations. The secondary work at the local and remote EHV substation included installing new 110 kV transmission line protection schemes, consisting of Main ‘A’ and Main ‘B’ new numerical relays for each line. This included the removal of existing inter-tripping schemes.
The project necessitated an innovative design, settings, and logic programming to be implemented on new relays. Existing secondary infrastructure including copper cables and intra-substation fibers of the single old protection scheme was utilized for the now duplicated transmission line protection. This involved the following.
- Removal of the existing multi-inter tripping schemes and reconfiguration using a new numerical protection scheme with appropriate setting and logic programming.
- Utilizing fiber optic cable and digital transceivers/receivers for provision of trip/close circuits.
- Implementing a reliable design and setting based on sound standard policy/philosophy.
- Installing, testing, and commissioning the new protection and inter-tripping schemes with minimum plant outages due to load critically.
Finally, the paper discusses how the implementation of the project involved innovative solutions so that new primary equipment and secondary copper cabling was not required while providing high system reliability and security
XML and UML – What They are and Why We Need to Know Them
The power system automation community is going through a period of transition from the world of hard-wired systems and proprietary configuration and analysis tools into the world of distributed IEC 61850 communications-based systems and object-oriented standards-based engineering and analysis tools. This requires the development of a new set of skills to help the specialists from our industry understand and use the new technology. The main goal of this paper is to introduce the Extensible Markup Language (XML) and the Unified Modeling Language (UML) to the protection and control community and focus on the UML diagrams and XML files used in the IEC 61850 standard and some IEEE standards related to protection and control to help the readers understand the diagrams and files included in or defined by the different standards.
Examples of the use of UML diagrams in IEC 61850 are given later in the paper.
Examples of the use of XML in the IEEE C37.239: IEEE Standard for Common Format for Event Data
Exchange (COMFEDE) standards are presented at the end of the paper.
Old Lessons – Re-learned
Over national holiday breaks, and weekends, especially during the spring and autumn, low loads and high proportional wind generation could combine and result in fault levels on the network dropping to unexpected values. In the event of a system fault, this could adversely affect the operation of protection schemes. If protection schemes do not detect faults the effects of system events will become more widespread leading to unnecessary damage to assets and power supply disruption. Looking at the operation of single-phase tripping schemes, this paper will discuss how the schemes work to clear a fault and the importance of ensuring tripping at all ends of the protected feeder with particular emphasis on Wind Farm fault supplying capability and protection scheme sensitivity looking at the various differential, distance and distance signal-aided line protection schemes. For transformer protection, we look at how basic relay settings are modified by zero-sequence filtering and ratio compensation leading to differing sensitivity.
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330 kV downed conductor protection and successful operation
Line protection systems were replaced between Transgrid’s Upper Tumut Switching Station and Snowy Hydro’s Tumut 1 and Tumut 2 Power Stations. The risk of a downed conductor before synchronizing the line at the switching station was identified, and a protection system was designed to detect this failure. Traditional systems would not detect this unique event until a significant quantity of fault current was reached with a possible bush fire. The predicted event occurred less than a year after the protection was installed, and was correctly cleared with no extra plant or environmental damage. This paper examines the thought processes required to see the need, the need and implementation of the protection, and the resulting fault and protection operation.
The Reality of Providing Energy in Australia: Bushfire Mitigation and the Benefits of Power Quality Monitoring Outside Substations
In Australia’s electricity supply history, utilities have grappled with some unique issues. Australian utilities are known for innovation, and the utility demands placed on manufacturers have been responsible for some of the greatest steps in switchgear development. As one of the largest interconnected networks in the world, distribution network service providers (DNSPs) in Australia face big issues presented by the unique geography and climate. One of the greatest causes for concern in the Australian Distribution community is the aspect of bushfire risk. Australia has a long history of bushfire disasters, but instead of the devastating events of February 2009, the impact of utilities has been burned into the Australian psyche. The resilience of Australia’s utilities and engineers prompts appropriate development to mitigate these risks, and this paper outlines some of the features available using one of the most common protective distribution switchgear devices: the automatic circuit recloser (ACR). ACRs humble beginnings as hydraulic devices in the mid-1900s have evolved greatly through the years through to semiconductor-controlled switches. These switches have proliferated across networks all over the globe, driven by the immediate reliability benefits and protection offered on a reasonable budget. Australia itself has had a fair share of manufacturers, and today there are thousands of NOJA Power reclosers in service providing reliability to customers. Driven by continuous requirements from utilities, these semiconductor-controlled reclosers have been greatly developed, and this paper presents some solutions implemented to combat the challenges of the Australian distribution network. Bushfire mitigation is at the forefront of development, and through the use of the NOJA Power RC10 control system, it is now possible to update and integrate bushfire mitigation strategies using commissioned NOJA Power assets, with a simple firmware update and a network integration strategy.
By using the onboard voltage and current sensing capabilities of these reclosers, the RC10 now can conduct complete power quality monitoring and reporting – a technology long bound to the granite yards of substations. This functionality is now available out on the feeders, using the same protection devices installed years ago, providing power quality feedback from the shores of the gold coast to Uluru. Enhancing Australian Protection System Testing through Real-Time Digital Simulations The modern power system is large and highly complex. At the same time, several new and potentially disruptive technologies can redefine the way the power system is designed, operated, and managed, changing long-existing network dynamics. Examples of these disruptive technologies include intermittent power generation (such as wind and large-scale solar PV farms), centralized energy storage, and distributed generation (DG). Meanwhile, computational power and sensing capacity is continuously increasing within the network. New generation network devices (including flexible alternating current transmission systems (FACTS) such as synchronous static compensators (STATCOMs), HVDC interconnections, multi-terminal dc networks, and dc grids) extend the available solutions but further complicate the optimal selection of technologies. This increased complexity also translates into requirements for more sophisticated and highly selective protection systems for faster fault detection and isolation, to minimize disruption and increase network availability. Improper settings or coordination among protection devices can lead to major network disruptions, as demonstrated in the 2003 North American Eastern Interconnection Blackout. Inadequate understanding of the power system and inadequate situational awareness are considered among the major causes of such failures. Recently, the aspect of grid resiliency has also attracted attention, in addition to the existing focus on reliability, efficiency, and cost-effectiveness. One of the main methods of demonstrating and verifying the performance of current and future power systems, thoroughly testing the design and operation of protection schemes, and experimenting with novel methods and approaches is through the use of real-time digital simulations. The concept of real-time digital simulations was initially introduced in 1969 by Dommel [3] and is based on the calculation of the system’s currents and voltages using the conductance matrix of an equivalent electrical network at a time smaller than the defined time-step [4]. The time step should be selected so that the real-time behavior of the network is accurately emulated and provides trustworthy results. Through real-time simulation, the behavior of the power system can be observed in real-time. At the same time, external hardware (e.g. digital controllers or protection relays) can be directly connected to the simulator enabling studies on the response of hardware and the response of the power system following any operation of the external device. The major drawback of this approach is that it requires large computational power and processing capabilities, which increase exponentially with the complexity of the simulated system. The typical time-step for real-time digital simulations is in the range of a few μs (up to 50μs). Real-time digital simulation can be a very powerful tool for network planners, protection engineers, and everyone involved in the design and operation of a power system. The objective of this article is to present the real-time digital simulator (RTDS) available at UNSW Australia, demonstrate its capabilities and illustrate applications relevant to protection testing as well as the broad range of simulations that can be performed.
Click here to download Proceedings of the Australian Protection Symposium
The PC operating program DIGSI 4 is the user interface to all SIPROTEC 4, SIPROTEC Compact, SIPROTEC 3 and SIPROTEC 2 devices. It is designed with a modern, intuitive user interface. With DIGSI 4, SIPROTEC devices are configured and evaluated – it is the tailored program for industrial and energy distribution systems. From the numerous protection functions, it is possible to easily select only those which are really required. This increases the clearness of the other menus. The settings can be entered and displayed as primary or secondary values. Switching over between primary and secondary values is done with one mouse click in the toolbar. The DIGSI 4 matrix shows the user the complete configuration of the device at a glance. For example, the assignment of the LEDs, the binary inputs, and the output relays are displayed in one image. With one click, the assignment can be changed. With the CFC (continuous function chart), it is possible to link and derive information without software knowledge by simply drawing technical processes, interlocks, and operating sequences. Logical elements such as AND, OR, timers, etc., as well as limit value requests of measured values, are available. Special attention has been paid to commissioning. All binary inputs and outputs can be set and read out in a targeted way. Thus, a very simple wiring test is possible. Messages can be sent to the serial interface deliberately for test purposes.
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DIGSI 5 is the configuration and operation tool for all SIPROTEC 5 devices. With DIGSI 5, you create system topologies, configure hardware and communication networks, set function settings, and perform many further tasks.
You perform all configuration tasks offline from your PC without the need for a SIPROTEC 5 device. You transmit all data online to the SIPROTEC 5 device later on – for example, directly through a communication network. For communication, DIGSI 5 and SIPROTEC 5 are based on current standards such as IEC 61850 and proven technologies such as Ethernet.
There are 3 different variants of DIGSI 5:
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For simple applications using individual SIPROTEC 5 devices, select DIGSI 5 Compact. With this variant, you deal with most standard tasks such as setting parameters or reading out process data.
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The DIGSI 5 Standard variant has an extended scope of functions. This variant includes, among others, the CFC editor and the Display editor. With these, you can now also create your own symbols. With DIGSI 5 Standard, you simulate the topology of a system as a 1-phase representation and you configure hardware and networks on a graphical basis. DIGSI 5 Standard offers full IEC 61850 support, including system configuration.
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DIGSI 5 Premium is the high-end variant of DIGSI 5. This variant contains the DIGSI 5 Test suite for testing SIPROTEC 5 devices and functions. You analyze fault records with SIGRA and you use the advantages of flexible engineering for IEC 61850. CFC debugging is a feature provided in DIGSI to verify the created logic before downloading it to any device. (Elec-Engg provides DIGSI 5 Premium License, more information, Contact Us)
What are the differences between DIGSI 4 and DIGSI 5?
Where Do I Find the DIGSI 4 Manager?
In DIGSI 4, the Manager is the initial platform for editing individual devices, modem connections, and more.
Instead of the DIGSI 4 Manager, DIGSI 5 has a common user interface for all required tools. Working with several overlapping cards is now a thing of the past. The Project Tree is now your control center.
If you prefer a similar representation as in the DIGSI 4 Manager, open the Overview Window. You can view the individual objects with details, as a list or as icons.
What Happened to the MLFB (Order Number)?
Instead of an MLFB (machine-readable product designation), SIPROTEC 5 devices have a product code, in both a long and a short form.
The long product code corresponds to the order number of a SIPROTEC 5 device. You find this number in your order documents. DIGSI 5 can directly interpret this long product code, as every character of the code can be assigned uniquely to a property of the SIPROTEC 5 device.
For easier handling, there is a short product code, which uniquely identifies a long product code. The short product code can be configured directly in DIGSI 5. You can find the short product code on the nameplate of the SIPROTEC 5 device and it is also available during ordering.
How Do I Open a SIPROTEC 5 Device for Editing?
To edit a device in DIGSI 4, you had to open this device with the device editing function. This is no longer necessary in DIGSI 5.
In the Project Tree, you find one entry for each SIPROTEC 5 device offline configuration. This entry summarizes all actions and access points that you need to edit this offline configuration.
Thus, for example, you display the Information Routing matrix by double-clicking to route information in the working area. This also works parallel for several offline configurations.
How Do I Set the Functional Scope of a SIPROTEC 5 Device?
In DIGSI 4, you had to open a device for editing and you had to adapt the scope of functions of the device in the DIGSI 4 device editing function. This is now no longer necessary. In DIGSI 5, you already select a so-called application template when adding a new SIPROTEC 5 device.
Application templates make further project planning simpler for a SIPROTEC 5 device. Each template contains the most important functions that are required for a specific application. Examples of such applications are line protection, motor, and transformer protection.
Selecting a certain application template consequently determines the basic functional scope of a SIPROTEC 5 device. You can change this by adding and removing functions. You can do this with drag and drop in Single-Line Editor, in the Information Routing matrix, or also within the Project Tree.
Why Can I Not Route to CFC and the Display in the Information Routing?
In DIGSI 4, you must route to CFC in the matrix the information that you need for a CFC function, or which is generated as a result of a CFC function. The same applies to the information that you need on the display.
All information that is listed in the information routing is automatically at your disposal in the Function-Chart (CFC) Editor and the Display Editor of DIGSI 5. It is no longer necessary to route to CFC or the display.
The columns for CFC and for the display in the Information Routing matrix serve only to indicate whether an item of information is used within a function chart (CFC) or the display. The display appears automatically as soon as you link an item of information with a function block or an element on a display page
How Do I Edit the Basic Display and the Control Display?
There is no longer any distinction between the main display and the controlled display, and there are now only display pages in SIPROTEC 5 and DIGSI 5.
In DIGSI 5 Standard and DIGSI 5 Premium, for every SIPROTEC 5 device you can generate up to 10 display pages with graphics, text, and measured values and can save them into the SIPROTEC 5 device. You use the Display editor to generate this. You yourself decide on which operating state you use which display page.
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The reverse busbar protection is a cost-effective solution for the accelerated clearance of busbar faults in distribution systems. It can only be applied on single busbars with a fixed direction of power flow and fault current flow. In picture 3, a typical application is shown.
Overview:
For this application, the protection device on the incoming bay (usually the transformer bay) will be provided with blocking signals from the outgoing bays (the feeder bays). If one of the outgoing bays (feeder bays) detects a fault, (pick-up signal), this bay must route a blocking signal to protect the incoming bay. This blocking signal prevents the fast tripping of the incoming bay (I>> stage). The block signal may only be present for one second.
For this application, a CFC chart in the incoming bay is required. Although it is possible to allocate a signal from a binary input so that it provides the blocking of a protection stage it is not possible to give more than one binary input to directly block one protection stage (the reason being that if two binary inputs that provide the same blocking signal have a different state, the device logic would not know which of the two binary inputs should be used).
Example application with 7SJ6 relays:
The I>> stage in the in-comer will be blocked with the signal 1721 >Block 50-2., and the signal 1724 >Block 50N-2. These signals must be allocated with source CFC. (see picture 1)
For example, a feeder relay (or many feeder relays with a blocking signal connected in parallel) designated as LHBB-block provides a blocking input signal via binary input to the incoming bay relay. This signal is routed to the user-defined single-point annunciation in the matrix (picture 1), binary input 20. Similarly, the second feeder relay (or second group of relays) designated as RHBB-block is/are allocated to binary input 21. Two new user-defined single-point annunciations, which have to be connected to the binary inputs must be generated. These signals (in picture 1) are called LHBB-Block and RHBBBlock. These signals must be routed with the destination CFC so that they will be available inside the CFC charts. In the CFC chart, the LHBB-Block and RHBB-Block signals are connected via OR-gate. The output of the OR gate triggers a timer that restricts the blocking signal to one second. This is achieved by applying the timer output via a negator to an AND gate (AND gate 4 in picture 2). The timer output will change from 0 to 1 one second after the OR gate output changes to 1. At this point, the second input of AND gate 4 will change to 0, thereby removing the blocking signal which is routed from OR gate one via the AND gate to the right-hand margin. As shown in picture 2, the blocking signal from the CFC chart is derived from the output of the AND gate and is routed to the signals 1721 >Block 50-2. and 1724 >Block 50N-2. Please note that the gates must be executed in the correct sequence, i.e. sequences 10 to 13 as shown in picture 2. The sequence of execution may commence with a different
number, depending on other logic located in the same execution layer, PLC_BEARB). The OR gates must be first in the sequence, followed by the timer, negator, and AND gate in turn.
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DIGSI 4 is for the configuration of all SIPROTEC 4, SIPROTEC Compact, SIPROTEC 3, and SIPROTEC 2 devices which are designed with a modern, intuitive user interface. With DIGSI 4, SIPROTEC devices are configured and evaluated.
This package contains DIGSI Video Tutorials
More about DIGSI 4:
From the numerous protection functions in SIPROTEC devices, it is possible to easily select only those which are really required. The settings can be entered and displayed as primary or secondary values. Switching over between primary and secondary values is done with one mouse click in the toolbar.
The DIGSI 4 matrix shows the user the complete configuration of the device at a glance. For example, the assignment of the LEDs, the binary inputs, and the output relays are displayed in one image. With one click, the assignment can be changed.
With the CFC (continuous function chart), it is possible to link and derive information without software knowledge by simply drawing technical processes, interlocks, and operating sequences. Logical elements such as AND, OR, timers, etc., as well as limit value requests of measured values, are available. Special attention has been paid to commissioning. All binary inputs and outputs can be set and read out in a targeted way. Thus, a very simple wiring test is possible. Messages can be sent to the serial interface deliberately for test purposes.
OMICRON Test Universe 4.00 trainig package
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Advanced Power in OMICRON Test Universe V4.00
Advanced Power Module in Test Universe V4
Power Module in Test Universe V4
DIGSI 5 is for configuring, parameterizing, and operating SIPROTEC 5 protection, combination, and bay devices. With a PC or a notebook, you can parameterize the devices via the interfaces and export and visualize the fault data. DIGSI 5 comes in different variants (Compact, Standard, and Premium) that provide different functionalities. To use DIGSI 5 Standard and Premium, you need a license key for each computer you are running DIGSI 5 on. If you execute the software without a license key, it will be always available as DIGSI 5 Compact edition or as a Trial version for 30 days. The licenses are provided on USB sticks.
DIGSI 5 V7.80 needs high performance specifications of the used operating system version. Therefore, it is recommended to install DIGSI 5 V7.80 on Intel® Core™ i5 with 16 GB of RAM,
With DIGSI 5 V7.80, you cannot upgrade projects created with DIGSI 5 V6.20 and below directly to DIGSI 5 V7.80 due to the technical limitations. During the installation of DIGSI 5 V7.80, you will be prompted depending on the current DIGSI 5 installation on your PC. The following possibilities exist:
- DIGSI 5 V6.20 and lower is installed on the PC : You are informed that it is required to install any one version from DIGSI 5 V7.00 to DIGSI 5 V7.50 (recommended) to upgrade projects to DIGSI 5 V7.80. This will uninstall the DIGSI 5 V6.20 and lower from the PC.
- DIGSI 5 V7.00 or higher version up to DIGSI 5 V7.50 is installed on the PC: You are prompted that it is required to retain/remove the existing installation.
- If the existing DIGSI 5 installation is retained, it is possible to upgrade the projects created with DIGSI 5 V6.20 and lower. In this case, 2 DIGSI 5 versions will be installed on the PC.
- If the existing DIGSI 5 installation is not retained, only the latest DIGSI 5 V7.80 is installed. It is then not possible to upgrade the projects created with DIGSI 5 V6.20 and below.
DIGSI 5 V7.80 can be used along with any available DIGSI 4 version on the same system. If you install DIGSI 4.82 or earlier after DIGSI 5, you need to reinstall the latest Automation License Manager (ALM) after installation of DIGSI 4. ALM setup is provided on the DIGSI 5 DVD in the folder \Automation License Manager.
DIGSI 4.93 is the user interface to configure SIPROTEC 4, SIPROTEC Compact, and SIPROTEC 3 devices. It is designed with a modern, intuitive user interface. With DIGSI 4.93, from the numerous protection functions, it is possible to easily select only those which are really required. The settings can be entered and displayed as primary or secondary values.
The DIGSI 4 matrix shows the user the complete configuration of the device at a glance. For example, the assignment of the LEDs, the binary inputs, and the binary output relays are displayed in one image. With one click, the assignment can be changed.
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With the CFC (continuous function chart), it is possible to link and derive information without software knowledge by simply drawing technical processes, interlocks and operating sequences.
Relay protection against the high current was the earliest relay protection mechanism to develop. From this basic method, the graded overcurrent relay protection system, discriminative short circuit protection, has been formulated. This should not be mixed with ‘overload’ relay protection, which typically utilizes relays that function in a time-related to some degree to the thermal capacity of the equipment to be protected. On the contrary, overcurrent relay protection is completely directed to the clearance of short circuits, even though with the settings typically assumed some measure of overload relay protection may be obtained.
Types of Overcurrent Relay
- Instantaneous Overc1r11e1nt Relay
- Inverse Time Overcurrent Relay (IDMT Relay)
- Directional overcurrent relay
- 1Mixed IDMT and high set instantaneous
Instantaneously overcurrent relay operates when the current exceeds its Pickup value. The operation of this relay is based on the current magnitude and it is without any time delay.
Instantaneous Overcurrent Relay
STANDARD IDMT OVERCURRENT PROTECTION RELAYS
The current/time-tripping characteristics of IDMT protection relays may need to be changed according to the functioning time needed and the characteristics of other relay protection elements used in the electrical network0.10 For these needs, IEC 60255 determined the number of standard characteristics. These are:
- Standard Inverse characteristic (SI)
- Very Inverse characteristic (VI)
- Extremely Inverse characteristic (EI)
- Definite Time characteristic (DT)
MIXED IDMT AND HIGH SET INSTANTANEOUS OVERCURRENT PROTECTION RELAYS
A high-set instantaneous device can be utilized where the source impedance is small in comparison with the protected circuit impedance. This allows a decrease in the operating time at high short circuit levels possible. It also enhances the overall electrical system grading by allowing the ‘discriminating protection curves’ behind the high set instantaneous device to be reduced. One of the benefits of high-set instantaneous devices is to decrease the tripping time of the circuit protection. If the source impedance stays constant, it is then feasible to accomplish high-speed relay protection over a large part of the protected circuit. The quick short circuit clearance time helps to decrease damage at the short circuit location. Grading with the protection relay directly behind the protection relay, which has the instantaneous devices enabled, is accomplished at the current setting of the instantaneous devices and not at the maximum short circuit level.
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DIRECTIONAL OVERCURRENT RELAY
When a short circuit current can go in both directions through the protection relay location, it may be required to make the response of the protection relay directional by the initiation of a directional control device. The device is provided by the use of extra voltage inputs to the protection relay. There are many ways for an appropriate connection of voltage and current signals. The different connections depend on the phase angle, at a unity system power factor, by which the current and voltage used in the protection relay are displaced
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مُقدمة Introduction
مفهوم الحماية الكهربية Protection Concept
دور و وظيفة جهاز الحماية الكهربية The Role Of Protection Relay
مكونات نظام الحماية الكهربية Protection Scheme Components
تصنيف أجهزة الحماية الكهربية Protection Relays Classification
تاريخ أجهزة الحماية الكهربية Protection Relays History
أهم مُتَطلبات أجهزة و نُظُم الحماية الكهربية Protection Scheme Requirements
أداء أجهزة و نُظُم الحماية الكهربية Protection Scheme Operation
تداخل مناطق الحماية لمهمات الشبكة الكهربية Protection zones overlapping
التنسيق باستخدام أوضاع محولات التيار CT Location Co-ordination
تأريض غلاف الكابل Cable Sheath Earthing
Stub Protection
Tee Protection
Time Co-ordination between Protective Relays
أشهر أنواع المنحنيات لعمل أجهزة الحماية ضد زيادة التيار و ضد التسرب الأرضي
اختيار المنحنى المناسب لعمل أجهزة الحماية ضد زيادة التيار و ضد التسرب الأرضي
أشهر أنواع توصيلات أجهزة الحماية ضد زيادة التيار و ضد التسرب الأرضي
مسؤوليات الحماية لمهمات الشبكة الكهربية Protection zones responsibilities
جهاز الحماية Protective relay
نظام الحماية Protective System
أسلوب (خُطة) الحماية Protection Scheme
أمثلة توضيحية لأهمية حدوث الفصل Trip Circuit Importance Explanation
إحكام/ تعزيز تنفيذ أمر الفصل Trip Command Sealing/Reinforcing
و ماذا يحدث لو لم يتم فصل القاطع المطلوب فصله؟ Consequences of failing to trip
نظام فصل القواطع الأُخرى المُحيطة بقاط ع فشلت جميع أوجهه في الفصل/التوصيل معًا Pole discrepancy
مكونات دائرة الفصل Trip Circuit Components
منطق مُراقبة دائرة الفصل Trip Circuit Supervision Logic
أهمية دائرة الفصل و أمثلة تطبيقية عليها Trip circuit & Examples
مبين حالة دائرة الفصل مستخدمة في القواطع صناعة MITSUBISHI
مبين حالة دائرة الفصل مستخدمة في القواطع صناعة TOSHIBA
الأوضاع المختلفة لمبين حالة دائرة الفصل Trip Circuit Indicators
للقواطع صناعة Mitsubishi و Toshiba
جهاز مُراقبة دائرة الفصل طراز MVAX21
جهاز مُراقبة دائرة الفصل طراز MVAX31
جهاز مُراقبة دائرة الفصل طراز ZETTLER
جهاز مُراقبة دائرة الفصل طراز TRC 4800
جهاز مُراقبة دائرة الفصل طراز XR250
جهاز مُراقبة دائرة الفصل طراز XR350
جهاز مُراقبة دائرة الفصل طراز XR351
جهاز مُراقبة دائرة الفصل طراز TSG 913
جهاز مُراقبة دائرة الفصل طراز GKAD1-22
جهاز مُراقبة دائرة الفصل طراز SPER1C1
النظام رقم 1 لمُراقبة دائرة الفصل بواسطة جهاز حماية طراز MICOM P543
النظام رقم 1 لمُراقبة دائرة الفصل بواسطة جهاز حماية طراز MICOM P543
النظام رقم 5 لمُراقبة دائرة الفصل بواسطة جهاز حماية طراز MICOM P543
مقارنة بين الأنظمة الثلاثة لمُراقبة دائرة الفصل بواسطة جهاز الحماية طراز MICOM P543
النظام رقم 1 لمُراقبة دائرة الفصل بواسطة جهاز حماية من طائفة SIPROTEC
النظام رقم 1 لمُراقبة دائرة الفصل بواسطة جهاز حماية من طائفة SIPROTEC
مُراقبة دائرة الفصل في جهاز حماية طراز L90 من صناعة شركة GE
Anti-Pumping circuit
Power Line Carrier (PLC) Line Trap
نظام طرح الحمل عند انخفاض الجهد (المركب على الدوائر جهد 151 ك ف)
نظام طرح الحمل عند انخفاض الجهد (المركب على القضبان جهد 151 ك ف)
المراجع References
مرحل زيادة تيار و تسرب أرضي من نوع Static
مرحل رقمي من صناعة شركة ABB
اعتمادية نظام الحماية
تسلسل عملية عز العطل منذ حدوثه
نظام فصل خاك عند تداخل منطقتي حماية القضبان و حماية الخط
التدر الزمني المُحدد بين أجهزة الحماية المتتالية
أشهر المُنحنيات للعلاقة بين التيار و الزمن
جهاز الحماية Protective relay : هو كيا ن قائ م بذاته يضم ملف اً أو أكثر من ملف أو جازءً ا ثابتا اً و جازءً ا متحركا اًا أو دائارة اساتاتيكية و وسيلة لتغيير قيم الضبطا وتحديد الوقتا وماا إلاى ذلاك. و يشاكل جهااز الحماياة عنصار اً هاما اً مان نظام الحماية. يُسمى جهاز الحماياة عموما اً وفقا اً لنوعاه مان البنااء أو مبادأ العمالا علاى سابيل المثا جهااز الحماياة الكهرومغناطيساي Electromagnetic ا أو الاساتاتيكي Static ا جهااز الحماياة المسافية Distance ا أو جهاز الحماية التفاضلي Differential .
نظام الحماية Protective System : و هو يتاألف مان محاولات تياار Current Transformers أو محاولات جهاد Voltage Transformers وأجهزة حماياة مرتبطاة بطريقاة معيناة عطااء الحماياة ضاد بعاض الحاالات الغيار طبيعياة ويسامى نظام الحماية وفقا لمبدأ التشغيل أو الحالة الغير طبيعية. من الأسماء المستندة إلاى حالاة غيار طبيعياة هو نظام الحماية ضد زيادة التيار Over Current ا و نظام الحماياة ضاد التسارب الأرضاي Earth Fault ا نظااام الحمايااة ضااد ارتفاااع أو انخفاااض الجهااد Over/Under Voltage . و ماان الأسااماء المستندة إلى مبدأ العملية هي نظام الحماية التفاضليةا ونظام الحماية المسافية.
أسلوب الحماية Protection Scheme : و هو يتكون من مجموعة من نظم الحماياةا علاى سابيل المثاا محاو القادرة Power Transformer يركب له أكثر من نظام حماية نظام مثل نظام الحماية التفاضلية و نظام الحماية ضد زياادة التياار و التسرب الأرضي على جوانبه العالي و المتوسط و المنخفض ا ا جهاز الحماية الغازية Buchholz بوخولز. ومن هنا جاءت خطة الحماية وتضام مجموعاة مان أنظماة الحماياة. أسالوب الحماياة يسامى وفقا لاسم المعدات المحميةا فمثلا أسلوب حماية المحولات و أسلوب حماية الخطوط الهوائية.
إحكام أمر الفصل عن طريق التعزيز بالتوازي
توصيلات نظام حماية القضبان BBP لمحطة ثُنائية القُضبان مُقسمة لأربعة أقسام
جهاز مُراقبة دائرة الفصل طراز MVAX31 عندما يكون القاطع موصلًا
توصيلات جهاز مُراقبة الجهد من طراز MVAG21 صناعة شركة Alstom
دورة تدريبية في قراءة مخططات الحماية والتحكم
دورة تدريبية في حماية المحولات الكهربائية
أنظمة الحماية في محطات النقل
أساسيات وتطبيقات في نظم الحماية لشبكات النقل
دورة تدريبية في حماية الخطوط الهوائية
الوقاية في النظام الكهربائي
دورة تدريبية في حماية المحولات الكهربائية
أساسيات وتطبيقات في نظم الحماية لشبكات النقل
محولات الجهد و التیار CTs & VTs
الوقاية في النظام الكهربائي
Devices and description of this sample SLD
- 7RED 670: Main-1 Differential / Distance Protection
- 7SD522: Main-2 Differential / Distance Protection
- 7VK87: CB Fail Protection Relay with Backup DOC/DEF Protection for OHL bays1
- 7KE85: Disturbance Recorder
- 7SD82: Main-1/2 Cable Differential Protection
- 7UT82: Low Impedance Restricted Earth Fault Protection
- 7SJ82: CB Fail Protection Relay with Bac kup OC/EF Protection
- 7SS85: Main-1/2 Centralized busbar Protection
- MFM: Multifunction Meter with transducer outputs for NCC measurements and display for indication of measured values.
- 6MD85: Bay Controller Unit (BCU)
- 85X, 85R1, 85R2: 7PA27, Intertrip Receive Relay
- F85: SWT3000, Intertrip Unit for OHL & UGC Bays
Following shows the ANSI code and functional
- 21: Distance protection
- 25: Synchrocheck
- 50: Definite time overcurrent protection
- 50N: Definite time earth fault protection
- 50BF: Circuit-breaker failure protection
- 51: Inverse time overcurrent protection
- 51N: Inverse time earth fault protection
- 64: Sensitive ground-fault protection
- 67: Directional overcurrent protection
- 67N: Directional earth fault protection
- 68: Power swing blocking
- 79: Automatic reclosing
- 87: Differential protection
- 87B: Busbar differential protection
- FL: Fault Locator
- Single Line Diagram + Legend
- Electrical Equipment Layout
- HV Line & Functional Drawing and terminal
- Server cabinet
- Transformer & Ground Protection Automation
- AVR Control
- Outgoing and Transformer Monitoring
- Control and Interlocking logic diagram
- UPS Board & General arrangement
sample Siemens 6MD diagram
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General Philosophy
In today’s competitive market scenarios, power utilities are under tremendous pressure to cut down their maintenance costs as they form a significant portion of the operation costs. This has led the utilities to adopt condition-based maintenance of the equipment rather than the usual preventive maintenance being carried out at a fixed interval of time. Maintenance intervals are normally fixed based on the type of equipment and sometimes on the equipment history. However, tests or measurements are also carried out to assess the condition of the equipment.
Different types of maintenance being done on equipment are:
- Breakdown maintenance
- Preventive maintenance
- Condition-based monitoring
- Reliability centered maintenance
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Number of Pages: 129
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Causes Of Major Substation Types of equipment And Remedial Measures Failures
This section briefly describes the probable causes of failure of significant substation equipment viz. Power Transformers, Reactors, Circuit Breakers, Instrument Transformers, Surge Arrestors, etc., and remedial measures taken to prevent such failures.
Maintenance Techniques For Switchyard types of equipment (CBs, Instrument Transformers, Surge Arrestors, And ISOLATORS)
This section briefly covers the maintenance practices/techniques being adopted by the power utilities for switchgear pieces of equipment installed in EHV/HV stations. However, competitive market utilities are under tremendous pressure to bring down maintenance costs in the present scenario. This has led to the adoption of condition-based monitoring rather than conventional scheduled maintenance. The frequency of the condition-based maintenance is fixed based on the type of equipment and its previous history. Tests or measurements are carried out to determine the condition of the equipment. It is the general experience of practically all the utilities that most of the equipment doesn’t show any abnormality during scheduled maintenance and there is no guarantee that the equipment shall not fail before the next scheduled maintenance. Thus, the scheduled maintenance efforts are in vain as well as costly because of shut-down time and manpower costs. Hence modern condition-based techniques are being adopted which are designed to continuously monitor the function parameters and also assess the deterioration of the components before a mal-operation occurs.
Maintenance of Transformers and Reactors
The techniques/procedures being adopted for both preventive maintenance and condition-based monitoring in respect of EHV transformers and reactors are briefly discussed in this section.
UNDERGROUND CABLES
Over a hundred years ago, Gautapercha was used as an insulating material for cables, which worked satisfactorily for telegraphic lines. However, with the development of the power current, changes in cable insulation became essential. While carrying power currents, cables became hot and heat sensitive. Gutta-percha was, therefore, found unsuitable for insulated power conductors. To suit the new requirements, a superior insulation system using a fibrous material was dried, impregnated under vacuum, and enclosed in a seamless lead sheath. They were the forerunners of paper-insulated lead sheathed cables that came into existence around 1890 and have been used since then.
Safety Electrical Clearances
Most of the equipment in a substation is provided with sufficient insulation from breaking down, yet others like bus bars, terminations of high voltage equipment, the equipment connected to take-off structures, etc; are bare unlike in gas-insulated substations. There is a need for assurance that the breakdown or flashover will not occur to the operating personnel and that some safe distance is to be maintained. As per the studies and experience gained over a period, various bodies like CEA in India and elsewhere are issuing guidelines from time to time to maintain certain minimum safety clearances depending upon the voltage class from bare conductors and parts of various types of equipment exposed to the atmosphere. The provisions are mandatory and all the concerned like utilities and consumers have to maintain these minimum safety clearances. They are necessary for the safety of the operating personnel and the safety of the equipment.
Earthing for EHV Sub-stations
One of the important aspects of the operation of protective equipment is proper earthing. By earthing, it means making a connection to the general mass of the earth. Earthing also increases the reliability of the supply service as it helps to provide stability of voltage conditions, prevent excessive voltage peaks during disturbances, and also as a means of providing a measure of protection against lightning. Its use is widespread in the supply network right from the generation to the apparatus on the consumer premises. The requirements of earthing vary at different points based on the fault level, soil resistivity, and the safety considerations
Instantaneously One of the important aspects of the operation of the protective equipment is proper earthing. By earthing, it means making a connection to the general mass of the earth. Earthing also increases the reliability of the supply service as it helps to provide stability of voltage conditions, prevent excessive voltage peaks during disturbances, and also as a means of providing a measure of protection against lightning. Its use is widespread in the supply network right from the generation to the apparatus on the consumer premises. The requirements of earthing vary at different points based on fault level, soil resistivity, and safety considerations.
Instantaneously overcurrent relay operates when the current exceeds its Pickup value. The operation of this relay is based on the current magnitude and it is without any time delay.
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General:
- Check the appearance of the motor; Check for body damage or damage to the cooling fan blade or shaft
- Manually rotate the shaft to check the bearing condition; Check for free & smooth rotation.
- Note the motor data from the motor NAMEPLATE
- Earth Continuity: Use your ohmmeter to verify the resistance between earth and the motor frame is less than 0.5 Ω
- Power supply– correct voltage (230 volts per line), 415 v between Ll to L2, L2 to L3, and, L3 to L1
Three Phase:
- Ensure the terminal for the power supply is in good condition. Check the connection bar for the terminal (U, V, W ). Connection type – STAR OR DELTA
- Confirm the power supply VOLTAGE for the electric motor. 230/400.
- Using the multimeter, check the continuity of winding from phase to phase (U to V, V to W, W to U). Each phase to phase must have continuity if the winding is OK
- Check the motor winding ohms reading using a multimeter or ohmmeter for the phase to phase terminal (U to V, V to W, W to U ). The ohms reading for each winding must be the same (or nearly the same)
- Insulation resistance of motor winding using Insulation tester meter set to the 500 Volt scale (1000v DC). 1. Check from phase to phase (U to V, V to W, W to U) and 2. check from phase to earthing (U to E, V to E, W to E). Minimum test value of the electric motor is 1 Meg Ohm (1 MΩ)
- With the motor running, check the running amps of the motor using a Clamp on the meter. Compare to the FLA on the nameplate of the motor.
- If every step is completed, decide the condition of an electrical motor either OK or NEED TO REPAIR
Single Phase
Check the motor winding ohms reading using a multimeter or ohmmeter. (C to S, C to R, S to R). The reading for starting to run should be equal to C to S + C to R.
Correct electrical terminal identification
There are three-terminal connections on a hermetically sealed motor compressor and are as follows: Common (C), Start (S), and Run (R). To identify the correct terminal connection the following procedure applies:
- The highest resistance reading is between the start and run terminals
- The middle resistance reading is between the start and common terminals.
- The lowest resistance reading is between the run and common terminals.
Transformers and Generators are voltage sources. They are traditionally protected by an Overcurrent + Earth fault relay, normally mounted in the breaker panel. It should be noted that this protection alone is not adequate.
When an earth fault occurs within the zone defined as A in the following figure (Internal fault), or within the machine, the fault current will circulate within the zone or the machine. The fault current will not flow through the CTs connected to the O/C +E/F relays near the breaker. This will cause a no-trip situation when there is a fault in zone A.
Consequently, a separate scheme is required to detect internal earth faults. This scheme is called Restricted Earth Fault (REF) scheme. It should be noted that the fault currents in Zone A are limited by the impedance of the equipment in the zone – for transformers and generators it is very low – the fault currents can rise very fast and damage the equipment. Consequently, REF protection is of utmost importance for generators and transformers.
Why is this called Restricted E/F?
The name Restricted is derived since the objective of the protection is to detect the earth fault is restricted to the specific zone, starting from the breaker to the machine terminals. In the case of a generator, the machine terminal is the neutral point. In the case of a transformer, the machine terminal becomes the star point of either the primary or secondary winding or both. In the case of delta winding, it is the winding itself.
How can we detect internal earth faults?
It is well established that the sum of currents at the beginning of zone A should be equal to the sum of currents exiting the zone. Two sets of CTs are used to derive the sum of currents at the inlet and exit. A fault in the zone will result in a difference in current.
An overcurrent relay is used to measure the difference in the sum of these currents. Please refer to fig.2 where a typical REF scheme is shown. The REF relay is connected between P & S. It will pick up if there is enough voltage across P-S to drive the pickup current through the relay.
There are two current sources in the CT secondary circuit PQRSTU:
- the current produced by CT X (loop RSPQ)
- the current produced by CT Y (loop UPST)
Under normal conditions, a vectorial sum of the currents of these two CTs will be equal and opposite in the branch P-S (ie) the resultant current in the branch PS will be zero. In this situation, the currents of CT X and CT Y will circulate in the loop PQRSTU. The voltage across P-S will be zero.
When there is an earth fault within zone A, the currents of X & Y CTs will not be equal – a small difference in current will flow in the branch P-S. This current will result in a voltage across P-S – since the current flows through the relay impedance. If this voltage is adequate to operate the relay, the relay will pick up – thus detecting a fault within the zone.
What if a fault occurs outside the zone?
For a fault outside the zone, the currents through CTs X & Y will be the same the resultant current through P-S will still be zero and the relay will not pick up. In this case, the fault has to be cleared by another O/C + E/F relay connected near the breaker.
Why is a Stabilizing resistor required in the REF scheme?
We have said in sections 3 & 4 that the REF relay will detect a fault within a zone restricted between two CTs and it will not detect a fault outside the zone defined by the CTs. This is true, only for ideal conditions- where the two CTs are perfectly matched. Following mismatches will occur under practical situations in the field:
- the CT secondary impedances may not be equal
- the lead wires connecting the CT secondaries to the relay may not have equal resistance
- the CTs may have different ratio errors and phase angle errors – due to this, the secondary currents will not be equal even if the primary currents are the same
- the CTs may have different saturation characteristics – this will cause a small difference in the secondary currents for the same primary current
The cumulative effect of all the above can make the relay trip even when there is a full load current flowing in the primaries – through the primary side currents are the same, the secondary side currents need not be the same – a voltage sufficient to trip the REF relay may develop across P-S and hence the relay will trip.
To make the relay insensitive to this voltage produced by CT mismatch, a resistor is added in series with the relay. Once this resistor is added, the relay will need a voltage that is higher than the voltage produced by the CT mismatch. This resistor is called a stabilizing resistor – this is an important component in the REF scheme –since this ensures stability in the scheme by avoiding spurious tripping.
What is knee point voltage?
It should be noted that the actual input circuit to trip mechanism (consisting of the relay + stabilizing resistor) has become a high impedance circuit. If the relay has to trip, the CT secondaries should produce sufficiently high enough voltage to activate the relay, after allowing for the drop across the stabilizing resistor.
To ensure the CTs produce enough voltage, an additional specification the Knee point voltage – is included for the CTs used for REF protection.
Knee point voltage (KPV)is defined as the point on the magnetizing curve (of the material used for the CT core) where the core will need a 50% increase in the magnetizing force (ampere-turns) to cause a 10% increase in the flux density. (voltage build-up across secondary). In effect, KPV defines the end of the linear portion of the BH curve. The higher the KPV, the larger the linear zone, and the better will be secondary output for higher fault currents. The higher the KPV, the better the chances of a high impedance relay trip.
How can we calculate the value of the stabilizing resistor and KPV?
The value of the stabilizing resistor and KPV will depend on the following parameters which are unique to a given feeder:
- The impedance of the CT secondaries
- Lead wire resistance between the CT secondaries and the REF relay
- The impedance of the REF relay – this can vary concerning pick upsetting. We have to consider the relay impedance at the pickup setting being contemplated for the feeder.
- The maximum fault current which can occur on the CT secondary side CT should not saturate under these maximum fault conditions. If the CT saturates, it will offer an alternate path for the resultant current and the REF relay may not trip.
What are L&T solutions for REF protections?
L&T manufactures a high impedance Overcurrent relay which is ideally suited for the REF protection of generators and transformers. Typical schemes are shown in figure 3 and figure 4.
L&T offers a unique feature in the REF relay SC14S – in addition to the instantaneous trip, the user can select a definite time delay of either 100 milliseconds or 200 milliseconds. In the case of small transformers & generators ( up to 5 MVA), the feeder trips during breaker closing. This mainly is due to the large inrush current causing a momentary difference in CT secondary currents due to a mismatch in saturation characteristics. A 100-millisecond time delay will help in this case.
Figure 3 shows a typical scheme for REF protection for generators. The scheme envisages the following;
- 3 nos. phase CTs
- 1 no. neutral CT
- 1 no. Relay SC14S
- 1 no. Stabilizing resistor
The following figure shows a typical scheme for REF protection for transformers. It should be noted that transformers will need two REF schemes – one on the primary side and the other on the secondary side.
For the transformer’s primary side, which is usually delta connected, the following are envisaged in the REF scheme :
- 3 nos. phase CTs
- 1 no. Relay SC14S
- 1 no. Stabilizing resistor
For the transformer’s secondary side, which is usually star connected, the following are envisaged in the REF scheme :
- 3 nos. phase CTs
- 1 no. neutral CT
- 1 no. Relay SC14S
- 1 no. Stabilizing resistor
All you need to do is to download these excel files and you can work with them straight away. These test sheets can be filled on your PC or can be printed and filled in by hand. These test sheets are not copyrighted so you can edit them, change them as you wish.
- GENERAL CHECK
- OVERCURRENT PROTECTION (51)
- OVERCURRENT PROTECTION (50)
- EARTH FAULT PROTECTION (51N / 51G)
- EARTH FAULT PROTECTION (50N / 50G)
- RESTRICTED EARTH FAULT PROTECTION (64 REF)
- UNDER VOLTAGE PROTECTION (27 / 27R)
- OVERVOLTAGE PROTECTION (59)
- UNBALANCE & LOSS OF PHASE PROTECTION (46)
- LOCKED ROTOR PROTECTION (48 – 51LR)
- OVERLOAD PROTECTION (49)
- DIFFERENTIAL PROTECTION (87)
- SYNCHRON CHECK (25)
- UNBALANCE & LOSS OF PHASE PROTECTION (46)
- OVERLOAD PROTECTION (49)
- SYNCHRON CHECK (25)
- SPECIFICATION OF C.T
- INSULATION RESISTANCE TEST
- RATIO AND POLARITY TEST
- VISUAL CHECK
- EARTH FAULT RELAY TEST
- OVERLOAD RELAY TEST
- CURRENT TRANSFORMER TEST
- FUNCTION TEST
- Wiring (arrangement, marking)Conformity with single line and 3 line diagram
- terminals(arrangement, marking, labeling)
- Auxiliary circuit test (Operating of lighting, heaters, thermostat, fans….)
- DC injection & check loop
- AC injection & check loop
- Mechanical position indication.
- Electrical closing local/remote
- Electrical tripping local/remote
- Earthing system mechanism check
- ALARM INDICATIONS -LOCAL/REMOTE
- OPERATION OF SAFETY SHUTTERS
- ALIGNMENT OF MAIN AND AUXILIARY CONTACTS
- MECHANICAL CLOSING AND TRIPPING
- INSULATION RESISTANCE TEST
- RESISTANCE TEST
- EARTHING SYSTEM
- INSULATION RESISTANCE TEST
- RATIO TEST
- POLARITY TEST
- INSULATION RESISTANCE TEST
- RATIO AND MAGNETIZING TEST
- VECTOR GROUP TEST
- INSULATION RESISTANCE TEST FOR CT
- RATIO TEST FOR CT
Elec-Engg, provides design and engineering services on power projects, ranging in complexity from simple low voltage industrial designs to 500 KV substation design engineering. Elec-Engg can prepare all plans and schematic drawings in AutoCAD to enable customers to examine system design concepts and conformity with total design criteria before the manufacturing, construction, and permit process.
- Protection and relaying design
- Substation automation design
- Device and equipment specification
Protection and relaying design
- One-line diagrams
- Three-line diagrams
- Three-line diagrams
- DC Schematics
- Control logic
- I/O mapping
- Point to point wiring schedules
- Control panel layout for protective devices
Substation automation design
- Substation communications for remote operation and control
- Telemetry
- IED network
- Smart meters
- Local and remote monitoring
Device and equipment specification
- Protective devices
- Remote Terminal Units (RTUs)
- Relay and Substation Networks
- Metering Systems
- Transformer, circuit breakers, and lines/feeders monitoring
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-
ABB PCM 600 training€85 -
ETAP Training€80 -
Testing and Commissioning€150 -
PSCAD Training€40 -
DIGSILENT Training€130 -
Busbar protection training€40 -
Generator Protection Training€80 -
MiCOM Relays Training€45 -
IEC 61850 Training€65 -
DIGSI 5 Training€90 -
DIGSI 4 Training€50
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Suggested Combined packages
Learning is a continuous process and enables us to be competitive in our field. Consistent with this belief and built on a strong experience in this field, we offer video training courses for practicing professionals in the area of Substation Automation and Protection Relays. The material of each course is designed to help you to be a professional in the field.
we provide training courses at your site or online, contact us for reservations.
ETAP has been designed and developed for engineers to study different aspects of power systems in one integrated package.
This course is structured into 4 chapters, with theory and practical examples. It is designed for protection engineers to understand the power system, short circuit concept, protection, and coordination.
Chapter 1, part 01: overviews different tools in ETAP with an example. ETAP offers a suite of fully integrated electrical engineering software solutions including load flow, short circuit, protection and coordination, harmonic analysis, transient stability, cable ampacity, arc flash, optimal power flow, and more. Some of these tools may not be required in our study. So we should know which part is the most important tool for us. This part overviews different parts of ETAP before starting the course. In this way, we can find the main tools and parts on which we should focus on.
Chapter 1, part 02: An introduction to ETAP software. We start with creating a new project and explaining different toolbars and menus in ETAP.
Chapter 1, part 03: This part overviews the main parameters of a busbar, 2 winding transformers, and 3 winding transformers.
Chapter 1, part 04: Overview of the main parameters of a transmission line and cable.
Chapter 1, part 05: overviews the main parameters of a static load, lumped load, and power grind.
Chapter 2, Part 01: shows how to study parameters with load flow analysis. To do so, we run a load flow analysis on a simple one-line diagram and study the effect of different parameters.
Chapter 2, Part 02: overviews the load flow study case and plot option settings.
Chapter 2, Part 03: presents a practice to understand the parameters of load, equipment cable, busbar, cable, and transformer deeply. Then it presents load flow and load analyzer tools.
Chapter 2, part 04: overviews the main parameters of low voltage circuit breaker and high voltage circuit breaker.
Chapter 2, part 05: overviews the main parameters of an induction machine and how to model an induction machine in three different methods.
Chapter 2, part 06: overviews the main parameters of a synchronous generator.
Chapter 2, Part 07: presents a practice to understand the parameters of an induction machine and a synchronous generator deeply.
Chapter 2, Part 08: presents how to remove the critical alarm. To do so CB overload, cable overload, and transformer overload alerts have been removed. To remove these alerts, we should know how to do cable sizing and transformer sizing in ETAP.
Chapter 3, Part 01: shows the effect of different parameters in the short circuit current. An induction motor can inject current to a grid even more than an equivalent generator, this part show this concept in ETAP.
Chapter 3, Part 02: explains the settings in the short circuit analysis. To explain the parameters of short circuit analysis and understand the short circuit modeling in ETAP, we have simulated an AG fault in PSCAD.
Chapter 3, Part 03: presents several duties and tools in short circuit analysis mode.
Chapter 4, Part 01: overviews the elements which are related to relay protection and coordination.
Chapter 4, Part 02: shows overcurrent parameters in ETAP and relay configurations software. The setting of overcurrent relays (P121 and distance relay SEL 421) are shown in the configuration software (Esergy studio and AcSELerator quick set software).
Chapter 4, Part 03: In this part, three-phase voltage and currents are injected into the SEL 421 with a secondary test kit (Omicron CMC 256) to explain the values in a relay and test the intravenous overcurrent function.
Chapter 4, Part 04: presents how to calculate the CT ratio and time delay overcurrent elements (Ansi 51). Then the coordination between two relays is explained with the help of start view tools.
Chapter 4, Part 05: the coordination between three relays and how to test the coordination with the help of the sequence viewer tool are presented.
Chapter 4, Part 06: This part explains the plot option parameters in the Star View.
Chapter 4, Part 07: This part explains how to set instantaneous overcurrent parameters (ANSI 50).
Chapter 4, Part 08: presents how to calculate overture ground elements in ETAP and how to set these parameters in the relay.
Chapter 4, Part 09: This part presents how to add a proper fuse to a feeder and coordinate the relays with the fuse.
Chapter 4, Part 10: This part explains the protection page of the main elements and how to protect an element with an overcurrent element.
Chapter 4, Part 11: This part presents helpful tools in the protection and coordination study room.
WhatsApp: +989129613659
Email: info@elec-engg.com
These days can’t perform many of the required analyzes in electrical networks without using the relevant engineering software. Therefore, engineering software has been very effective in industrial environments. One of the most famous software is ETAP which is used in the analysis of distribution networks in industrial Plants and is made by the Operational Technology company. In this training package, in addition to collecting the required technical information in an attractive multimedia environment, various analyzes, and how to do them using ETAP software are presented practically.
Learning is a continuous process and enables us to be competitive in our field.
In this package, you get Trained DIGSI 4 and DIGSI 5 to work with SIPROTEC 4 & 5, how to work with Etap software, and how to use IEC 61850 for integration and communication between different equipment brands.
Product detail:
- DIGSI 4 video training (3 hrs)
- DIGSI 5 video training (7 hrs)
- IEC 61850 training (4 hrs)
- ETAP for protection engineers (5.5 hrs)
- Trainer: Dr. Saeed Roostaee
- Language: English
- Full lifetime access
- DIGSI 5 Training: 435 Minutes – Full HD Size ( 1.9 GB), In English, By Dr. Saeed Roostaee
- DIGSI 4 Video Training: 185 Minutes, In English, By Dr. Saeed Roostaee
- IEC 61850 configuration Video Training: 4 hrs Language, In English, By Dr. Saeed Roostaee
- ETAP Video Training: 5.5 hrs, In English
contact us to get this impressive IEC61850 collection
- IEC 61850 Precision Time Protocol IEEE 1588
- IEC 61850 PRP Redundancy
- IEC 61850 Quality of Service
- IEC 61850 Redundancy Protocols
- IEC 61850 Substation Architecture
- IEC 61850 Substation Design Considerations
- IEC 61850 Time Synchronization
- IEEE 1588 – Master, Slave, and Transparent Clocks
- IEEE 1588 Synchronization Basics
- Important Properties of PTP
- Integrating Serial and IP Ethernet
- Introduction to IEEE 1588 Precision Time Protocol
- Network Management System Deployment Scenarios
- Network Management System Security
- Network Security- The Defense in Depth Model
- NMS User Guide- Device Discovery
- NMS User Guide- Permissions and Users
- NMS User Guide- Statistics
- NMS User Guide- Views and Alarms
- Product Overview – RAPTOREye
- PTP Profiles
- PTP Timing Requirements in Power Systems
- Securing a Switch and Functional Architecture
- Security Standards and the NERC CIP Framework
- Serial IP Conversion Use Case
- Switch Hardening_ Local Password and Access Authentication
- Switch Hardening- Finalizing the Security Configuration
- Switch Hardening- Secure Management and Configuration
- The Best Master Clock Algorithm
- The Gap Between Legacy Serial and Ethernet
- The Network Management System FCAPS Model
- Time Transfer Technology Comparison
- Virtual Serial Port Redirection
- What is a Network Management System (NMS)
- Name Size Date Modified
- Best Practice – Securing SNMP
- Best Practice_ Securing Management Protocols
- Best Practice- Enabling Remote Logging
- Best Practice- Time Sync, Disable Services, and Port Security
- Converting Serial to IP
- Core Redundancy and OSPF
- Defense in Depth Model
- Device Hardening- Best Practice Basics
- Device Level Security and Switch Functional Architecture
- Digital Substations- An Introduction to IEC 61850
- Ethernet Network Overview
- Gateway Redundancy – VRRP
- How does a VLAN work
- How PTP IEEE 1588 v2 Works
- HSR-PRP Redundancy
- IEC 61850 Communication Protocols
- IEC 61850 HSR Redundancy
- Interior Routing Protocol
- Layer 2 and Redundancy
- Layer 3 Concepts – Routing
- MAC and IP Addressing Format
- Managed vs Unmanaged Switch and Router
- Migration from Serial to Ethernet
- Redundancy Architecture from Substation to Control Center
- Redundant Network Timing Requirements
- Routing Functions and The Routing Table
- Static Routing vs. Dynamic Routing
- STP and RSTP Redundancy
- The Physical Layer
- VLAN Basics
- VLANs (IEEE 802.1Q)
- VLANs and Redundancy
- VLANs, Routing, and Cybersecurity
- What Is a Switch
- What is a VLAN
- What is Ethernet
- Bridging the Gap Ethernet, Serial, and Legacy Equipment in Substations
- Digital Substation Communications – What you Need to Know About IEC61850 Network Design
- Educational Training Introduction_ Networking 101 For OT Professionals
- IEC61850 Overview Video
- It’s about Time – Intro to IEEE 1588 and Precision Time Protocol
- Keeping an Eye Out_ Understanding Network Management Utilization
- Network Hardening, NERC CIP and the Smart Grid
- Network Redundancy- What Are Your Options- Why Choose One Technology over Another
- Networking 101 for OT Professionals_ Ethernet and its Application in Critical Utility Networks
- Networking 101 For OT Professionals- Making Sense of the Layers. Benefits of Layer 2 and Layer 3
- Switch Hardening Best Practices- How to Secure Your Industrial Network
- VLAN Fundamentals and Its Benefit in Network Design for Mission Critical Applications
- Name Size Date Modified
- Alex Apostolov about the past, present and the future of relay protection
- Christoph Brunner about origins of IEC 61850 and its future developments — Big Energy.
- IoT for Utility and Industrial Power Grids- Where Is the value-
- Route to IEC 61850 (2016)- The Concept of IEC 61850
- Route to IEC 61850- Engineering IEC 61850 systems
- Route to IEC 61850- HMI and Station Control
- Route to IEC 61850- Testing IEC 61850 Systems
- Route to IEC 61850- The Concept of IEC 61850
- Route to IEC 61850- Time Synchronization for IEC 61850
- The Future of Industrial Automation Video – GE Intelligent Platforms
- Welcome to the Digital Substation World I Episode 01
- ABB Goose config
- Cara Create ICD_SCD File (IEC61850 Protocol) dari Relay Reyrolle Argus 7SR
- Fiber Optic and Data Transferring between Substations and OTDR
- GE course
- GE DCS
- GE Geese confgi procedure
- Hands on Protection Testing using IEC 61850
- How to configure IEC 61850 with Easergy Studio
- How to enable Virtual Machine on Latest Windows Host Operating System
- How to generate the IEC 61850 MMS GOOSE Protocol traffic using SCL files with IEDScout
- How to perform the compare and find difference between the SCL files
- How to save the SCL file from IEDScout
- How to setup OpenSCD to be used in offline
- How to subscribe the GOOSE messages from third-party relays to ABB make relays in PCM600
- How to use IEDScout in offline and the benefits behind
- How to use IEDScout in offline to practic
- IEC 61850 implementation-related documentation for IEDs and Tools
- IEC 61850 Overview Part 9 SCL Files
- IEC 61850 programming training
- iec61850.
- ied scout
- Introduction and contents overview
- Introduction to packet sniffing and basics of communication protocols
- Making right connections to start sniffing in switched environment
- Start capturing with Wireshark and manage its basic settings
- Using Filters
- Working with packets
- Working with capture files
- Digital substation traffic capture analysis
- Practical demonstration
- IEDScout on MBX1 IEC 61850 IED Simulation with Positive use cases
- ieee1588
- OMICRON Customer Portal Overview
- Route to IEC 61850 (2016)- The Concept of IEC 61850
- SEL Goose config
- SETR850 schnider
- Simulating an IED from IEDScout PC with 102 port-occupied services
- StationScout offline benefits-Part-1
- STRATON IEC61850
- Trick Rahasia Edit CID File IEC61850 untuk Integrasi SIPROTEC5 PACIS Alstom
- Using IEC 61850 to Solve Protective Relaying Challenges (2011).mp4 292 M
- ABB webinar
- Awareness of IEC 61850 communication standard – Preface and tutors introduction
- digsi 4 iec61850 config
- digsi4 report
- easergy pro
- ethernet
- How does Modbus Communication Protocol Work
- IEC 61850 Data Modeling Part 2 – Triangle MicroWorks Inc
- IEC 61850 in the Modern Substation
- IEC 61850 Standard for T&D Grids
- iec 61850 webinar omicron
- IEC 61850
- IEC_61850_Simply_usable_mit_closing.
- iot – 38 – Lecture 3.3 Packet Capture Demo
- Mensajes GOOSE en IEC61850 de Siemens
- omicron goose
- omicron products
- omicron SV
- Relational Database Concepts
- sip5 iec61850
- triangle
- Practical IEC 61850 for Substation Automation for Engineers and Technicians
- Video Session 2- Practical IEC 61850 for Substation Automation for Engineers and Technicians
- Video Session 3- Practical IEC 61850 for Substation Automation for Engine
- What is OSI Model
- What is the IEC 61850 protocol- How does it work- What’s the difference with other protocols
- SIPROTEC 5 certificate automation – using Enrollment over Secure Transport protocol
- Webinar SIPROTEC 5 certificate Secure Transport EST protocol
- Expert Talk – Overview of SICAM A8000, SIAPP & Web HMI
- Global Summit 2022 Digital switchgears for intelligent secondary distribution grid automation
- Global Summit 2022 Behind the scenes– Self optimized grid to the largest onshore fish farm in Norway
- Global Summit 2022 Conference Digital switchgear solutions for primary distribution
- Global Summit 2022 Conference Precisely tailored substation automation with SICAM A8000
- Global Summit 2022 Keynote Innovative technologies in electrification & automation for our future
- Global Summit 2022 Mastering distribution grid diversification by IoT SIPROTEC5
- Global Summit 2022 SICAM A8000 beyond the typical substation automation–New apps for the Etransition
- Global Summit 2022 Training How to write your own application for SICAM A8000 with SIAPP
- Migration of SICAM TOOLBOX II configuration
- SICAM Earth Fault Indicator – SICAM EFI Introduction Animation (FR)
- SICAM Earth Fault Indicator – SICAM EFI Introduction Animation
- Automation and remote terminal units SICAM A8000 RTU SIPROTEC-5 SIEMENS
- Sicam Application CP8050 Automation and remote terminal units A8000 RTU SIPROTE
ABB CAP 505 (Computer Aided Programming system) can be used to config the ABB RED 500 and SPACOM series. This training course introduces the hardware structure of the RE 500 series and then the configuration procedure of these relays in CAP 505.
Pre-recorded Videos
- Part 01: RE 500 relay hardware explanation (26 minutes)
- Part 02: CAP 505 user interface, create a project, and add relay REF 54 (13 minutes)
- Part 03: Create project structure (16 minutes)
- Part 04: Function blocks and IO configuration (8 minutes)
- Part 05: Blocking signal by inrush and Fuse failure (9 minutes)
- Part 06: Config Trip signals (4 minutes).
- part 07: Measurements and LEDs configuration (5 minutes).
- Part 08: Disturbance recorder configuration (3 minutes).
- Part 09: LCD configuration (8 minutes).
- Part 10: settings and download to the relay (15 minutes).
Course Contents:
- The hardware structure of ABB RE 500 series (REM543, REF543, REM545, REF 541, REF543, …)
- Introduce the CAP 505 and the user interface (Caption bar, Toolbar, Project Structure, Status bar, Status bar, Menu bar)
- Create a new project and add a case study relay (manage the project, project structurization, add new Rlay REF 543, The configuration dialog for REF54x device, add communication port)
- Create project structure (define the library, add Logical POUs, Physical hardware config, resources, tasks, assign tasks, …)
- Add function block and config Inputs and outputs ( add directional Overcurretn and Direction earthfall functions, Config analog inputs, binary inputs, and binary outputs, …)
- LED, LCD, measurement, and disturbance configuration (Config trip signals to the LEDs, config measurements to the LCD, Config the breaker position to the LCD)
- Settings and upload/download (explain the main parameters of the Directional overcurrent, Direcinal earth fault, disturbance recorder, Fuse fail, inrush current, …)
How to access the training course
Buy now and start learning:
- PCM 600 Introduction
- Communication and project setup in PCM 600
- Update Manager tool
- Hardware Configuration tool
- Read from IED
- Write to IED
- Application configuration in PCM 600
- Signal Matrix tool
- Parameter Setting tool
- Signal matrix and parameter setting in PCM 600
- Interlinking between Signal Matrix tool and Application configuration tool
- IED Compare tool
- Disturbance Handlin tool
- Signal Monitoring tool
- PCM 600 Monitoring
- Graphical Display Editor in PCM 600
- Graphical display editor
- Migrate configuration tool
- PCM Options
- IED user Management tool
- Scheduler
- Set Technical Key tool
- Goose Communication engineering (GCB)
- Changing the SCL version of IED
- Client-Server engineering (RCB) for vertical communication
Prerequisite Training packages
ABB REG670 Training package (Advanced level)
- Trainer: Dr. Saeed Roostaee (Profile on Linkedin)
- Pre-recorded videos
- Supplementary Files
- The course is still being recorded and new sessions will be added over time
- The course is licensed and you need a Windows computer to view the videos
- Download this course: contact us or leave a comment on this post
- For more info, please leave a comment on this post or contact us on WhatsApp: +989129613659
Course Details:
Configuration in the PCM600
- Generator, GSU, ET Transformer Unit Protection System
- Analog inputs, Generator & Transformer- CT and VT
- Generator protection functions (87G, 40G, 78, 50S, 46, 51V, 49S, 59, 27, 21G, 32R, 50/27, 64GB, 64R, 47, 64s-95 &100%, 81 O&U, 24G)
- GSU Trans Protection Functions (87T, 87GT, 64T(87N), 51N, 50/51T)
- Excitation Trans Protection Functions (50.51ET, 49ET)
- Trip matrix, Blocking logic
- Binary Outputs, LED Signal, Output Contact test
- Disturbance recorder
- IEC 61850 Signals
Parameter setting and Relay calculations
- 87G Generator Differential Protection
- 87T GSU Trans. Differential Protection
- 87GT Overall Differential Protection
- 40G Generator Field Failure Protection
- 78G Generator Pole Slipping Protection
- 50S, Generator Split phase overcurrent protection
- 46 Generator Negative Phase Sequence Protection
- 51V Generator Voltage-Dependent O/C Protection
- 49S Generator Stator Overload Protection
- 59G Generator Overvoltage Protection
- 21G Generator Underimpedance Protection
- 27G Generator Undervoltage Protection
- 32R Generator Reverse Power Protection
- 64S Generator 95%&100% Stator Earth Fault Protection
- 51/27 Generator Dead Machine Protection
- 64GB Generator Busbar Earth Fault Protection
- 64R Generator Rotor Earth Fault Protection
- 81O Generator Overfrequency Protection
- 81U Generator Underfrequency Protection
- 24G Generator Overflux Protection
- 47G Generator Fuse Failure Supervision
- 50/51ET Excitation Trans. Overcurrent Protection
- 49ET Excitation Trans. Overload Protection
- 51N-GSU Gen. Step-up Trans. Neutral Point OvercurrentProtection
- 64T GSU Trans. Restricted Earth Fault Protection
- 50/51T GSU Trans. Over Current Protection
- 50/51SST Station Service Trans. Over Current Protection
Click here to enroll in the course and get the certificate of the IEC 61850 compilation course
https://elec-engg.com/iec-61850-training-course/
- IEC 61850 TRAINING CERTIFICATE NUMBER C 1000: Click here to download
- IEC 61850 TRAINING CERTIFICATE NUMBER C 1001: Click here to download
- IEC 61850 TRAINING CERTIFICATE NUMBER C 1002: Click here to download
- IEC 61850 TRAINING CERTIFICATE NUMBER C 1003: Click here to download
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Training delivery: Face-to-face / Online sections on Google Meet + pre-recorded videos
Trainer: Dr. Saeed Roostaee
What you’ll learn
- Packet sniffing approaches and tools
- How to connect to switched network infrastructure to capture required data
- How to start with Wireshark and its basic settings
- How do you use capture and display filters in Wireshark?
- Tips and tricks on working with packets
- Tips and tricks on working with capture files
- How to analyze GOOSE, Sampled Values, and MMS traffic with Wireshark
- Practical examples
- Capture and interpret network traffic with Wireshark
- Understand core networking protocols – DHCP, DNS, TCP/IP
- Troubleshoot the top five network problems with Wireshark
- Analyze a cybersecurity attack with Wireshark
Content
Using Wireshark for traffic analysis in digital substations
- Introduction and Contents Overview
- Installing Wireshark and the Command Line Tools
- Introduction to packet sniffing and basics of communication protocols
- What are Wireshark Profiles and Why Should We Use Them?
- Hands-On with Wireshark
- Configuring Profiles, Adding Custom Columns
- Configuring the Wireshark Interface
- Making the right connections to start sniffing in a switched environment
- Start capturing with Wireshark and manage its basic settings
- Introduction to Wireshark Filters
Capture filters Vs display filters - Filtering for IP Addresses, Source or Destination
- Filtering for Protocols and Port Numbers
- Filtering for conversations
- Operators in display filters
- Working with packets
- Working with capture files
- Creating Display Filters in Wireshark
- Packets and the OSI Model
- Ethernet – The Frame Header
- Unicasts vs Broadcasts vs Multicasts
- The Internet Protocol – Learning the Header Values
- Following a Packet Through the Network – Re-Encapsulation
- Analyzing a Packet From Multiple Capture Points
- How IP Fragmentation Works
- The UDP Header Explained
- UDP Review
- Practical TCP – The Handshake
- Analyzing TCP Options
- How Sequence and Acknowledgement Numbers Work
- Slow application response time
- High Network Latency
- Network Packet Loss
- TCP Analysis Review
- Digital substation traffic capture analysis
- Practical demo with Wireshark
- Trainer: Dr. Saeed Roostaee (Profile)
- Pre-recorded videos with online access+Free updates +Free certification +Free technical support
Content:
Supplementary Files: The important related files/ videos /software and attached to the course as extra files.
Any queries, please feel free to contact me at: saeed61850@gmail.com
Part A: Introduction, general settings, Hardware & connection, Impedance/Vector/report View, the test object, …
- A 01 (Length: 02 min, Update: Oct 3, 2021): Introduction
- A 02 (Length: 05 min, Update: Oct 3, 2021): Strat page (Omicron)
- A 03 (Length: 06 min, Update: Oct 3, 2021): General settings (Omicron)
- A 04 (Length: 05 min, Update: Oct 3, 2021): Strat page (Vebko)
- A 05 (Length: 14 min, Update: Oct 3, 2021): Phasor view, Impedance view (Omicron)
- A 06 (Length: 06 min, Update: Oct 3, 2021): Phasor view, Impedance view, differential view (Vebko)
- A 07 (Length: 04 min, Update: Oct 3, 2021): Hardware connection
- A 08 (Length: 10 min, Update: Oct 3, 2021): Practical section with Omicron 256 plus, SEL 421
Part B: Overcurrent and Directional Overcurrent Functions (67, 67N, 50, 51, 50N, 51N)
- B 01 (Length: 19 min, Update: Oct 3, 2021): Test object, Overcurrent RIO block, testing of overcurrent
- B 02 (Length: 16 min, Update: Oct 3, 2021): Settings of the Overcurrent test module
- B 03 (Length: 15 min, Update: Oct 3, 2021): Practical section
- B 04 (Length: 17 min, Update: Oct 3, 2021): Practical section
- B 05 (Length: 06 min, Update: Oct 3, 2021): Practical section
- B 06 (Length: 15 min, Update: Oct 3, 2021): Practical section
- B 07 (Length: 09 min, Update: Oct 3, 2021): Practical section
- B 08 (Length: 15 min, Update: Oct 3, 2021): Practical section
- B 09 (Length: 22 min, Update: Oct 3, 2021): Practical section
- B 10 (Length: 23 min, Update: Oct 3, 2021): Practical section (directional overcurrent concepts, settings, practice)
- B 11 (Length: 06 min, Update: Oct 3, 2021): Practical section (directional overcurrent testing)
Part C: Differential Protection Functions (87G, 87T, 87L)
- C 01 (Length: 03 min, Update: Oct 27, 2021): Diff protection principal
- C 02 (Length: 11 min, Update: Oct 27, 2021): Diff parameters
- C 03 (Length: 12 min, Update: Oct 27, 2021): Diff RIO block
- C 04 (Length: 05 min, Update: Oct 27, 2021): Diff configuration
- C 05 (Length: 07 min, Update: Oct 27, 2021): Diff Operating Characteristic
- C 06 (Length: 12 min, Update: Oct 27, 2021): Diff Trip Time Characteristic & Diff Harmonic Restraint
Part D: XRIO and PTL
- D 01 (Length: 13 min, Update: Nov 13, 2021): RIO and XRIO history and why we should use this format for relay testing, RIO structure, XRIO structure, Differences between RIO and XRIO files, XRIO features & benefits, LinkToXRIO
- D 02 (Length: 05 min, Update: Nov 13, 2021): XRIO template, How to Import Relay Settings, How to find a proper XRIO template and filter based on the relay
- D 03 (Length: 08 min, Update: Nov 13, 2021): Common problems while loading the relay settings into a template and how to solve the issues, XRIO template based on the relay versions
- D 04 (Length: 06 min, Update: Nov 13, 2021): Explain a case study XRIO file
- D 05 (Length: 10 min, Update: Nov 13, 2021): Modify a case study XRIO file
- D 06 (Length: 09 min, Update: Nov 13, 2021): Modify the XRIO template, RIO blocks
Part E: Impedance Protection Functions
- E 01 (Length: 09 min, Update: Nov 26, 2021): Distance RIO block
- E 02 (Length: 07 min, Update: Nov 26, 2021): Advance Distance Test Module settings
- E 03 (Length: 08 min, Update: Nov 26, 2021): Distance protection function principal, Impedance View
- E 04 (Length: 18 min, Update: Nov 26, 2021): Analysis of several faults visually in the impedance view
- E 05 (Length: 19 min, Update: Nov 26, 2021): Analysis of several distance relays (RAZOA, ABB REL670, SEL421, Siemens 7SA8x, MiCOM P442, NR PCS 931S, Protecta)
- E 06 (Length: 08 min, Update: Nov 26, 2021): Distance Test Module settings
- E 07 (Length: 12 min, Update: Nov 26, 2021): Preparing XRIO file for testing of impedance protection functions
Part F: Autoreclosure Function (ANSI 79)
- F 01 (Length: 04 min, Update: Dec 03, 2021): Autoreclosure Description, auto reclose process
- F 02 (Length: 05 min, Update: Dec 03, 2021): Autoreclosure settings, Autoreclose timing diagram
- F 03 (Length: 11 min, Update: Dec 03, 2021): Autoreclosure simulation
- F 04 (Length: 12 min, Update: Dec 03, 2021): Testing of AR in state sequencer
- F 05 (Length: 09 min, Update: Dec 03, 2021): Testing of AR in the Autorecoser test module
Part G: Voltage and Frequency Protection Functions (ANSI 27, ANS59, ANSI81O, 81U)
- G 01 (Length: 06 min, Update: Dec 08, 2021): Ramping test modules and testing the frequency functions
- G 02 (Length: 05 min, Update: Dec 08, 2021): Paulse ramping test module
- G 03 (Length: 06 min, Update: Dec 08, 2021): Continous ramp and step ramp
- G 04 (Length: 11 min, Update: Dec 08, 2021): How to test Over/Under voltage protection functions (59, 27)
Part H: Study functions, testing, and commission of SIPROTEC 7UT6
- H 01 (Length: 10 min, Update: Dec 20, 2021): SIPROTEC 7UT6 setting description and configuration
- H 02 (Length: 14 min, Update: Dec 20, 2021): How to test differential function in SIPROTEC 7UT6, No combined characteristic feature, Automate testing by creating SIEMENS 7UT XRIO file
- H 03 (Length: 18 min, Update: Jan 01, 2022): The procedure of testing transformer protection with Quick CMC
Part K: Study functions, testing, and commission of MiCOM P44x
- K 01 (Length: 19 min, Update: Oct 31, 2022): Hardware and function description of the MiCOM P441, P442 & P444
- K 02 (Length: 17 min, Update: Oct 31, 2022): MiCOM Relay connections, communication, and Wire connection test
- K 03 (Length: 05 min, Update: Nov 1, 2022): Distance protection parameters and testing
- K 04 (Length: 10 min, Update: Nov 1, 2022): Switch on to fault protection (SOTF) function parameters and testing
- …
- Introduction, Software Installation, and general settings
- Different types of test modules
- Impedance/Vector/report View, Display settings
- Test Object, Hardware Configuration
- RIO, XRIO, and PTL
- Control Center, How to create and modify XRIO/ PTL files
- Transient module, Advanced transplay
- RIO Function Over Current, Define Element Characteristic, Pick-Up/ Drop-Off Test
- Testing of the Overcurrent and Directional Overcurrent Functions (67, 67N, 50, 51, 50N, 51N)
- Distance Configuration, Settings, Shot Test, Check Test, Search Test, Z\t Diagram, Zone Settings
- Testing of the Distance function (21)
- Principle of Differential Protection, Operating Characteristic, Differential Configuration, Differential Operating Characteristic, Differential Trip Time, and Harmonic Restraint
- Testing of the Differential protection function (87, 87G, 87T)
- Testing of the Power swing function
- Autoreclosure, shot and times, unsuccessful / Successful Sequence
- Testing of the Autorecloser function
- Testing of the Fault location function
- Testing of the Over/Under frequency (81O/ 81U)
- Testing of the Over/Undervoltage (59, 27)
- Testing of the Pole-Slip function (78)
- Testing of the Loss of Excitation (40)
- Testing of the Negative Phase Sequence (46)
- Testing of the Overload (49)
- How to test the distance function if the distance module is deactivated in the test universe software
- How to test differential function if the differential module is deactivated in the test universe
- Practical sections with testing of the relays (ABB REG670, MiCOM P441, MiCOM P123, …)
The testing & commissioning of the protection relays can be done by different testing software and hardware. In this training, we have used OMICRON Test Universe, Vebko AMpro, and FREJA win.
Need some experience people to join KBR-AMCDE, Oil and Gas, Al-Khobar, Saudi Arabia
About KBR-AMCDE
KBR-AMCDE is an entity formed to carry out general engineering and project management services under the Saudi Arabian Oil Company (Saudi Aramco) General Engineering Services Plus (GES+) initiative. KBR AMCDE provides front-end engineering and design (FEED), detailed design, procurement and project management services within the Oil & Gas industry. KBR-AMCDE specializes in front-end engineering design (FEED), detailed design, material procurement, and project management services (PMS). With extensive resources and technology, we deliver quality engineering packages to clients in Kingdom and overseas.
If you are qualified and experienced in PSCAD, please contact Mr. Narayanan Sivakumar with the below details:
Linkedin profile: linkedin.com/in/narayanan-sivakumar-95b80515
Email ID: narayanansivakumar1985@gmail.com
- Trainer: Dr. Saeed Roostaee (Profile)
- Pre-recorded videos
- The demo is available based on the request
- Course creation 8 April 2023
- Last update: 10 June 2023
- Total hours: 6 hrs and 17 min till 10 June 2023
- The updates will be added for free and no expiration.
Chapter I: Transformer Introduction
- Course introduction and transformer history (13 min)
- Concepts of the Electric Power Transmission Transformers (10 min)
- How does a Transformer work part I (7 min)
- How does a Transformer work part II (4 min)
- Transformer Parts and Functions (28 min)
- Single-phase and three-phase transformers (2 min)
- Transformer shipping and installation (9 min)
- Large Transformer Transportation (1 min)
- Transformer Equivalent Circuit (5 min)
- Why do we need an equivalent circuit (5 min)
- The Series Components (8 min)
- The Shunt Components (6 min)
- The Internal Ideal Transformer (4 min)
- Simplifying the Transformer Equivalent Circuit Part I (6 min)
- Simplifying the Transformer Equivalent Circuit Part II (4 min)
- Simplifying the Transformer Equivalent Circuit Part III (6 min)
- Vector Group Connections (15 min)
Chapter II: Transformer Faults
- Power Transformer Faults (3 min)
- Top 10 Transformer Blasts and Short Circuits (15 min)
- Power Transformer Explosion Incidents & Reasons & Precautionary Measures (4 min)
- Winding & Terminal Failures (4 min)
- The Effect of Through Faults on Power Transformers (4 min)
- Tap Changer (OLTC) Failure (3 min)
- Transformer bushings How it works (1 min)
- High Voltage bushing Faults early Detection and bushing monitoring (36 min)
- Why is Online Transformer Bushing Monitoring So Important (3 min)
- Transform Miscellaneous Failures (3 min)
- Why do we need Transformer Protection? (2 min)
- How do we Protect Transformers? (9 min)
- GE Transformer Protection& Control IED (2 min)
- SEL 787 & ABB RET 670 (14 min)
Chapter III: Transformer Protection Functions
- Differential Protection Part I (16 min)
- Transformer Differential Protection Part II (14 min)
- Differences between digital transformer differential relays (7 min)
- Simulate different cases and test the differential transformer protection function (9 min)
- Restricted Earth Fault Protection(REF) in Transformer (7 min)
- High Impedance Restricted Earth Fault Protection working principle (7 min)
- Stability Resistance and Metrosil Resistance in REF Protection (12 min)
- Low impedance REF (8 min)
- Buchholz relay (4 min)
- Transformer Buchholz Protection Relay principal (2 min)
- Inside the Buchholz relay (4 min)
- Buchholz relay by MR (5 min)
Chapter IV: Transformer Protection Relay IEDS
- ABB RET 670 Hardware structure (11 min)
- ABB RET 670 Transformer Protection Application template (6 min)
- ABB RET 670 Configuration and T2WPDIF Function block (12 min)
- ABB RET 670 Parameters and T2WPDIF parameters (11 min)
- Simulation of the differential protection algorithm in the ABB RET 670 relays (12 min)
SIEMENS 7UT85 configuration
How to enroll in this training course (How to access transformer protection training course):
1- Check out the Transformer Protection Training with the below link (https://elec-engg.com/product/transformer-protection-training/)
2- we will complete your order by sending your license to access the videos (https://elec-engg.com/how-to-access-our-training-courses/)
ِDemo is available
Transformer Protection Training
- Trainer: Dr. Saeed Roostaee (Profile)
Course details and samples on: https://elec-engg.com/transformer-protection-training-video/
- Trainer: Dr. Saeed Roostaee (Profil…
€80
Overview
The IEC 61850 source code library allows a fast and cost-efficient implementation of the IEC 61850 protocols (MMS, GOOSE, Sampled Values) into devices and applications. The APIs are designed to be very easy to use. The basic library is written in C (C99 compliant to provide maximum portability). Due to its hardware and platform-independent design, it can quickly deploy on any platform.
C#.NET Component
The C# library allows the creation of a managed DLL component that can easily be deployed in .NET applications. It is a wrapper of the C library. It can be used to be integrated into GUI applications, SCADA systems …
- Compatible with .NET and Mono
- Runs on Windows, Linux, and other platforms supported by .NET and Mono
- Very easy-to-use API
- Support for MMS client/server
- Support for GOOSE/SV subscribers
Features Source Code Library
- Easy to use IEC 61850 oriented API
- MMS, GOOSE, and Sampled Measured Values (SMV)
- TLS support
- Support editions 1, 2, and 2.1 of the standards
- Configurable generation of server data models from SCL/CID file at runtime
- Peer-reviewed and secure source code
- C library (C99) with C and C#/.NET API
Source codes that you see in this package:
- MMS client/server, GOOSE (IEC 61850-8-1)
- Sampled Values (SV – IEC 61850-9-2)
- Support for buffered and unbuffered reports
- Online report control block configuration
- Data access service (get data, set data)
- online data model discovery and browsing
- all data set services (get values, set values, browse)
- dynamic data set services (create and delete)
- log service
- flexible API to connect custom databases
- comes with sqlite implementation
- MMS file services (browse, get the file, set file, delete/rename the file)
- download COMTRADE files
- upload firmware or configuration files
- Setting group handling
- Service tracking (v1.5)
- GOOSE and SV control block handling
- TLS support
Application That can create with this library:
- Communications in Substations (MMS/GOOSE/SV)
- Communications for Wind Power Plants (IEC 61400-25)
- Communications for Decentralized Energy Resources (DER – IEC 61850-420)
- Intelligent Electronic Devices (IED)
- Measurement Devices
- SCADA Systems
- Monitoring
- Test systems
Easy programming and development of Scada and Monitoring System for protection Relays and other devices that compatible with IEC 61850 Standard with this package
- IEC 61850 Programming with C#
- Pre-recorded sessions: 4 hours
In this course, you will learn the principles of IEC 61850 programming and building monitoring and SCADA systems for networks that use IEC 61850 protection relays or IEDs (Intelligent Electronic Devices). To do so, first, you will learn about the IEC 61850 standard, including the concept of this standard, the simulation of the IEC 61850 GOOSE, and the IEC 61850 MMS reports. And how to read or write data and control commands to IEDs.
Next, you will learn Programming in IEC61850 Standard. In this chapter, you will learn how to use the IEC61850 Libraries for Programming in C# Language which are prepared by us and attached to the course as a gift. Then you will learn how to write a code for discovering and reading the substation IEDs, Functions, and Data Models. After that, you will learn how to write code to create DataSet and Report from the Data Models and set trigger options.
Course Content:
- Basics of IEC61850
- Sample Value
- GOOSE Protocol
- MMS Protocol
- Simulation of IEC 61850 Data Models
- Simulation of IEC 61850 DataSet
- Simulation of IEC 61850 GOOSE
- Simulation of IEC 61850 MMS
- Programming in IEC61850 Standard
- Necessary Libraries for Programming to C# Language in IEC61850 Standard
- Discovering Substation IEDs, Functions, and Data Models
- Read Data from Substation IEDs (Protection Relays,…)
- Create DataSet From Functions and Data Models and Read This DataSet
- Create a Report and Set Triggers
- Conclusion
Learn programming SCADA software based on IEC 61850 for your station as you like!
Supplementary Files:
- Source Code and Library for IEC 61850
- Visual Studio Code for Developers 2023
- C# Ultimate Guide – Beginner to Advanced
- FUNDAMENTALS OF COMPUTER PROGRAMMING WITH C#
- IEC 61850 Communication Networks and Systems In Substations: An Overview for Users
- Click here to download supplementary files
Source Code and Library for IEC 61850
The IEC 61850 source code library allows a fast and cost-efficient implementation of the IEC 61850 protocols (MMS, GOOSE, Sampled Values) into devices and applications. The APIs are designed to be very easy to use. The basic library is written in C (C99 compliant to provide maximum portability). Due to its hardware and platform-independent design, it can quickly deploy on any platform.
The C# library allows the creation of a managed DLL component that can easily be deployed in .NET applications. It is a wrapper of the C library. It can be used to be integrated into GUI applications, SCADA systems …
- Compatible with .NET and Mono
- Runs on Windows, Linux, and other platforms supported by .NET and Mono
- Very easy-to-use API
- Support for MMS client/server
- Support for GOOSE/SV subscribers
Features Source Code Library
- Easy to use IEC 61850 oriented API
- MMS, GOOSE, and Sampled Measured Values (SMV)
- TLS support
- Support editions 1, 2, and 2.1 of the standards
- Configurable generation of server data models from SCL/CID file at runtime
- Peer-reviewed and secure source code
- C library (C99) with C and C#/.NET API
Source codes that you see in this package:
- MMS client/server, GOOSE (IEC 61850-8-1)
- Sampled Values (SV – IEC 61850-9-2)
- Support for buffered and unbuffered reports
- Online report control block configuration
- Data access service (get data, set data)
- online data model discovery and browsing
- all data set services (get values, set values, browse)
- dynamic data set services (create and delete)
- log service
- flexible API to connect custom databases
- comes with sqlite implementation
- MMS file services (browse, get the file, set file, delete/rename the file)
- download COMTRADE files
- upload firmware or configuration files
- Setting group handling
- Service tracking (v1.5)
- GOOSE and SV control block handling
- TLS support
Application that can be created with this library:
- Communications in Substations (MMS/GOOSE/SV)
- Communications for Wind Power Plants (IEC 61400-25)
- Communications for Decentralized Energy Resources (DER – IEC 61850-420)
- Intelligent Electronic Devices (IED)
- Measurement Devices
- SCADA Systems
- Monitoring
- Test systems
Easy programming and development of Scada and Monitoring System for protection Relays and other devices that compatible with IEC 61850 Standard with this package
Keywords:
- IEC61850 Standard Communication Protocol Fundamentals
- IEC61850 Standard Standard Communication Protocols Simulation
- Programming for IEC61850 Standard Protocols
- Detect, Read, and Write values on IEDs (Relay Protections, Power Management, Meterings,…)
- IEC 61850 Programming
- IEC 61850 C# Programming in Visual Studio
- IEC 61850 SCADA Programming
- IEC 61850 MMS Programming
Reference Publication Type Title Value-added products Current Version
- IEC TS 61850-1-2: 2020 TS Part 1-2: Guideline on extending IEC61850 2020
- IEC TS 61850-1-2: 2020/AMD1:2022 TS Part 1-2: Guideline on extending IEC61850 Amendment 1 Consolidated Version 2022
- IEC TS 61850-2: 2019 TS Part 2: Glossary 2019
- IEC 61850-7-1: 2011/AMD 1: 2020 IS Part 7-1: Basic communication structure – Principles and models Amendment 1 Consolidated Version 2020
- IEC 61850-7-2: 2010/AMD 1:2020 IS Part 7-2: Basic information and communication structure – Abstract communication service interface(ASCI) Amendment 1 Consolidated Version 2020
- IEC 61850-7-3: 2010/AMD1:2020 IS Part 7-3: Basic communication structure – Common data classes Amendment 1 Consolidated Version 2020
- IEC 61850-7-4: 2010/ AMD 1: 2020 IS Part 7-4: Basic communication structure – Compatible logical node classes and data object classes Amendment 1 Consolidated Version 2020
- IEC TR 61850-7-5: 2021 TR Part 7-5: IEC 61850 modelling concepts 2021
- IEC TR 61850-7-6: 2019 TR Part 7-6: Guideline for definition of Basic Application Profiles (BAPs) using IEC61850 2019
- IEC TS 61850-7-7: 2018 TS Part 7-7: Machine processable format of IEC 61850-related data models for tools 2018
- IEC TS 61850-7-7: 2018/ AMD 1: 2023 TS Part 7-7: Machine processable format of IEC 61850-related data models for tools Amendment 1 Consolidated Version 2023
- IEC 61850-7-410: 2012 IS Part 7-410: Basic communication structure – Hydroelectric power plants – Communication for monitoring and control 2012
- IEC 61850-7-410: 2012/AMD 1: 2015 IS Part 7-410: Basic communication structure – Hydroelectric power plants – Communication for monitoring and control Amendment 1 Consolidated Version 2015
- IEC 61850-7-420: 2021 IS Part 7-420: Basic communication structure – Distributed energy resources and distribution automation logical nodes. 2021
- IEC TR 61850-7-500: 2017 TR Part 7-500: Basic information and communication structure – Use of logical nodes for modeling application functions and related concepts and guidelines for substations. 2017
- IEC TR 61850-7-510: 2021 TR Part 7-510: Basic communication structure – Hydroeletcric power plants, steam and gas turbines – Modelling concepts and guidelines. 2021
- IEC 61850-8-1: 2011/AMD1:2020 IS Part 8-1: Specific communication service mapping (SCSM) – Mappings to MMS (ISO 9506-1 and ISO 9506-2) and to ISO/IEC 8802-3 Amendment 1 Consolidated Version 2020
- IEC 61850-8-2:2018 IS Part 8-2: Specific communication service mapping (SCSM) – Mappings to extensive Messaging Presence Proptocol (XMPP). 2018
- IEC 61850-9-2: 2011/AMD1:2020 IS Part 9-2: Specific communication service mapping (SCSM) – Sampled values over ISO/IEC 8802-3 Amendment 1 Consolidated Version 2020
- IEC/IEEE 61850-9-3:2016 IS Part 9-3:Precision time protocol profile for power utility automation. 2016
- IEC 61850-10: 2012 IS Part 10: Conformance testing 2012
- IEC TR 61850-10-3:2022 TR Part 10-3: Functional testing of IEC 61850 systems. 2022
- IEC TS 61850-80-1:2016 TS Part 80-1: Guideline to exchanging information from a CDC-based data model; using IEC 60870-5-101 or IEC 60870-5-104 2016
- IEC TR 61850-80-3:2015 TR Part 80-3: Mapping to web protocols – Requirements and technical choices 2015
- IEC TS 61850-80-4:2016 TS Part 80-4: Translation from the COSEM object model (IEC 62056) TO the IEC 61850 data model 2016
- IEC TR 61850-90-1:2010 TR Part 90-1: Use of IEC 61850 for the communication between substations 2010
- IEC TR 61850-90-2:2016 TR Part 90-2: Using IEC 61850 for communication between substations and control centres 2016
- IEC TR 61850-90-3:2016 TR Part 90-3: Using IEC 61850 FOR condition monitoring diagnosis and analysis 2016
- IEC TR 61850-90-4:2020 TR Part 90-4: Network engineering guidelines 2020
- IEC TR 61850-90-5:2012 TR Part 90-4: Use of IEC 61850 to transmit synchrophasor information according to IEEE C37.118 2012
- IEC TR 61850-90-6:2018 TR Part 90-6: Use of IEC 61850 for Distribution Automation Systems 2018
- IEC TR 61850-90-7:2013 TR Part 90-7: Object models for power converters in dictributed energy resources (DER) systems. 2017
- IEC TR 61850-90-8:2016 TR Part 90-8: Object model for E-mobility 2016
- IEC TR 61850-90-9:2020 TR Part 90-9: Use of IEC 61850 for Electrical Energy Storage Systems 2020
- IEC TR 61850-90-10:2017 TR Part 90-10: Models for scheduling 2017
- IEC TR 61850-90-11:2020 TR Part 90-11: Methodologies for modelling of logics for IEC 61850 based applications 2020
- IEC TR 61850-90-12:2020 TR Part 90-12: Wide area network engineering guidelines 2020
- IEC TR 61850-90-13:2021 TR Part 90-13: Deterministic network technologies 2021
- IEC TR 61850-90-14:2021 TR Part 90-14: Using IEC 61850 FOR facts (flexible alternate current transmission systems), HVDC (high voltage direct current) transmission and power conversion data modelling 2021
- IEC TR 61850-90-16:2021 TR Part 90-16: Requirements of system management for Smart Energy Automation 2021
- IEC TR 61850-90-17:2017 TR Part 90-17: Using IEC 61850 to transmit power quality data. 2017
- Trainer: Dr. Saeed Roostaee (Profile)
- Face-to-face training
- Location & Fee: please contact us
- Duration: 10 days
Topics:
Substation Automation System:
- Substation Automation- Overview
- SAS Introduction
- SAS history
- SAS future
- Substation Automation Functions
- Process level
- Bay level
- Station Level
Network & Ethernet:
- Ethernet Concepts
- Fundamentals of Communication Via Ethernet
- Network Theory
- Components of the Network
- Fundamentals of Communication Via Ethernet Various Topologies
- Important Factors for Choosing a Topology
- Required Redundancy
- Distances Between Devices and Physical Dimensions of a Network
- Price Consideration
- Simple (Pure) Star
- Star Topology with Double Take
- Ring and Star Combination
- Economical Ring Solution With Only one External Switch
- Ring Topology With Two External Switches
- Commonly Used Configurations
- One Ring and Several Stars (most Frequently Occurring Topology)
- Two Rings Fitted into Each other
- Two Rings Connected Via a Double Main Ring
- Introduction: Provide an overview of SICAM PAS system
- Install SICAM PAS software and System components
- The new project, PAS Operation and Configure an IEC 103 interface
- How to use Device Descriptions (files)
- How to use the SICAM Value Viewer
- Configure an IEC 101 interface and T101 slave interfaces
- Configure an IEC 104 interface, T104 interface
- Introduction to IEC61850
- Creating a DIGIS database for a siprotec relay
- IEC61850 system configurator
- Data export and import
- Configure an IEC 61850 interface
- Normalization, Normalizing measured values
- Configure a PAS CC interface, Configuring an HMI interface
- Connect an IEC 61850 IED
IEC 61850:
- IEC 61850 Concepts
- An Introduction to IEC 61850
- IEC 61850 data structure and data format
- Information Modeling
- Interoperability
- Architecture: Station & Process Buses
- Logical Nodes
- ACSI – Class Models
- DataSet
- Communication models
- Controls
- GOOSE / GSSE
- Client / Server
- Data Reporting & Logging
- Sampled Values
- Time Synch
- GOOSE & Ethernet Frames
- 7-OSI Layers & Client / Server
- MMS Protocol
- ASN.1 Encoding & Message Parsing
- SCL Syntax and Semantics
- .ICD/.CID Files: IED definitions
- .SCD File: Substation Section
- Access Points & Communications
- EC 61850 station in DIGSI 5 and IEC 61850 System Configurator
- Time synchronization settings and SNTP configuration
- IEC 61850 configuration in DIGSI 4
- GOOSE configuration and the publisher/subscriber LNs
- GOOSE simulation via IEDScout
- Sample IEC61850 Configuration & Parameterization of a SIPROTEC 4 Device (BCU)
SIEMENS SAS
- Introduction to SICAM PAS Automation System
- Fields of Application
- Hardware Configuration
- Setting the Interface Parameters
- Setting for Time Synchronization
- Configuration of IEC 61850 Network
- Inter Bay Communication GOOSE
- Modbus Connection of Measuring Centers (EMA90)
- RS484 Bus Connection
- EMA90 Connection Setting
- Setting the Network Parameters for Ethernet Switches
- Configuration of General Parameters of Ethernet Switches
- Configuration of RSTP Bridge & RSTP Port Parameters
- Configuration of SNMP Users, Group, and Access
- 7XV6555 Serial/Ethernet Converter
- 7XV5655 Configuration Tool
- 7XV5655 Parameterization
- GPS Satellite Clock
- Server Type of Satellite Clock
- PCI Card type of Satellite Clock
- Station Level Engineering
- SICAM PAS Installation System Types
- Demo Version
- Licensed Version
- Installation Requirements
- SICAM PAS Configuration Working with Project Databases
- SICAM PAS UI-Operation
- SICAM PAS Value Viewer
- SICAM PASCC
- Introduction to SICAM PASCC Control Center
- Overview of SICAM PAS CC
- SICAM PASCC
- Starting The WinCC/PASCC Software
Practical Section
working with SIPROTEC 5 multifunction relay IED 7SX800
Information
- Course Name: SIPROTEC 5 and DIGSI 5 (advanced)
- Trainer: Dr. Saeed Roostaee
- Format: Pre-recorded videos (demo is available)
- Course creation: June 2023
- Last update: July 2023
Note: This course can also be held either Online or Face to face based on the request
Course Structure:
- Module 1: SIPROTEC 5 Hardware and ordering
- Module 2: Starting with DIGSI 5
- Module 3: Working with SIPROTEC 5 in online mode
- Module 4: System Functions
- Module 5: Function Groups
- Module 6: SIPROTEC 7SJ8
- Module 7: SIPROTEC 7SA8
- Module 8: SIPROTEC 7UT8
- Module 9: SIPROTEC 7SS8
- Module 10: SIPROTEC 7SK8
- Module 11: SIPROTEC 7VK8
- Module 12: SIPROTEC 7SD8
- Module 13: SIPROTEC 7SL8
- Module 14: SIPROTEC 7SX8
- Module 15: SIPROTEC 7UM8
- Module 16: SIPROTEC 7MD8
- Module 17: Functions and Settings
- Module 18: Signals and Masking IO
- Module 19: CFC
- Module 20: Control Functions
- Module 21: Display Page configuration
- Module 22: Functional Tests
- Module 23: Measured Values
- Module 24: Power Quality
- Module 25: Supervision
- Module 26: Communication
- Module 27: IEC 61850
- Module 28: Digital Twin
- Module 29: Case Study 7UT8
- Module 30: Case Study 7VK8
- Module 31: Case Study 7SA8
- Module 32: Case Study 7SS8
Course Details (Note: This part is continuously updating)
Module: SIPROTEC 5 Hardware and order
- SIPROTEC5 Hardware
- DIGSI 5 installation and DDD
- General Settings
- DIGSI 5 User interface
- New project + Add device (Offline)
- Modify the order code in the SIPROTEC online configurator
- SIPROTEC 5 Online Configurator
- Function Point
- SIP 5 Configuration Procedure
Module: Online & Working with SIPROTEC 5
- Connect to SIPROTEC 5
- Indications
- Fault Recording
- Log
- Reading Indications on the On-Site Operation Panel
- Reading Indications from the PC with DIGSI 5
- Displaying Indications
- Operational Log
- Fault Log
- Switching-Device Log
- Ground-Fault Log
- Setting-History Log
- User Log
- Security Log
- Device-Diagnosis Log
- Communication Log
- Communication-Supervision Log
- Motor-Starting Log
- Saving and Deleting the Logs
- Spontaneous Indication Display in DIGSI 5
- Spontaneous Fault Display on the On-Site Operation Panel
- Stored Indications in the SIPROTEC 5 Device
- Resetting Stored Indications of the Function Group
- Test Mode and Influence of Indications on Substation Automation Technology
- Changing the Transformation Ratios of the Transformer on the Device
Module: System Functions
- Sampling-Frequency Tracking and Frequency Tracking Groups
- Text Structure and Reference Number for Settings and Indications
- Processing Quality Attributes
- Protection Communication
- Date and Time Synchronization
- User-Defined Objects
- Device Settings
- Data Types
- Function Control
- Connection Examples
- Chatter blocking
- Settings-Group Switching
Module: Function Groups
- Voltage current 3-Phase
- Circuit-breaker
- Process Monitor
- Voltage-current 1-phase
- Motor
- Line
- Voltage 3-Phase
- Analog Units
- User-Defined Function Group
- Recording
- Motor Monitor
- Current-Flow Criterion
- Circuit-Breaker Condition for the Motor
- Closure Detection
- Motor-State Detection
- Cold-Load Pickup Detection
- Thermal Replica Rotor
- Capacitor Bank
Module: Functions and Settings
- Power-System Data
- Overcurrent Protection, Phases
- Overcurrent Protection, Ground
- Line Differential Protection
- Stub Differential Protection
- Restricted Ground-Fault Protection
- Distance Protection with Reactance Method (RMD)
- Distance Protection with Classic Method
- Impedance Protection
- Power-Swing Blocking
- Teleprotection with Distance Protection
- Universal Teleprotection with Distance Protection
- Ground-Fault Protection for High-Resistance Ground Faults in Grounded Systems
- Teleprotection with Ground-Fault Protection
- Universal Teleprotection with Ground-Fault Protection
- Echo and Tripping in the Event of Weak Infeed 874
- Tripping with Missing or Weak Infeed According to French Specification
- External Trip Initiation
- Automatic Reclosing Function
- Directional Overcurrent Protection, Phases
- Positive-Sequence Overcurrent Protection
- Instantaneous High-Current Tripping
- Group Indications of Overcurrent Protection Functions
- Overcurrent Protection, 1-Phase
- Voltage-Dependent Overcurrent Protection, Phases
- Sensitive Ground-Fault Detection
- Non-Directional Intermittent Ground-Fault Protection
- Directional Intermittent Ground-Fault Protection
- Negative-Sequence Protection
- Directional Negative-Sequence Protection with Current-Independent Time Delay
- Undercurrent Protection
- Overvoltage Protection with 3-Phase Voltage
- Overvoltage Protection with Positive-Sequence Voltage
- Overvoltage Protection with Negative-Sequence Voltage
- Overvoltage Protection with Positive-Sequence Voltage and Compounding
- Overvoltage Protection with Zero-Sequence Voltage/Residual Voltage
- Overvoltage Protection with Any Voltage
- Undervoltage Protection with 3-Phase Voltage
- Undervoltage Protection with Positive-Sequence Voltage
- Undervoltage Protection with Any Voltage
- Rate-of-Voltage-Change Protection
- Undervoltage-Controlled Reactive-Power Protection
- Voltage-Comparison Supervision
- Fault Locator
- Fault Locator Plus
- Over frequency Protection
- Under frequency Protection
- Rate of Frequency Change Protection
- Under frequency Load Shedding
- Phase-Sequence Switchover
- Instantaneous Tripping at Switch onto Fault
- Thermal Overload Protection, 3-Phase – Advanced
- Thermal Overload Protection, 1-Phase
- Temperature Supervision
- Circuit-Breaker Failure Protection
- Circuit-Breaker Restrike Protection
- Out-of-Step Protection
- Inrush-Current and 2nd Harmonic Detection
- Power Protection (P, Q), 3-Phase
- Current-Jump Detection
- Voltage-Jump Detection
- Vector-Jump Protection
- Arc Protection
- Voltage Measuring-Point Selection
Module: Specific Functions
- Current-Unbalance Protection for Capacitors, 1-Phase
- Peak Overvoltage Protection for Capacitors
- Motor-Starting Time Supervision
- Motor Restart Inhibit
- Load-Jam Protection Motor
- Thermal Overload Protection, Rotor
Module: Control Functions
- Introduction
- Switching Devices
- Switching Sequences
- Control Functionality
- Synchronization Function
- User-Defined Function Block [Control]
- CFC-Chart Settings
- Tap Changers
- Voltage Controller
- Point-on-Wave Switch
Module: Functional Tests
- Direction Test of the Phase Quantities
- Functional Test Protection Communication
- Functional Test of the Line Differential Protection
- Functional Test for Overvoltage Protection with Zero-Sequence Voltage/Displacement Voltage
- Primary and Secondary Tests of the Circuit-Breaker Failure Protection
- Circuit-Breaker Test
- Out-of-Step Protection Function Test
- Functional Test of the Inrush-Current Detection
- Functional Test of the Trip-Circuit Supervision
- Power-Swing Blocking Functional Test
- Functional Test for the Phase-Rotation Reversal
- Functional Test for Overvoltage Protection with Zero-Sequence Voltage/Residual Voltage
- Directional Testing for Isolated or Resonant-Grounded Systems
- Primary and Secondary Testing of the Synchronization Function
- Commissioning Hints for Voltage Control
Module: Measured Values
- Operational Measured Values
- Fundamental and Symmetrical Components
- THD and Harmonics
- Minimum/Maximum Values
- Average Values
- Energy Values
- Circuit-Breaker Monitoring
- Statistical Values of the Primary System
Module: Power Quality
- Voltage Variation
- Voltage Unbalance
- THD and Harmonics
- Total Demand Distortion
Module: Supervision
- Resource-Consumption Supervision
- Supervision of the Secondary System
- Supervision of the Device Hardware
- Supervision of Device Firmware
- Supervision of Hardware Configuration
- Supervision of Communication Connections
- Error Responses and Corrective Measures
- Group Indications
Module: IEC 61850
- External Signals
- Quality Processing/Affected by the User for Received GOOSE Values
- Quality Processing/Affected by the User in CFC Charts
- Quality Processing/Affected by the User in Internal Device Functions
More info and update about this course: Contac us
To participate in this face-to-face / online training course: contact us
- Course Name: Power System Protection based on SIEMENS and ABB relays
- Trainer: Dr. Saeed Roostaee
- Location: Turkey
- Duration: one week
- Course define: 14 July 2023
- Last update: 22 July 2023
- Course start: 5 November 2023
- Certificate: On successful completion of this training course, Elec-Engg Certificate will be awarded to the delegates
Day 1: Power system protection & Numerical Relay IEDs
- Why power system protection
- Numerical relay history
- Numerical structure
- Numerical relay functionality
- symmetrical component
- ANSI Codes
- Current and Voltage Transformer Types, Specifications, and Applications
- Protection Zones
- Time-current Characteristics Curves
- Modern Software for Protection
Day 2: SIPROTEC & DIGSI
- SIPROTEC 5 Hardware and ordering
- Connect to SIPROTEC 5
- Working with SIPROTEC 5 in online mode
- Indications and logs
- Recorder
- Relay configuration
- Functions and Settings
Day 3: ABB Relion & PCM 600
- ABB relays history
- PCM and connectivity pack installation
- Add IEDs
- Hardware configuration
- Application configuration
- Distance relay config
- Busbar relay config
Day 4: Feeder & Line Protection
- Overcurrent
- IDMT O/C & E/F Protection
- Definite Time (DT) Protection
- High-set Instantaneous Protection
- Earth fault
- Directional OC
- Distance
Day 5: Busbar and Circuit Breakers
- Circuit breaker failure protection (CBF)
- busbar arrangement
- busbar differential protection function
- Protection Zone
- REB670 series hardware structure
- REB670 Configuration
Day 6: Generator & Transformer Protection
- Transformer Introduction
- Vector Group Connections
- Transformer Faults
- Transformer Differential Protection
- Restricted Earth Fault Protection(REF)
- Buchholz Relay and Pressure Relief Operations
- ABB RET 670 Hardware structure
- ABB RET 670 Transformer Protection Application Template
- ABB RET 670 Configuration and Function blocks
- Generator construction
- Generator differential protection
- Generator stator earth fault protection
- Generator Under excitation / Loss-of -Excitation (ANSI 40 ) protection
- Generator Out-of-Step Protection (Pole Slip)
- Generator negative sequence protection
- Loss of Prime Mover protection
- Generator Over-Under frequency
- Generator under-voltage protection
- REG670 configuration
Sample DIGSI 5 logs
Library Global DIGSI 5 Library was opened
Project SaeedRoostaee_digsi5training opened
Analyzed compatibility information
6MU85 configuration requires 0 function points
Starting import of function chart(s) (CFC) from file C:\User
Importing log messages for function chart (CFC) Group warning,
Importing log messages for function chart (CFC) Process mode inactive,
Successfully finished importing
Analyzed software part.,7/27/2023,10:08:10 AM
Line Mode has no settings, so it is not listed under Settings. It is displayed in the Single-line configuration, Communication mapping, and Information routing.,7/27/2023,10:08:16 AM
DIGSI has no settings, so it is not listed under Settings. It is displayed in the Single-line configuration, Communication mapping, and Information routing.,7/27/2023,10:08:17 AM
Web UI has no settings, so it is not listed under Settings. It is displayed in the Single-line configuration, Communication mapping, and Information routing.
Analyzed compatibility information.,7/27/2023,10:09:11 AM
6MU85 configuration requires 0 function points.,7/27/2023,10:09:11 AM
6MU85 configuration requires 0 function points.,7/27/2023,10:09:11 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\3vawjx0o.yc3.tmp into device 6MU85.,7/27/2023,10:09:24 AM
Importing log messages for function chart (CFC) Group warning,7/27/2023,10:09:24 AM
Importing log messages for function chart (CFC) Process mode inactive,7/27/2023,10:09:24 AM
Successfully finished importing.,7/27/2023,10:09:24 AM
Analyzed software part.,7/27/2023,10:09:25 AM
Due to a change in hardware, 1 routing was deleted.,7/27/2023,10:09:28 AM
Line Mode has no settings, so it is not listed under Settings. It is displayed in the Single-line configuration, Communication mapping, and Information routing.,7/27/2023,10:09:32 AM
DIGSI has no settings, so it is not listed under Settings. It is displayed in the Single-line configuration, Communication mapping and Information routing.,7/27/2023,10:09:32 AM
Web UI has no settings, so it is not listed under Settings. It is displayed in the Single-line configuration, Communication mapping and Information routing.,7/27/2023,10:09:33 AM
Analyzed compatibility information.,7/27/2023,10:10:07 AM
6MU85 configuration requires 0 function points.
6MU85 configuration requires 0 function points.,7/27/2023,10:10:07 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\u2zboyex.sai.tmp into device 6MU85.,7/27/2023,10:10:21 AM
Importing log messages for function chart (CFC) Group warning,7/27/2023,10:10:21 AM
Importing log messages for function chart (CFC) Process mode inactive,7/27/2023,10:10:21 AM
Successfully finished importing.,7/27/2023,10:10:22 AM
6MU85 configuration requires 20 function points.,7/27/2023,10:10:22 AM
Analyzed software part.,7/27/2023,10:10:22 AM
Due to change in hardware, 1 routings were deleted.,7/27/2023,10:10:25 AM
Line Mode has no settings, so it is not listed under Settings. It is displayed in the Single-line configuration, Communication mapping and Information routing.,7/27/2023,10:10:29 AM
DIGSI has no settings, so it is not listed under Settings. It is displayed in the Single-line configuration, Communication mapping and Information routing.,7/27/2023,10:10:30 AM
Web UI has no settings, so it is not listed under Settings. It is displayed in the Single-line configuration, Communication mapping and Information routing.,7/27/2023,10:10:30 AM
Analyzed compatibility information.,7/27/2023,10:11:01 AM
6MU85 configuration requires 0 function points.,7/27/2023,10:11:01 AM
6MU85 configuration requires 0 function points.,7/27/2023,10:11:01 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\i5dxb3f4.p3z.tmp into device 6MU85.,7/27/2023,10:11:11 AM
Importing log messages for function chart (CFC) Group warning,7/27/2023,10:11:11 AM
Importing log messages for function chart (CFC) Process mode inactive,7/27/2023,10:11:11 AM
Successfully finished importing.,7/27/2023,10:11:11 AM
Analyzed software part.,7/27/2023,10:11:12 AM
Line Mode has no settings, so it is not listed under Settings. It is displayed in the Single-line configuration, Communication mapping and Information routing.,7/27/2023,10:11:17 AM
DIGSI has no settings, so it is not listed under Settings. It is displayed in the Single-line configuration, Communication mapping and Information routing.,7/27/2023,10:11:18 AM
Web UI has no settings, so it is not listed under Settings. It is displayed in the Single-line configuration, Communication mapping and Information routing.,7/27/2023,10:11:18 AM
Analyzed compatibility information.,7/27/2023,10:11:50 AM
6MU85 configuration requires 0 function points.,7/27/2023,10:11:50 AM
6MU85 configuration requires 0 function points.,7/27/2023,10:11:50 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\kd145sd3.5vv.tmp into device 6MU85.
Importing log messages for function chart (CFC) Group warning
Importing log messages for function chart (CFC) Process mode inactive,
Successfully finished importing.,7/27/2023,10:11:57 AM
Analyzed software part.
Line Mode has no settings, so it is not listed under Settings. It is displayed in the Single-line configuration, Communication mapping and Information routing.,7/27/2023,10:12:01 AM
DIGSI has no settings, so it is not listed under Settings. It is displayed in the Single-line configuration, Communication mapping and Information routing.,7/27/2023,10:12:02 AM
Web UI has no settings, so it is not listed under Settings. It is displayed in the Single-line configuration, Communication mapping and Information routing.,7/27/2023,10:12:02 AM
Function-chart (CFC) compilation,7/27/2023,10:13:01 AM
The project SaeedRoostaee_digsi5training was saved successfully.,7/27/2023,10:15:57 AM
Analyzed compatibility information.,7/27/2023,10:16:38 AM
7UM85 configuration requires 0 function points.,7/27/2023,10:16:38 AM
7UM85 configuration requires 0 function points.,7/27/2023,10:16:38 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\4fklxd5f.hx1.tmp into device 7UM85.,7/27/2023,10:16:59 AM
Analyzed software part.,7/27/2023,10:17:01 AM
Analyzed compatibility information.,7/27/2023,10:18:41 AM
7UM85 configuration requires 0 function points.,7/27/2023,10:18:41 AM
7UM85 configuration requires 0 function points.,7/27/2023,10:18:41 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\q1grapr5.1rp.tmp into device 7UM85.,7/27/2023,10:19:05 AM
Importing log messages for function chart (CFC) Group warning,7/27/2023,10:19:05 AM
Importing log messages for function chart (CFC) Process mode inactive,7/27/2023,10:19:05 AM
Successfully finished importing.,7/27/2023,10:19:05 AM
7UM85 configuration requires 85 function points.,7/27/2023,10:19:06 AM
Analyzed software part.,7/27/2023,10:19:06 AM
Analyzed compatibility information.,7/27/2023,10:20:28 AM
7UM85 configuration requires 0 function points.,7/27/2023,10:20:28 AM
7UM85 configuration requires 0 function points.,7/27/2023,10:20:28 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\1e0gnksz.mfz.tmp into device 7UM85.,7/27/2023,10:20:55 AM
Importing log messages for function chart (CFC) Group warning,7/27/2023,10:20:55 AM
Importing log messages for function chart (CFC) Process mode inactive,7/27/2023,10:20:55 AM
Successfully finished importing.,7/27/2023,10:20:55 AM
7UM85 configuration requires 105 function points.,7/27/2023,10:20:56 AM
Analyzed software part.,7/27/2023,10:20:56 AM
Analyzed compatibility information.,7/27/2023,10:21:48 AM
7UM85 configuration requires 0 function points.,7/27/2023,10:21:48 AM
7UM85 configuration requires 0 function points.,7/27/2023,10:21:48 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\yzrziyf1.5ct.tmp into device 7UM85.,7/27/2023,10:22:26 AM
Importing log messages for function chart (CFC) Group warning,7/27/2023,10:22:26 AM
Importing log messages for function chart (CFC) Process mode inactive,7/27/2023,10:22:26 AM
Successfully finished importing.,7/27/2023,10:22:26 AM
7UM85 configuration requires 330 function points.,7/27/2023,10:22:27 AM
Analyzed software part.,7/27/2023,10:22:29 AM
Analyzed compatibility information.,7/27/2023,10:23:24 AM
7UM85 configuration requires 0 function points.,7/27/2023,10:23:24 AM
7UM85 configuration requires 0 function points.,7/27/2023,10:23:24 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\g5ojtdjt.axj.tmp into device 7UM85.,7/27/2023,10:23:53 AM
Importing log messages for function chart (CFC) Group warning,7/27/2023,10:23:53 AM
Importing log messages for function chart (CFC) Process mode inactive,7/27/2023,10:23:54 AM
Successfully finished importing.,7/27/2023,10:23:54 AM
7UM85 configuration requires 255 function points.,7/27/2023,10:23:55 AM
Analyzed software part.,7/27/2023,10:23:55 AM
The project SaeedRoostaee_digsi5training was saved successfully.,7/27/2023,10:25:01 AM
Analyzed compatibility information.,7/27/2023,10:26:38 AM
7VU85 configuration requires 0 function points.,7/27/2023,10:26:38 AM
7VU85 configuration requires 0 function points.,7/27/2023,10:26:38 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\htzmdc0f.3i1.tmp into device 7VU85.,7/27/2023,10:26:56 AM
Importing log messages for function chart (CFC) Group warning,7/27/2023,10:26:56 AM
Importing log messages for function chart (CFC) Process mode inactive,7/27/2023,10:26:56 AM
Successfully finished importing.,7/27/2023,10:26:57 AM
Analyzed software part.,7/27/2023,10:26:57 AM
Analyzed compatibility information.,7/27/2023,10:27:59 AM
7VU85 configuration requires 0 function points.,7/27/2023,10:27:59 AM
7VU85 configuration requires 0 function points.,7/27/2023,10:27:59 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\djy2bv1q.rly.tmp into device 7VU85.,7/27/2023,10:28:29 AM
Importing log messages for function chart (CFC) Group warning,7/27/2023,10:28:29 AM
Importing log messages for function chart (CFC) Process mode inactive,7/27/2023,10:28:30 AM
Successfully finished importing.,7/27/2023,10:28:30 AM
7VU85 configuration requires 470 function points.,7/27/2023,10:28:31 AM
Analyzed software part.,7/27/2023,10:28:32 AM
Analyzed compatibility information.,7/27/2023,10:29:16 AM
7VU85 configuration requires 0 function points.,7/27/2023,10:29:16 AM
7VU85 configuration requires 0 function points.,7/27/2023,10:29:16 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\drdplp2d.gqq.tmp into device 7VU85.,7/27/2023,10:29:44 AM
Importing log messages for function chart (CFC) Group warning,7/27/2023,10:29:44 AM
Importing log messages for function chart (CFC) Process mode inactive,7/27/2023,10:29:45 AM
Successfully finished importing.,7/27/2023,10:29:45 AM
7VU85 configuration requires 400 function points.,7/27/2023,10:29:45 AM
Analyzed software part.,7/27/2023,10:29:46 AM
The project SaeedRoostaee_digsi5training was saved successfully.,7/27/2023,10:30:09 AM
The project SaeedRoostaee_digsi5training was saved successfully.,7/27/2023,10:30:47 AM
Analyzed compatibility information.,7/27/2023,10:32:33 AM
7VE85 configuration requires 0 function points.,7/27/2023,10:32:33 AM
7VE85 configuration requires 0 function points.,7/27/2023,10:32:33 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\4ynlrvko.squ.tmp into device 7VE85.,7/27/2023,10:32:46 AM
Importing log messages for function chart (CFC) Group warning,7/27/2023,10:32:46 AM
Importing log messages for function chart (CFC) Process mode inactive,7/27/2023,10:32:46 AM
Successfully finished importing.,7/27/2023,10:32:46 AM
Analyzed software part.,7/27/2023,10:32:47 AM
Analyzed compatibility information.,7/27/2023,10:33:33 AM
7VE85 configuration requires 0 function points.,7/27/2023,10:33:33 AM
7VE85 configuration requires 0 function points.,7/27/2023,10:33:33 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\h4jl3ijd.fox.tmp into device 7VE85.,7/27/2023,10:33:53 AM
Importing log messages for function chart (CFC) Group warning,7/27/2023,10:33:53 AM
Importing log messages for function chart (CFC) Process mode inactive,7/27/2023,10:33:54 AM
Successfully finished importing.,7/27/2023,10:33:54 AM
7VE85 configuration requires 75 function points.,7/27/2023,10:33:54 AM
Analyzed software part.,7/27/2023,10:33:55 AM
Analyzed compatibility information.,7/27/2023,10:34:28 AM
7VE85 configuration requires 0 function points.,7/27/2023,10:34:28 AM
7VE85 configuration requires 0 function points.,7/27/2023,10:34:28 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\rlvnzip1.5zo.tmp into device 7VE85.,7/27/2023,10:34:44 AM
Importing log messages for function chart (CFC) Group warning,7/27/2023,10:34:44 AM
Importing log messages for function chart (CFC) Process mode inactive,7/27/2023,10:34:45 AM
Successfully finished importing.,7/27/2023,10:34:45 AM
7VE85 configuration requires 115 function points.,7/27/2023,10:34:46 AM
Analyzed software part.,7/27/2023,10:34:47 AM
Analyzed compatibility information.,7/27/2023,10:35:58 AM
7VE85 configuration requires 0 function points.,7/27/2023,10:35:58 AM
7VE85 configuration requires 0 function points.,7/27/2023,10:35:58 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\d1etzmsn.mav.tmp into device 7VE85.,7/27/2023,10:36:15 AM
Importing log messages for function chart (CFC) Group warning,7/27/2023,10:36:15 AM
Importing log messages for function chart (CFC) Process mode inactive,7/27/2023,10:36:15 AM
Successfully finished importing.,7/27/2023,10:36:15 AM
7VE85 configuration requires 115 function points.,7/27/2023,10:36:16 AM
Analyzed software part.,7/27/2023,10:36:17 AM
Analyzed compatibility information.,7/27/2023,10:37:18 AM
7VE85 configuration requires 0 function points.,7/27/2023,10:37:18 AM
7VE85 configuration requires 0 function points.,7/27/2023,10:37:18 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\hysu15dy.clo.tmp into device 7VE85.,7/27/2023,10:37:41 AM
Importing log messages for function chart (CFC) Group warning,7/27/2023,10:37:41 AM
Importing log messages for function chart (CFC) Process mode inactive,7/27/2023,10:37:41 AM
Importing log messages for function chart (CFC) VoltageSelection,7/27/2023,10:37:41 AM
Successfully finished importing.,7/27/2023,10:37:42 AM
7VE85 configuration requires 115 function points.,7/27/2023,10:37:42 AM
Analyzed software part.,7/27/2023,10:37:42 AM
Analyzed compatibility information.,7/27/2023,10:38:47 AM
7VE85 configuration requires 0 function points.,7/27/2023,10:38:47 AM
7VE85 configuration requires 0 function points.,7/27/2023,10:38:47 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\c0jkcjzm.ff4.tmp into device 7VE85.,7/27/2023,10:39:13 AM
Importing log messages for function chart (CFC) Group warning,7/27/2023,10:39:13 AM
Importing log messages for function chart (CFC) Process mode inactive,7/27/2023,10:39:14 AM
Successfully finished importing.,7/27/2023,10:39:14 AM
7VE85 configuration requires 230 function points.,7/27/2023,10:39:14 AM
Analyzed software part.,7/27/2023,10:39:15 AM
Due to change in hardware, 15 routings were deleted.,7/27/2023,10:39:21 AM
The project SaeedRoostaee_digsi5training was saved successfully.,7/27/2023,10:40:17 AM
Analyzed compatibility information.,7/27/2023,10:42:05 AM
7SX85 configuration requires 0 function points.,7/27/2023,10:42:05 AM
7SX85 configuration requires 0 function points.,7/27/2023,10:42:05 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\rwtxsokr.dq5.tmp into device 7SX85.,7/27/2023,10:42:24 AM
7SX85 configuration requires 74 function points.,7/27/2023,10:42:25 AM
Analyzed software part.,7/27/2023,10:42:26 AM
Analyzed compatibility information.,7/27/2023,10:43:04 AM
7SX85 configuration requires 0 function points.,7/27/2023,10:43:04 AM
7SX85 configuration requires 0 function points.,7/27/2023,10:43:04 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\bhr4svo1.p0w.tmp into device 7SX85.,7/27/2023,10:43:27 AM
7SX85 configuration requires 126 function points.,7/27/2023,10:43:27 AM
Analyzed software part.,7/27/2023,10:43:28 AM
The project SaeedRoostaee_digsi5training was saved successfully.,7/27/2023,10:44:17 AM
Analyzed compatibility information.,7/27/2023,11:00:39 AM
6MD86 configuration requires 0 function points.,7/27/2023,11:00:39 AM
6MD86 configuration requires 0 function points.,7/27/2023,11:00:40 AM
Analyzed software part.,7/27/2023,11:00:46 AM
Analyzed compatibility information.,7/27/2023,11:01:09 AM
6MD86_1 configuration requires 0 function points.,7/27/2023,11:01:09 AM
6MD86_1 configuration requires 0 function points.,7/27/2023,11:01:09 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\oua4evsi.ttf.tmp into device 6MD86_1.,7/27/2023,11:01:28 AM
Analyzed software part.,7/27/2023,11:01:30 AM
Analyzed compatibility information.,7/27/2023,11:02:29 AM
6MD86 configuration requires 0 function points.,7/27/2023,11:02:29 AM
6MD86 configuration requires 0 function points.,7/27/2023,11:02:29 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\erexcpgi.y4l.tmp into device 6MD86.,7/27/2023,11:03:15 AM
Analyzed software part.,7/27/2023,11:03:20 AM
Due to change in hardware, 29 routings were deleted.,7/27/2023,11:03:32 AM
Analyzed compatibility information.,7/27/2023,11:04:08 AM
6MD86 configuration requires 0 function points.,7/27/2023,11:04:08 AM
6MD86 configuration requires 0 function points.,7/27/2023,11:04:08 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\vowhsuzk.axy.tmp into device 6MD86.,7/27/2023,11:04:48 AM
6MD86 configuration requires 60 function points.,7/27/2023,11:04:50 AM
Analyzed software part.,7/27/2023,11:04:51 AM
Due to change in hardware, 23 routings were deleted.,7/27/2023,11:05:00 AM
Analyzed compatibility information.,7/27/2023,11:06:19 AM
6MD86 configuration requires 0 function points.,7/27/2023,11:06:19 AM
6MD86 configuration requires 0 function points.,7/27/2023,11:06:19 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\wojcjuzy.cux.tmp into device 6MD86.,7/27/2023,11:06:36 AM
Importing log messages for function chart (CFC) GRPWARN_POW,7/27/2023,11:06:36 AM
Importing log messages for function chart (CFC) PROCESS_MODE_INACTIVE,7/27/2023,11:06:36 AM
Successfully finished importing.,7/27/2023,11:06:36 AM
6MD86 configuration requires 200 function points.,7/27/2023,11:06:37 AM
Analyzed software part.,7/27/2023,11:06:37 AM
Analyzed compatibility information.,7/27/2023,11:25:01 AM
7UT87 configuration requires 0 function points.,7/27/2023,11:25:01 AM
7UT87 configuration requires 0 function points.,7/27/2023,11:25:01 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\fk53a1ei.qb0.tmp into device 7UT87.,7/27/2023,11:25:20 AM
Importing log messages for function chart (CFC) Group warning,7/27/2023,11:25:20 AM
Importing log messages for function chart (CFC) Process mode inactive,7/27/2023,11:25:21 AM
Successfully finished importing.,7/27/2023,11:25:21 AM
Analyzed software part.,7/27/2023,11:25:22 AM
Analyzed compatibility information.,7/27/2023,11:26:30 AM
7UT87 configuration requires 0 function points.,7/27/2023,11:26:30 AM
7UT87 configuration requires 0 function points.,7/27/2023,11:26:30 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\4h5nmjbt.upq.tmp into device 7UT87.,7/27/2023,11:26:54 AM
Importing log messages for function chart (CFC) Group warning,7/27/2023,11:26:54 AM
Importing log messages for function chart (CFC) Process mode inactive,7/27/2023,11:26:54 AM
Successfully finished importing.,7/27/2023,11:26:55 AM
7UT87 configuration requires 25 function points.,7/27/2023,11:26:55 AM
Analyzed software part.,7/27/2023,11:26:56 AM
Analyzed compatibility information.,7/27/2023,11:28:30 AM
7UT87 configuration requires 0 function points.,7/27/2023,11:28:30 AM
7UT87 configuration requires 0 function points.,7/27/2023,11:28:30 AM
Starting import of function chart(s) (CFC) from file
SIPROTEC 5 and DIGSI 5 training by Dr. Saeed Roostaee
C:\Users\LENOVO\AppData\Local\Temp\zf1oyw44.fey.tmp into device 7UT87.,7/27/2023,11:28:58 AM
Importing log messages for function chart (CFC) Group warning,7/27/2023,11:28:58 AM
Importing log messages for function chart (CFC) Process mode inactive,7/27/2023,11:28:58 AM
Successfully finished importing.,7/27/2023,11:28:59 AM
7UT87 configuration requires 30 function points.,7/27/2023,11:28:59 AM
Analyzed software part.,7/27/2023,11:29:00 AM
Analyzed compatibility information.,7/27/2023,11:29:41 AM
7UT87 configuration requires 0 function points.,7/27/2023,11:29:42 AM
7UT87 configuration requires 0 function points.,7/27/2023,11:29:42 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\kocertsc.mb2.tmp into device 7UT87.,7/27/2023,11:30:10 AM
Importing log messages for function chart (CFC) Group warning,7/27/2023,11:30:10 AM
Importing log messages for function chart (CFC) Process mode inactive,7/27/2023,11:30:11 AM
Successfully finished importing.,7/27/2023,11:30:11 AM
7UT87 configuration requires 170 function points.,7/27/2023,11:30:11 AM
Analyzed software part.,7/27/2023,11:30:12 AM
Analyzed compatibility information.,7/27/2023,11:30:46 AM
7UT87 configuration requires 0 function points.,7/27/2023,11:30:46 AM
7UT87 configuration requires 0 function points.,7/27/2023,11:30:46 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\g1vz3iv4.n3x.tmp into device 7UT87.,7/27/2023,11:31:13 AM
Importing log messages for function chart (CFC) Group warning,7/27/2023,11:31:13 AM
Importing log messages for function chart (CFC) Process mode inactive,7/27/2023,11:31:13 AM
Successfully finished importing.,7/27/2023,11:31:13 AM
7UT87 configuration requires 50 function points.,7/27/2023,11:31:14 AM
Analyzed software part.,7/27/2023,11:31:14 AM
Analyzed compatibility information.,7/27/2023,11:31:47 AM
7UT87 configuration requires 0 function points.,7/27/2023,11:31:47 AM
7UT87 configuration requires 0 function points.,7/27/2023,11:31:47 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\mueys0vx.wkm.tmp into device 7UT87.,7/27/2023,11:32:14 AM
Importing log messages for function chart (CFC) Group warning,7/27/2023,11:32:14 AM
Importing log messages for function chart (CFC) Process mode inactive,7/27/2023,11:32:15 AM
Successfully finished importing.,7/27/2023,11:32:16 AM
Analyzed software part.,7/27/2023,11:32:17 AM
Analyzed compatibility information.,7/27/2023,11:33:01 AM
7UT87 configuration requires 0 function points.,7/27/2023,11:33:01 AM
7UT87 configuration requires 0 function points.,7/27/2023,11:33:01 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\o2l40wo1.1qd.tmp into device 7UT87.,7/27/2023,11:33:39 AM
Importing log messages for function chart (CFC) Group warning,7/27/2023,11:33:39 AM
Importing log messages for function chart (CFC) Process mode inactive,7/27/2023,11:33:40 AM
Successfully finished importing.,7/27/2023,11:33:40 AM
7UT87 configuration requires 45 function points.,7/27/2023,11:33:40 AM
Analyzed software part.,7/27/2023,11:33:41 AM
Analyzed compatibility information.,7/27/2023,11:34:32 AM
7UT87 configuration requires 0 function points.,7/27/2023,11:34:32 AM
7UT87 configuration requires 0 function points.,7/27/2023,11:34:32 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\bx5kvvoj.idx.tmp into device 7UT87.,7/27/2023,11:35:16 AM
Importing log messages for function chart (CFC) Group warning,7/27/2023,11:35:16 AM
Importing log messages for function chart (CFC) Process mode inactive,7/27/2023,11:35:16 AM
Importing log messages for function chart (CFC) DIS_Z4_trip_all_CB,7/27/2023,11:35:16 AM
Successfully finished importing.,7/27/2023,11:35:16 AM
7UT87 configuration requires 150 function points.,7/27/2023,11:35:17 AM
Analyzed software part.,7/27/2023,11:35:19 AM
Analyzed compatibility information.,7/27/2023,11:39:39 AM
7UT87 configuration requires 0 function points.,7/27/2023,11:39:39 AM
7UT87 configuration requires 0 function points.,7/27/2023,11:39:39 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\nwlj1jve.e4e.tmp into device 7UT87.,7/27/2023,11:40:12 AM
Importing log messages for function chart (CFC) Group warning,7/27/2023,11:40:12 AM
Importing log messages for function chart (CFC) Process mode inactive,7/27/2023,11:40:13 AM
Successfully finished importing.,7/27/2023,11:40:13 AM
7UT87 configuration requires 30 function points.,7/27/2023,11:40:13 AM
Analyzed software part.,7/27/2023,11:40:14 AM
Analyzed compatibility information.,7/27/2023,11:41:13 AM
7UT87 configuration requires 0 function points.,7/27/2023,11:41:13 AM
7UT87 configuration requires 0 function points.,7/27/2023,11:41:13 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\s20dfpoq.2kd.tmp into device 7UT87.,7/27/2023,11:41:59 AM
Importing log messages for function chart (CFC) Group warning,7/27/2023,11:41:59 AM
Importing log messages for function chart (CFC) Process mode inactive,7/27/2023,11:42:00 AM
Successfully finished importing.,7/27/2023,11:42:00 AM
7UT87 configuration requires 30 function points.,7/27/2023,11:42:01 AM
Analyzed software part.,7/27/2023,11:42:02 AM
Assignment of offline configuration 7UT87_3_2W 1.5 to another offline configuration 7UT87_1_2W basic is not possible. Assign always online devices to offline configurations.,7/27/2023,11:43:08 AM
The project SaeedRoostaee_digsi5training was saved successfully.,7/27/2023,11:43:56 AM
Analyzed compatibility information.,7/27/2023,11:45:51 AM
7SS85 configuration requires 0 function points.,7/27/2023,11:45:51 AM
7SS85 configuration requires 0 function points.,7/27/2023,11:45:51 AM
Starting import of function chart(s) (CFC) from file
C:\Users\LENOVO\AppData\Local\Temp\1lwlt0co.g3s.tmp into device 7SS85.,7/27/2023,11:46:01 AM
Importing log messages for function chart (CFC) Group warning,7/27/2023,11:46:01 AM
Importing log messages for function chart (CFC) Process mode inactive,7/27/2023,11:46:01 AM
Successfully finished importing.,7/27/2023,11:46:01 AM
Analyzed software part.,7/27/2023,11:46:01 AM
Analyzed compatibility information.,7/27/2023,11:46:52 AM
7VK87 configuration requires 0 function points.,7/27/2023,11:46:52 AM
7VK87 configuration requires 0 function points.,7/27/2023,11:46:52 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\gpn2w0ns.wbw.tmp into device 7VK87.,7/27/2023,11:47:13 AM
Importing log messages for function chart (CFC) Group warning,7/27/2023,11:47:13 AM
Importing log messages for function chart (CFC) Process mode inactive,7/27/2023,11:47:14 AM
Successfully finished importing.,7/27/2023,11:47:14 AM
Analyzed software part.,7/27/2023,11:47:15 AM
Analyzed compatibility information.,7/27/2023,11:48:11 AM
7SL87 configuration requires 0 function points.,7/27/2023,11:48:11 AM
7SL87 configuration requires 0 function points.,7/27/2023,11:48:11 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\by51qi0y.yx1.tmp into device 7SL87.,7/27/2023,11:48:32 AM
Importing log messages for function chart (CFC) Group warning,7/27/2023,11:48:32 AM
Importing log messages for function chart (CFC) Process mode inactive,7/27/2023,11:48:33 AM
Successfully finished importing.,7/27/2023,11:48:33 AM
Analyzed software part.,7/27/2023,11:48:34 AM
Analyzed compatibility information.,7/27/2023,11:49:10 AM
7SL87 configuration requires 0 function points.,7/27/2023,11:49:10 AM
7SL87 configuration requires 0 function points.,7/27/2023,11:49:10 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\ojyjebnh.0lh.tmp into device 7SL87.,7/27/2023,11:49:41 AM
Importing log messages for function chart (CFC) Group warning,7/27/2023,11:49:41 AM
Importing log messages for function chart (CFC) Process mode inactive,7/27/2023,11:49:42 AM
Successfully finished importing.,7/27/2023,11:49:42 AM
7SL87 configuration requires 225 function points.,7/27/2023,11:49:43 AM
Analyzed software part.,7/27/2023,11:49:44 AM
Analyzed compatibility information.,7/27/2023,11:50:19 AM
7SL87 configuration requires 0 function points.,7/27/2023,11:50:19 AM
7SL87 configuration requires 0 function points.,7/27/2023,11:50:20 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\znrrm0rx.ugj.tmp into device 7SL87.,7/27/2023,11:50:59 AM
Importing log messages for function chart (CFC) DISCON_7SL87_7SD87,7/27/2023,11:50:59 AM
Importing log messages for function chart (CFC) Group warning,7/27/2023,11:50:59 AM
Importing log messages for function chart (CFC) Process mode inactive,7/27/2023,11:51:00 AM
Importing log messages for function chart (CFC) RECL_7SX87_1,7/27/2023,11:51:00 AM
Importing log messages for function chart (CFC) RECL_7SX87_2,7/27/2023,11:51:00 AM
Successfully finished importing.,7/27/2023,11:51:01 AM
7SL87 configuration requires 400 function points.,7/27/2023,11:51:01 AM
Analyzed software part.,7/27/2023,11:51:03 AM
The project SaeedRoostaee_digsi5training was saved successfully.,7/27/2023,11:51:57 AM
Analyzed compatibility information.,7/27/2023,11:52:29 AM
7SD87 configuration requires 0 function points.,7/27/2023,11:52:29 AM
7SD87 configuration requires 0 function points.,7/27/2023,11:52:29 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\u2lbfpnj.14x.tmp into device 7SD87.,7/27/2023,11:52:49 AM
Importing log messages for function chart (CFC) Group warning,7/27/2023,11:52:49 AM
Importing log messages for function chart (CFC) Process mode inactive,7/27/2023,11:52:50 AM
Successfully finished importing.,7/27/2023,11:52:50 AM
Analyzed software part.,7/27/2023,11:52:51 AM
Analyzed compatibility information.,7/27/2023,11:53:34 AM
7SD87 configuration requires 0 function points.,7/27/2023,11:53:34 AM
7SD87 configuration requires 0 function points.,7/27/2023,11:53:34 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\ti4eq0z4.04y.tmp into device 7SD87.,7/27/2023,11:53:58 AM
Importing log messages for function chart (CFC) Group warning,7/27/2023,11:53:58 AM
Importing log messages for function chart (CFC) Process mode inactive,7/27/2023,11:53:59 AM
Successfully finished importing.,7/27/2023,11:53:59 AM
7SD87 configuration requires 170 function points.,7/27/2023,11:53:59 AM
Analyzed software part.,7/27/2023,11:54:00 AM
Analyzed compatibility information.,7/27/2023,11:54:43 AM
7SD87 configuration requires 0 function points.,7/27/2023,11:54:43 AM
7SD87 configuration requires 0 function points.,7/27/2023,11:54:43 AM
Starting import of function chart(s) (CFC) from file C:\Users\LENOVO\AppData\Local\Temp\qytlw5aa.tuf.tmp into device 7SD87.,7/27/2023,11:55:18 AM
Importing log messages for function chart (CFC) DISCON_7SL87_7SD87,7/27/2023,11:55:18 AM
Importing log messages for function chart (CFC) Group warning,7/27/2023,11:55:19 AM
Importing log messages for function chart (CFC) Process mode inactive,7/27/2023,11:55:20 AM
Importing log messages for function chart (CFC) RECL_7SX87_1,7/27/2023,11:55:20 AM
Importing log messages for function chart (CFC) RECL_7SX87_2,7/27/2023,11:55:20 AM
Successfully finished importing.,7/27/2023,11:55:21 AM
7SD87 configuration requires 345 function points.
Analyzed software part.,
The project SaeedRoostaee_digsi5training was saved successfully.
- Trainer: Dr. Saeed Roostaee (Profile)
- Online
- Date: 19 and 20 August 2023
- Platform: Google Meet & Online player
- Last update: 6 August 2023
- Contact us
Course content:
- Basics of Synchronous and Asynchronous Motors
- Motor Nameplate
- Motor Connections
- Motor Faults, Faults, and Protection Functions
- Overview of the Motor Protection Functions
- Motor Overcurrent Protection
- Motor Earth fault protection
- Motor Overload protection
- Motor Voltage protection
- Negative Sequence Protection
- Motor Lock Rotor & Mechanical Jam protection
- Motor Undercurrent protection
Modern numerical motor relay protection technology must be sufficient to meet the protection requirements of any of the vast range of motor designs. A motor protection relay providing sufficient protection will have the following set of characteristics such as extended start relay protection, loss-of-load relay protection, number of starts limitation, stalling relay protection, short circuit relay protection, thermal relay protection, Earth fault relay protection, negative sequence current detection, winding RTD measurement/trip, under-voltage relay protection, auxiliary supply supervision, …
- 14 Speed Switch
- 27 Undervoltage*
- 37 (P,C) Underpower/Undercurrent
- 38 Bearing Temperature*
- 46 Current Unbalance
- 47 Phase Reversal
- 49P PTC Overtemperature*
- 49R RTD Thermal*
- 49T Thermal Model
- 50 (P,G,Q) Overcurrent (Phase, Ground, Neg. Seq.)
- 50P LR Locked Rotor
- 50P LJ Load Jam
- 50N Neutral Overcurrent
- 51 (P,G,Q) Time-Overcurrent (Phase, Residual, Neg. Seq.)
- 55 Power Factor*
- 59P Phase Overvoltage*
- 60 Loss-of-Potential*
- 66 Starts-Per-Hour
- 81 (O,U) Over-/Underfrequency
- 87 Current Differential*
- 90 (P,I,T) Load Control (Power, Current, Thermal Capacity)
- 50/51 Adaptive Overcurrent
- 85 RIO SEL Mirrored Bits® Communications
- DFR Event Reports—Motor Starts, Motor Operating
- Statistics
- ENV Optional SEL-2600 RTD Module*
- HMI Operator Interface
- LDP Load Data Profiling
- LGC SELogic® Control Equations
- MET Metering
- RTU Remote Terminal Unit
- SDTM Slip-Dependent AccuTrackTM Thermal Model
- SER Sequential Events Recorders
- Stator overload protection 49
- Starting time supervision, locked rotor protection 48
- Restart inhibit 66,49R
- Negative-sequence current protection I2> 46
- Thermal unbalanced-load protection I2 2(t) 46
- Temperature measurement 1 38
- Undercurrent protection 37
- Active-power protection (P<) 32U
- Sensitive ground-fault protection 59N,
- non-directional 51Ns
- directional 67Ns
- Overcurrent protection 50, 51
- Current-differential protection 87
- Undervoltage protection 27
- Overvoltage protection 59
- Underexcitation protection 40
- Rotor ground-fault protection 64R
- Frequency protection 81
- Circuit-breaker failure protection 50BF
- User-programmable logic (CFC)
- Control functionality
- Graphic display (large)
- Flexible interfaces
- Frequency operating range (10 Hz – 70 Hz)
- Operational measured values and
- functional measured values
- Three-phase non-directional overcurrent protection, low-stage PHLPTOC 3I> 51P-1
- Three-phase non-directional overcurrent protection, instantaneous stage PHIPTOC 3I>>> 50P/51P
- Non-directional earth-fault protection, low-stage EFLPTOC I0> 51N-1
- Non-directional earth-fault protection, high stage EFHPTOC I0>> 51N-2
- Non-directional earth-fault protection, instantaneous stage EFIPTOC I0>>> 50N/51N
- Directional earth-fault protection, low stage DEFLPDEF I0> -> 67N-1
- Directional earth-fault protection, high stage DEFHPDEF I0>> -> 67N-2
- Rotor earth-fault protection MREFPTOC Io>R 64R
- Negative-sequence overcurrent protection for machines MNSPTOC I2>G/M 46G/46M
- Phase-reversal protection PREVPTOC I2>> 46R
- Three-phase thermal overload protection for motors MPTTR 3Ith>M 49M
- Motor startup supervision STTPMSU Is2t n< 48,66,14,51LR Motor load jam protection JAMPTOC Ist> 51LR
- Emergency start ESMGAPC ESTART ESTART
- Loss of load supervision LOFLPTUC 3I< 37 High-impedance or flux-balance based differential protection for machines MHZPDIF 3dIHi>G/M 87GH/87MH
- Stabilized differential protection for machines MPDIF 3dI>G/M 87G/87M
- Three-phase overvoltage protection PHPTOV 3U> 59
- Three-phase undervoltage protection PHPTUV 3U< 27 Positive-sequence overvoltage protection PSPTOV U1> 47O+
- Positive-sequence Undervoltage protection PSPTUV U1< 47U+ Negative-sequence overvoltage protection NSPTOV U2> 47OResidual
- overvoltage protection ROVPTOV U0> 59G
- Reverse power/directional overpower protection DOPPDPR P> 32R/32O
- Frequency gradient protection DAPFRC df/dt> 81R
- Over frequency protection DAPTOF f> 81O
- Under frequency protection DAPTUF f< 81U Three-phase underexcitation protection UEXPDIS X< 40 Circuit breaker failure protection CCBRBRF 3I>/I0>BF 51BF/51NBF
- Tripping logic TRPPTRC I -> O 94
- Multipurpose analog protection MAPGAPC MAP MAP
- Bay control QCCBAY CBAY CBAY
- Interlocking interface SCILO 3 3
- Circuit breaker/disconnector control GNRLCSWI I <-> O CB/DC I <-> O CB/DC
- Circuit breaker DAXCBR I <-> O CB I <-> O CB
- Disconnector DAXSWI I <-> O DC I <-> O DC
- Local/remote switch interface LOCREM R/L R/L
- Single point control (8 signals) SPC8GGIO
- Double point indication DPGGIO
- Single point indication SPGGIO
- Generic measured value MVGGIO
- Logic Rotating Switch for function selection and LHMI presentation SLGGIO
- Selector mini switch VSGGIO
- Pulse counter for energy metering PCGGIO
- Event counter CNTGGIO
- Supervision and monitoring
- Runtime counter for machines and devices MDSOPT OPTS OPTM
- Circuit breaker condition monitoring SSCBR CBCM CBCM
- Fuse failure supervision SEQRFUF FUSEF 60
- Current circuit supervision CCRDIF MCS 3I MCS 3I
- Trip-circuit supervision TCSSCBR TCS TCM
- Station battery supervision SPVNZBAT U<> U<>
- Energy monitoring EPDMMTR E E
- Measured value limit supervision MVEXP
- Three-phase current measurement CMMXU 3I 3I
- Three-phase voltage measurement (phase-to-earth)
- VPHMMXU 3Upe 3Upe
- Three-phase voltage measurement (phase-to-phase) VPPMMXU 3Upp 3Upp
- Residual current measurement RESCMMXU I0 I0
- Residual voltage measurement RESVMMXU U0 U0
- Power monitoring with P, Q, S, power factor, frequency PWRMMXU PQf PQf
- Sequence current measurement CSMSQI I1, I2 I1, I2
- Sequence voltage measurement VSMSQI U1, U2 V1, V2
- Current Protection: Phase Overcurrent (67, 51, 50)
- Directional Control of Overcurrent Protection (67)
- Overcurrent Protection (50)
- Current Protection: Undercurrent (37)
- Phase Unbalance (46)
- Time Delayed Overcurrent Protection (51)
- Current Protection: Measured Earth Fault (50/51G)
- Directional Control of Measured Earth Fault Protection (67G)
- Measured Earth Fault Protection (50G)
- Time Delayed Measured Earth Fault Protection (51G)
- Current Protection: Derived Earth Fault (50/51N)
- Directional Control of Derived Earth Fault Protection (67N)
- Time Delayed Derived Earth Fault Protection (51N)
- High Impedance Restricted Earth Fault (87REF)
- Voltage Protection: NPS Overvoltage (47)
- Earth Fault Protection (50N)
- Voltage Protection: Under/Over Frequency (81)
- Power Protection – 32
- Sensitive Power Protection – 32S
- Break Capacity Limit (50BCL)
- Phase Reversal (46 PH REV)
- Temperature Monitoring
- CT Supervision (60CTS)
- Power Factor – 55
- Trip Circuit Supervision (74TCS)
- Close Circuit Supervision (74CCS)
- Circuit Breaker Failure (50BF)
- Local human-machine interface
- 4 IED menu
- 4.2 Operation status ………………………………………………………………………………………………… 9
- 4.3 Query reports ………………………………………………………………………………………………….. 10
- 4.4 Set time …………………………………………………………………………………………………………… 10
- 4.5 Contrast …………………………………………………………………………………………………………… 10
- 4.6 Settings …………………………………………………………………………………………………………… 11
- 4.7 IED setting ………………………………………………………………………………………………………. 11
- 4.8 Test binary output ……………………………………………………………………………………………. 12
- 4.9 Testing operation …………………………………………………………………………………………….. 12
- 3.1.2 Terminals of Analogue Input Module (AIM) ……………………………………………….. 17
- 3.1.3 Terminals of Binary Input Module (BIM) ……………………………………………………. 18
- 3.1.4 Terminals of Binary Output Module (BOM) ……………………………………………….. 19
- 3.1.5 Terminals of Communication module (COM) ……………………………………………. 23
- 3.1.6 Communication ports of CPU module (CPU) ……………………………………………. 24
- 3.1.7 Terminals of Power Supply Module (PSM) ……………………………………………….. 25
- 3.1.8 RS232 port ……………………………………………………………………………………………….. 26
- 3.2 Connecting to Protective Earth…………………………………………………………………………. 26
- 3.3 Connecting the power supply module ……………………………………………………………… 26
- 3.4 Connecting to CT and VT circuits ……………………………………………………………………. 26
- 3.5 Connecting the binary inputs and outputs………………………………………………………… 26
- 3.6 Making the screen connection …………………………………………………………………………. 28
- 3.7 Optical connections …………………………………………………………………………………………. 28
- 3.8 RS485 and RS232 ports connection ……………………………………………………………….. 29
- 3.8.1 RS485 port connection …………………………………………………………………………….. 29
- 3.8.2 RS232 port connection …………………………………………………………………………….. 29
- 3.9 Connecting the GPS………………………………………………………………………………………… 30
- 4 Checking before energizing …………………………………………………………………………………………… 31
- Checking the power supply connection …………………………………………………………… 31
- 4.4 Checking the CT and VT circuits connection …………………………………………………… 31
- 4.4.1 Checking the CT circuits connection ………………………………………………………… 31
- 4.4.2 Checking the VT connection …………………………………………………………………….. 32
- 4.5 Checking the binary input and output connection ……………………………………………. 32
- 4.5.1 Checking the binary input connection ………………………………………………………. 32
- 4.5.2 Checking the binary output connection …………………………………………………….. 33
- 4.6 Checking the screened cables connection ………………………………………………………. 33
- 4.7 Checking the optical connections ……………………………………………………………………. 33
- 4.8 Checking the S485 and RS232 port connections ………………………………………………. 33
- 4.8.1 Checking the RS485 port connection ……………………………………………………….. 33
- 4.8.2 Checking RS232 port connection …………………………………………………………….. 33
- 4.9 Checking GPS connection ………………………………………………………………………………. 33
- 4.10 Checking the insulation voltage and insulation resistance ………………………………. 33
- 4.10.1 Checking the insulation voltage ……………………………………………………………….. 34
- 4.10.2 Checking the Insulation Resistance…………………………………………………………… 34
- 5 Checking after energizing ……………………………………………………………………………………………… 35
- 5.2 Test LCD …………………………………………………………………………………………………………. 35
- 5.3 Test the keyboard ……………………………………………………………………………………………. 35
- 5.4 Setting the IED time ………………………………………………………………………………………… 35
- 5.5 Self-supervision HMI data ……………………………………………………………………………….. 36
- 5.6 Checking the software and hardware version ………………………………………………….. 36
- Chapter 4 Read and change setting ………………………………………………………………………………… 37
- 1 Read and change the setting value ……………………………………………………………………………….. 38
- 1.1 Read and change the setting value via LHMI ………………………………………………….. 38
- 1.1.1 Introduction ………………………………………………………………………………………………. 38
- 1.1.2 Communication parameter ……………………………………………………………………….. 38
- 1.1.3 Equipment parameter ………………………………………………………………………………. 39
- 1.1.4 Setting values and binary settings for protection function …………………………. 39
- 2 Switching the setting group ……………………………………………………………………………………………. 46
- 2.1 Introduction ……………………………………………………………………………………………………… 46
- 2.2 Method for switching setting group via LHMI …………………………………………………… 46
- 2.3 Method for switching setting group via binary input …………………………………………. 46
- Chapter 5 Testing the communication connection and time synchronization ……………………. 47
- 1 Testing the communication connection ………………………………………………………………………….. 48
- 1.1 Testing the Ethernet communication ……………………………………………………………….. 48
- 1.1.1 Testing the electrical Ethernet communication …………………………………………. 48
- 1.1.2 Testing the optical Ethernet communication ……………………………………………… 48
- 1.2 Testing the RS485 port……………………………………………………………………………………. 48
- 1.3 Testing the RS232 port……………………………………………………………………………………. 48
- 2 Testing the time synchronization ……………………………………………………………………………………. 50
- 2.1 Network mode …………………………………………………………………………………………………. 50
- 2.2 Pulse mode ……………………………………………………………………………………………………… 50
- 2.3 IRIG-B mode ……………………………………………………………………………………………………. 50
- Chapter 6 IED testing ………………………………………………………………………………………………………. 51
- 1 Introduction ……………………………………………………………………………………………………………………. 52
- 2 Points for attention during testing…………………………………………………………………………………… 54
- 3 Preparing for test …………………………………………………………………………………………………………… 56
- 3.1 Introduction ……………………………………………………………………………………………………… 56
- 3.2 Connecting test equipment to IED …………………………………………………………………… 56
- 4 Testing the power supply ……………………………………………………………………………………………….. 58
- 4.1 Checking the self-startup performance ……………………………………………………………. 58
- 4.2 DC power on and power off testing………………………………………………………………….. 58
- 4.3 Checking the expiry date of power supply ……………………………………………………….. 58
- 5 Checking the analog channel ………………………………………………………………………………………… 59
- 5.1 Checking the zero drift …………………………………………………………………………………….. 59
- 5.2 Calibrating ……………………………………………………………………………………………………….. 59
- 5.3 Checking the accuracy and the linearity of analog quantitis …………………………….. 60
- 5.4 Checking the polarity of analog quantities ……………………………………………………….. 60
- 6 Testing binary input ……………………………………………………………………………………………………….. 62
- 7 Testing binary output ……………………………………………………………………………………………………… 63
- 8 Verifying the IED functions …………………………………………………………………………………………….. 64
- 8.1 Instantaneous differential protection ………………………………………………………………… 64
- 8.1.1 Verifying the settings ………………………………………………………………………………… 64
- 8.1.2 Completing the test ………………………………………………………………………………… 66
- 8.1.3 Reference setting list for test ……………………………………………………………………. 66
- 8.2 Percentage differential protection ……………………………………………………………………. 66
- 8.2.1 Verifying the settings ………………………………………………………………………………… 66
- 8.2.2 Completing the test ………………………………………………………………………………… 76
- 8.2.3 Reference setting list for test ……………………………………………………………………. 77
- 8.3 Restricted earth fault protection……………………………………………………………………….. 79
- 8.3.1 Verifying the settings ………………………………………………………………………………… 79
- 8.3.2 Completing the test ………………………………………………………………………………… 81
- 8.3.3 Reference setting list for test ……………………………………………………………………. 81
- 8.4 Overexcitation protection …………………………………………………………………………………. 83
- 8.4.1 Verifying the settings ………………………………………………………………………………… 83
- 8.4.2 Completing the test ………………………………………………………………………………… 88
- 8.4.3 Reference setting list for test ……………………………………………………………………. 88
- 8.5 Overcurrent protection …………………………………………………………………………………….. 90
- 8.5.1 Verifying the settings ………………………………………………………………………………… 90
- 8.5.2 Completing the test …………………………………………………………………………………… 97
- 8.5.3 Reference setting list for test ……………………………………………………………………. 97
- 8.6 Earth fault protection ……………………………………………………………………………………… 103
- 8.6.1 Verifying the settings ………………………………………………………………………………. 103
- 8.6.2 Completing the test …………………………………………………………………………………. 109
- 8.6.3 Reference setting list for test ………………………………………………………………….. 110
- 8.7 Neutral earth fault protection …………………………………………………………………………. 115
- 8.7.1 Verifying the settings ………………………………………………………………………………. 115
- 8.7.2 Completing the test ………………………………………………………………………………… 121
- 8.7.3 Reference setting list for test ………………………………………………………………….. 122
- 8.8 Thermal overload protection ………………………………………………………………………….. 127
- 8.8.1 Verifying the settings ………………………………………………………………………………. 127
- 8.8.2 Completing the test ………………………………………………………………………………… 137
- 8.8.3 Reference setting list for test ………………………………………………………………….. 137
- 8.9 Overload protection ……………………………………………………………………………………….. 138
- 8.9.1 Verifying the settings ………………………………………………………………………………. 138
- 8.9.2 Completing the test ………………………………………………………………………………… 142
- 8.9.3 Reference setting list for test ………………………………………………………………….. 142
- 8.10 Overvoltage protection ………………………………………………………………………………….. 144
- 8.10.1 Verifying the settings ………………………………………………………………………………. 144
- 8.10.2 Completing the test ………………………………………………………………………………… 150
- 8.10.3 Reference setting list for test ………………………………………………………………….. 150
- 8.11 Circuit breaker failure protection ……………………………………………………………………. 151
- 8.11.1 Verifying the settings ………………………………………………………………………………. 152
- 8.11.2 Completing the test ………………………………………………………………………………… 156
- 8.11.3 Reference setting list for test ………………………………………………………………….. 156
- 8.12 Dead zone protection …………………………………………………………………………………….. 158
- 8.12.1 Verifying the settings ………………………………………………………………………………. 158
- 8.12.2 Completing the test ………………………………………………………………………………… 161
- 8.12.3 Reference setting list for test ………………………………………………………………….. 161
- 8.13 STUB protection ……………………………………………………………………………………………. 161
- 8.13.1 Verifying the settings ………………………………………………………………………………. 162
- 8.13.2 Completing the test ………………………………………………………………………………… 164
- 8.13.3 Reference setting list for test ………………………………………………………………….. 164
- 8.14 Poles discordance protection ………………………………………………………………………… 164
- 8.14.1 Verifying the settings ………………………………………………………………………………. 165
- 8.14.2 Completing the test ………………………………………………………………………………… 169
- 8.14.3 Reference setting list for test ………………………………………………………………….. 169
- 8.15 Voltage transformer secondary circuit supervision ………………………………………… 170
- 8.15.1 Verifying the settings ………………………………………………………………………………. 170
- 8.15.2 Completing the test ………………………………………………………………………………… 181
- 8.15.3 Reference setting list for test ………………………………………………………………….. 181
- 9 Checking before operation …………………………………………………………………………………………… 183
- 9.1 Checking the LED …………………………………………………………………………………………. 183
- 9.2 Checking the display on LCD ………………………………………………………………………… 183
- 9.3 Checking the clock ………………………………………………………………………………………… 183
- 9.4 Checking the voltage and current ………………………………………………………………….. 183
- 9.5 Checking the setting group ……………………………………………………………………………. 183
- 9.6 Checking the setting ……………………………………………………………………………………… 183
- 9.7 Checking the binary input ………………………………………………………………………………. 184
- 9.8 Checking the normal operation mode …………………………………………………………….. 184
- 9.8.1 Trip and close test with the circuit breaker ………………………………………………. 184
- 9.9 Put into operation …………………………………………………………………………………………… 184
- Chapter 7 Operating maintenance …………………………………………………………………………………. 186
- 1 Attentions during operating ………………………………………………………………………………………….. 187
- 2 Routine checking …………………………………………………………………………………………………………. 189
- 3 Periodical checking ……………………………………………………………………………………………………… 190
- 4 Operation after updating software or replacing modules ………………………………………………. 191
- 4.1 Operation after updating software or replacing CPU module …………………………. 191
- 4.2 Operation after updating software or replacing communication module …………. 191
- 4.3 Operation after replacing the binary input or output module …………………………… 192
- 4.4 Operation after replacing the analog input module ………………………………………… 192
- 4.5 Operation after replacing power supply module …………………………………………….. 192
- 5 The alarm information and measure …………………………………………………………………………….. 193
- 5.1 Alarm information and the measure ……………………………………………………………….. 193
- Chapter 8 Transportation and storage ……………………………………………………………………………. 196
- 1 Transportion…………………………………………………………………………………………………………………. 197
- 2 Storage ………………………………………………………………………………………………………………………… 198
- Chapter 9 Appendix ……………………………………………………………………………………………………….. 200
- 1 Arrangement diagram of modules ………………………………………………………………………………… 201
- 2 Typical diagram ……………………………………………………………………………………………………………. 202
- Chapter 2 Basic protection elements ………………………………………………………………….. 9
- 1 Startup element ……………………………………………………………………………………………10
- 1.1 Introduction ……………………………………………………………………………………..10
- 1.2 Sudden-change current startup element ………………………………………………10
- 1.3 Differential current startup element ……………………………………………………..10
- 2 Input and output signals ……………………………………………………………………………….. 11
- 3 Settings ………………………………………………………………………………………………………13
- 4 Report ………………………………………………………………………………………………………..16
- Chapter 3 Differential protection ………………………………………………………………………..17
- 1 Introduction …………………………………………………………………………………………………18
- 2 Applications…………………………………………………………………………………………………18
- 3 Protection algorithm ……………………………………………………………………………………..19
- 3.1 Differential and restraint current calculation ………………………………………….20
- 3.2 Automatic Ratio compensation …………………………………………………………..22
- 3.3 Automatic Vector group and zero sequence current compensation …………..26
- 4 Protection principle……………………………………………………………………………………….32
- 4.1 Instantaneous differential protection characteristic …………………………………32
- 4.2 Treble slope percent differential protection characteristic ………………………..34
- 4.3 Selective inrush stabilization schemes …………………………………………………37
- 4.3.1 2nd harmonic stabilization …………………………………………………………………38
- 4.3.2 Fuzzy recognition of inrush based on the waveform ………………………………38
- 4.4 Overexcitation stabilization ………………………………………………………………..40
- 4.5 CT Failure supervision ………………………………………………………………………42
- 4.6 CT Saturation supervision ………………………………………………………………….43
- 4.7 Differential current supervision……………………………………………………………44
- 5 Input and output signals ………………………………………………………………………………..46
- 6 Settings ………………………………………………………………………………………………………47
- 7 Report ………………………………………………………………………………………………………..50
- 8 Technical data ……………………………………………………………………………………………..51
- Chapter 4 Restricted earth fault protection ………………………………………………………….53
- 1 Introduction …………………………………………………………………………………………………54
- 2 Applications…………………………………………………………………………………………………54
- 3 Protection principle……………………………………………………………………………………….56
- 3.1 Differential and restraint current calculation ………………………………………….57
- 3.2 Automatic Ratio compensation …………………………………………………………..59
- 3.3 Positive sequence current blocking ……………………………………………………..61
- 3.4 Restricted earth fault current alarm ……………………………………………………..62
- 4 Input and output signals ………………………………………………………………………………..63
- 5 Settings ………………………………………………………………………………………………………64
- 6 Report ………………………………………………………………………………………………………. 66
- 7 Technical data …………………………………………………………………………………………….. 67
- Chapter 5 Overexcitation protection ………………………………………………………………….. 69
- 1 Introduction ………………………………………………………………………………………………… 70
- 2 Protection principle ……………………………………………………………………………………… 70
- 2.1 Protection principle ………………………………………………………………………….. 70
- 2.2 Voltage channel configuration …………………………………………………………… 76
- 3 Input and output signals ……………………………………………………………………………….. 77
- 4 Settings …………………………………………………………………………………………………….. 78
- 5 Report ………………………………………………………………………………………………………. 79
- 6 Technical data …………………………………………………………………………………………….. 80
- Chapter 6 Overcurrent protection……………………………………………………………………… 83
- 1 Introduction ………………………………………………………………………………………………… 84
- 2 Protection principle ……………………………………………………………………………………… 84
- 2.1 Protection Elements ………………………………………………………………………… 84
- 2.2 Inrush Restraint Feature …………………………………………………………………… 86
- 2.3 Direction Determination Feature ………………………………………………………… 87
- 2.4 CBF initiation Feature ……………………………………………………………………… 90
- 3 Input and output signals ……………………………………………………………………………….. 91
- 4 Setting ………………………………………………………………………………………………………. 92
- 5 Report ………………………………………………………………………………………………………. 99
- 6 Technical data …………………………………………………………………………………………….. 99
- Chapter 7 Earth fault protection ……………………………………………………………………… 101
- 1 Protection principle ……………………………………………………………………………………. 102
- 1.1 Protection elements ………………………………………………………………………. 102
- 1.2 Inrush Restraint Feature …………………………………………………………………. 104
- 1.3 Direction Determination Feature ………………………………………………………. 105
- 1.4 CBF initiation Feature ……………………………………………………………………. 107
- 2 Input and output signals ……………………………………………………………………………… 108
- 3 Setting …………………………………………………………………………………………………….. 109
- 4 Report …………………………………………………………………………………………………….. 115
- 5 Technical data …………………………………………………………………………………………… 116
- Chapter 8 Neutral earth fault protection …………………………………………………………… 119
- 1 Protection principle ……………………………………………………………………………………. 120
- 1.1 Protection Elements ………………………………………………………………………. 120
- 1.2 Inrush Restraint Feature …………………………………………………………………. 122
- 1.3 Direction Determination Feature ………………………………………………………. 122
- 1.4 CBF initiation Feature ……………………………………………………………………. 124
- 2 Input and output signals ……………………………………………………………………………… 125
- 3 Setting …………………………………………………………………………………………………….. 126
- 4 Report …………………………………………………………………………………………………….. 132
- 5 Technical data …………………………………………………………………………………………… 133
- Chapter 9 Thermal overload protection ……………………………………………………………. 135
- 1 Introduction ………………………………………………………………………………………………. 136
- 2 Protection principle…………………………………………………………………………………….. 136
- 3 Input and output signals ……………………………………………………………………………… 138
- 4 Setting ……………………………………………………………………………………………………… 138
- 5 Report ……………………………………………………………………………………………………… 140
- 6 Technical data …………………………………………………………………………………………… 141
- Chapter 10 Overload protection ……………………………………………………………………….. 143
- 1 Protection principle…………………………………………………………………………………….. 144
- 2 Input and output signals ……………………………………………………………………………… 145
- 3 Setting ……………………………………………………………………………………………………… 146
- 4 Report ……………………………………………………………………………………………………… 148
- Chapter 11 Overvoltage protection ……………………………………………………………………. 149
- 5 Introduction ………………………………………………………………………………………………. 150
- 6 Protection principle…………………………………………………………………………………….. 150
- 6.1 Phase to phase overvoltage protection ……………………………………………… 150
- 6.2 Phase to earth overvlotage protection……………………………………………….. 151
- 7 Logic diagram …………………………………………………………………………………………… 151
- 8 Input and output signals ……………………………………………………………………………… 151
- 9 Setting ……………………………………………………………………………………………………… 152
- 10 Report ……………………………………………………………………………………………….. 154
- 11 Technical data …………………………………………………………………………………….. 154
- Chapter 12 Circuit breaker failure protection ………………………………………………………. 157
- 1 Introduction ………………………………………………………………………………………………. 158
- 2 Protection principle…………………………………………………………………………………….. 158
- 3 Logic diagram …………………………………………………………………………………………… 161
- 4 Input and output signals ……………………………………………………………………………… 163
- 5 Setting ……………………………………………………………………………………………………… 164
- 6 Report ……………………………………………………………………………………………………… 167
- 7 Technical data …………………………………………………………………………………………… 167
- Chapter 13 Dead zone protection ……………………………………………………………………… 169
- 1 Introduction ………………………………………………………………………………………………. 170
- 2 Protection principle…………………………………………………………………………………….. 170
- 2.1 Function description……………………………………………………………………….. 171
- 3 Logic diagram …………………………………………………………………………………………… 171
- 4 Input and output signals ……………………………………………………………………………… 172
- 5 Setting ……………………………………………………………………………………………………… 173
- 6 Report ……………………………………………………………………………………………………… 174
- 7 Technical data …………………………………………………………………………………………… 174
- Chapter 14 STUB protection ……………………………………………………………………………. 175
- 1 Introduction ………………………………………………………………………………………………. 176
- 2 Protection principle…………………………………………………………………………………….. 176
- 2.1 Function description……………………………………………………………………….. 176
- 3 Logic diagram …………………………………………………………………………………………… 177
- 4 Input and output signals ……………………………………………………………………………… 177
- 5 Setting ……………………………………………………………………………………………………… 178
- 6 Report …………………………………………………………………………………………………….. 180
- 7 Technical data …………………………………………………………………………………………… 181
- Chapter 15 Poles discordance protection ………………………………………………………….. 183
- 1 Introdcution ………………………………………………………………………………………………. 184
- 2 Protection principle ……………………………………………………………………………………. 184
- 2.1 Function description ………………………………………………………………………. 184
- 3 Logic diagram …………………………………………………………………………………………… 185
- 4 Input and output signals ……………………………………………………………………………… 186
- 5 Setting …………………………………………………………………………………………………….. 187
- 6 Report …………………………………………………………………………………………………….. 188
- 7 Technical data …………………………………………………………………………………………… 188
- Chapter 16 Secondary system supervision ………………………………………………………… 189
- 1 VT failure supervision function …………………………………………………………………….. 190
- 2 Function principle ……………………………………………………………………………………… 190
- 3 Input and output signals ……………………………………………………………………………… 193
- 4 Setting …………………………………………………………………………………………………….. 194
- 5 Report …………………………………………………………………………………………………….. 195
- 6 Technical data …………………………………………………………………………………………… 196
- Chapter 17 External BIs to trip BOs ………………………………………………………………….. 197
- 1 Introduction ………………………………………………………………………………………………. 198
- 2 Function principle ……………………………………………………………………………………… 198
- 3 BI Trigger Record ……………………………………………………………………………………… 199
- 4 BI Switch SetGroup …………………………………………………………………………………… 200
- 5 BI “Blk Rem Access” and “RELAY TEST” ………………………………………………………. 200
- 6 BI “BI_Config1~ BI_Config2” and “BI TRIGGER DR1~ 10” ………………………………. 201
- 7 Setting …………………………………………………………………………………………………….. 201
- Chapter 18 Station communication …………………………………………………………………… 203
- 1 Overview …………………………………………………………………………………………………. 204
- 1.1 Protocol ……………………………………………………………………………………….. 204
- 1.1.1 LON communication protocol ……………………………………………………. 204
- 1.1.2 IEC61850-8 communication protocol ………………………………………….. 204
- 1.1.3 IEC60870-5-103 communication protocol ……………………………………. 205
- 1.2 Communication port ………………………………………………………………………. 205
- 1.2.1 Front communication port …………………………………………………………. 205
- 1.2.2 RS485 communication ports ……………………………………………………… 205
- 1.2.3 Ethernet communication ports …………………………………………………… 205
- 1.3 Technical data ………………………………………………………………………………. 205
- Front communication port …………………………………………………………………………………. 206
- RS485 communication port ………………………………………………………………………………. 206
- 2 Typicalcommunication scheme ……………………………………………………………………. 208
- 2.1 Typical substation communication scheme ………………………………………… 208
- 2.2 Typical time synchronizing scheme ………………………………………………….. 208
- Chapter 19 Hardware …………………………………………………………………………………….. 211
- This chapter describes the IED hardware. …………………………………………………………… 211
- 3 Introduction ………………………………………………………………………………………………. 212
- 3.1 IED structure ………………………………………………………………………………… 212
- 3.2 IED appearance …………………………………………………………………………….. 212
- 3.3 IED module arrangement ………………………………………………………………… 213
- 3.4 The rear view of the protection IED …………………………………………………… 213
- 4 Local human-machine interface …………………………………………………………………… 214
- 4.1 Human machine interface ……………………………………………………………….. 214
- 4.2 LCD …………………………………………………………………………………………….. 215
- 4.3 Keypad ………………………………………………………………………………………… 215
- 4.4 Shortcut keys and functional keys …………………………………………………….. 216
- 4.5 LED …………………………………………………………………………………………….. 217
- 4.6 Front communication port ……………………………………………………………….. 218
- 5 Analog input module ………………………………………………………………………………….. 219
- 5.1 Introduction …………………………………………………………………………………… 219
- 5.2 Terminals of Analogue Input Module (AIM) ………………………………………… 219
- 5.3 Technical data ……………………………………………………………………………….. 220
- 5.3.1 Internal current transformer ……………………………………………………….. 220
- 5.3.2 Internal voltage transformer ………………………………………………………. 221
- 6 Communication module ……………………………………………………………………………… 222
- 6.1 Introduction …………………………………………………………………………………… 222
- 6.2 Substaion communication port …………………………………………………………. 222
- 6.2.1 RS232 communication ports ……………………………………………………… 222
- 6.2.2 RS485 communication ports ……………………………………………………… 222
- 6.2.3 Ethernet communication ports……………………………………………………. 222
- 6.2.4 Time synchronization port …………………………………………………………. 223
- 6.3 Terminals of Communication Module ………………………………………………… 223
- 6.4 Operating reports …………………………………………………………………………… 224
- 6.5 Technical data ……………………………………………………………………………….. 224
- 6.5.1 Front communication port …………………………………………………………. 224
- 6.5.2 RS485 communication port ……………………………………………………….. 225
- 6.5.3 Ethernet communication port …………………………………………………….. 225
- 6.5.4 Time synchronization ……………………………………………………………….. 226
- 7 Binary input module …………………………………………………………………………………… 227
- 7.1 Introduction …………………………………………………………………………………… 227
- 7.2 Terminals of Binary Input Module (BIM) …………………………………………….. 227
- 7.3 Technical data ……………………………………………………………………………….. 229
- 8 Binary output module …………………………………………………………………………………. 230
- 8.1 Introduction …………………………………………………………………………………… 230
- 8.2 Terminals of Binary Output Module (BOM) …………………………………………. 230
- 8.2.1 Binary Output Module A ……………………………………………………………. 230
- 8.2.2 Binary Output Module C ……………………………………………………………. 233
- 8.3 Technical data ……………………………………………………………………………….. 234
- 9 Power supply module …………………………………………………………………………………. 236
- 9.1 Introduction …………………………………………………………………………………… 236
- 9.2 Terminals of Power Supply Module (PSM) ………………………………………… 236
- 9.3 Technical data ………………………………………………………………………………. 238
- 10 Techinical data ……………………………………………………………………………………. 239
- 10.1 Basic data ……………………………………………………………………………………. 239
- 10.1.1 Frequency ……………………………………………………………………………… 239
- 10.1.2 Internal current transformer ………………………………………………………. 239
- 10.1.3 Internal voltage transformer ………………………………………………………. 239
- 10.1.4 Auxiliary voltage ……………………………………………………………………… 239
- 10.1.5 Binary inputs…………………………………………………………………………… 240
- 10.1.6 Binary outputs ………………………………………………………………………… 240
- 10.2 Type tests …………………………………………………………………………………….. 241
- 10.2.1 Product safety-related Tests ……………………………………………………… 241
- 10.2.2 Electromagnetic immunity tests …………………………………………………. 242
- 10.2.3 DC voltage interruption test ………………………………………………………. 244
- 10.2.4 Electromagnetic emission test …………………………………………………… 244
- 10.2.5 Mechanical tests ……………………………………………………………………… 244
- 10.2.6 Climatic tests ………………………………………………………………………….. 245
- 10.2.7 CE Certificate …………………………………………………………………………. 246
- 10.3 IED design …………………………………………………………………………………… 246
- Chapter 20 Appendix ……………………………………………………………………………………… 247
- 1 General setting list …………………………………………………………………………………….. 248
- 1.1 Function setting list ……………………………………………………………………….. 248
- 1.2 Binary setting list …………………………………………………………………………… 266
- 2 General report list ……………………………………………………………………………………… 288
- 3 Time inverse characteristic …………………………………………………………………………. 295
- 3.1 11 kinds of IEC and ANSI inverse time characteristic curves ………………… 295
- 3.2 User defined characteristic ……………………………………………………………… 296
- 4 CT Requirement ……………………………………………………………………………………….. 296
- 4.1 Overview ……………………………………………………………………………………… 296
- 4.2 Current transformer classification …………………………………………………….. 296
- 4.3 Abbreviations (according to IEC 60044-1, -6, as defined) …………………….. 297
- 4.4 General current transformer requirements …………………………………………. 298
- 4.4.1 Protective checking current ………………………………………………………. 298
- 4.4.2 CT class ………………………………………………………………………………… 299
- 4.4.3 Accuracy class ……………………………………………………………………….. 301
- 4.4.4 Ratio of CT …………………………………………………………………………….. 301
- 4.4.5 Rated secondary current ………………………………………………………….. 301
- 4.4.6 Secondary burden …………………………………………………………………… 302
- 4.5 Rated equivalent secondary e.m.f requirements …………………………………. 302
- 4.5.1 Transformer differential protection ……………………………………………… 303
Line differential protection (87L):
The line differential protection consists of three protection functions, phase segregated differential protection function, sudden change current differential protection function and zero sequence current differential protection function.
These three functions are associated with achieving high sensitivity and reliability with capacitive charge current compensation and reliable phase selection during various system disturbances. The precise time
synchronization of sampling ensures the differential protection of both end IEDs to operate reliably
Distance protection (21, 21N)
The transmission line distance protection provides a five zones full scheme protection with all phase to phase faults and phase to earth fault loops independently for each zones.
Additionally, one extension zone is employed to co-operate with Auto-reclosing and tele-protection schemes.
Chapter 1 IED Introduction ………………………………………………………………………………………………… 1
Chapter 2 Local human machine interface ………………………………………………………………………… 3
1 Introduction ……………………………………………………………………………………………………………………… 4
2 Liquid crystal display（LCD） …………………………………………………………………………………………. 6
3 Keyboard ………………………………………………………………………………………………………………………… 7
4 IED menu ………………………………………………………………………………………………………………………… 8
4.1 Menu construction …………………………………………………………………………………………….. 8
4.2 Operation status ……………………………………………………………………………………………….. 9
4.3 Query reports ………………………………………………………………………………………………….. 10
4.4 Set time …………………………………………………………………………………………………………… 10
4.5 Contrast ………………………………………………………………………………………………………….. 10
4.6 Settings …………………………………………………………………………………………………………… 11
4.7 IED setting ………………………………………………………………………………………………………. 12
4.8 Test binary output ……………………………………………………………………………………………. 12
4.9 Testing operation …………………………………………………………………………………………….. 12
Chapter 3 Installing IED …………………………………………………………………………………………………… 13
1 Unpacking and checking the IED …………………………………………………………………………………… 14
2 Installing the IED …………………………………………………………………………………………………………… 15
3 IED connection ……………………………………………………………………………………………………………… 16
3.1 IED connector …………………………………………………………………………………………………. 16
3.1.1 Introduction ………………………………………………………………………………………………. 16
3.1.2 Terminals of Analogue Input Module (AIM) ………………………………………………. 17
3.1.3 Terminals of Binary Input Module (BIM) ……………………………………………………. 18
3.1.4 Terminals of Binary Output Module (AIM) …………………………………………………. 19
3.1.5 Terminals of Communication module (COM) ……………………………………………. 23
3.1.6 Communication ports of CPU module (CPU) ……………………………………………. 24
3.1.7 Terminals of Power Supply Module (PSM) ……………………………………………….. 25
3.1.8 RS232 port ………………………………………………………………………………………………. 26
3.2 Connecting to protective earth ………………………………………………………………………… 26
3.3 Connecting the power supply module ……………………………………………………………… 26
3.4 Connecting to CT and VT circuits ……………………………………………………………………. 26
3.5 Connecting the binary inputs and outputs ……………………………………………………….. 26
3.6 Making the screen connection …………………………………………………………………………. 28
3.7 Optical connections …………………………………………………………………………………………. 28
3.8 RS485 and RS232 ports connection ……………………………………………………………….. 29
3.8.1 RS485 port connection …………………………………………………………………………….. 29
3.8.2 RS232 port connection …………………………………………………………………………….. 29
3.9 Connecting the GPS ……………………………………………………………………………………….. 30
4 Checking before energizing …………………………………………………………………………………………… 31
4.1 Introduction ……………………………………………………………………………………………………… 31
4.2 Checking the protective earth connection ………………………………………………………… 31
4.3 Checking the power supply connection ……………………………………………………………. 31
4.4 Checking the CT and VT circuits connection …………………………………………………… 31
4.4.1 Checking the CT circuits connection ………………………………………………………… 31
4.4.2 Checking the VT connection …………………………………………………………………….. 32
4.5 Checking the binary input and output connection …………………………………………….. 32
4.5.1 Checking the binary input connection ……………………………………………………….. 32
4.5.2 Checking the binary output connection …………………………………………………….. 33
4.6 Checking the screened cables connection ………………………………………………………. 33
4.7 Checking the optical connections …………………………………………………………………….. 33
4.8 Checking the S485 and RS232 port connectios ………………………………………………. 33
4.8.1 Checking the RS485 port connection ……………………………………………………….. 33
4.8.2 Checking RS232 port connection ……………………………………………………………… 33
4.9 Checking GPS connection ………………………………………………………………………………. 33
4.10 Checking the insulation voltage and insulation resistance ……………………………….. 33
4.10.1 Checking the insulation voltage ………………………………………………………………… 34
4.10.2 Checking the insulation resistance …………………………………………………………… 34
5 Checking after energizing ………………………………………………………………………………………………. 35
5.1 Introduction ……………………………………………………………………………………………………… 35
5.2 Test LCD …………………………………………………………………………………………………………. 35
5.3 Test the keyboard ……………………………………………………………………………………………. 35
5.4 Setting the IED time ………………………………………………………………………………………… 35
5.5 Self-supervision HMI data ……………………………………………………………………………….. 36
5.6 Checking the software and hardware version ………………………………………………….. 36
Chapter 4 Read and change setting …………………………………………………………………………………. 37
1 Read and change the setting vaule ……………………………………………………………………………….. 38
1.1 Read and change the setting value via LHMI…………………………………………………… 38
1.1.1 Introduction ………………………………………………………………………………………………. 38
1.1.2 Communication parameter ……………………………………………………………………….. 38
1.1.3 Equipment parameter ……………………………………………………………………………….. 39
1.1.4 Setting values and binary settings for protection function …………………………. 39
2 Switching the setting group ……………………………………………………………………………………………. 48
2.1 Introduction ……………………………………………………………………………………………………… 48
2.2 Method for switching setting group via LHMI …………………………………………………… 48
2.3 Method for switching setting group via binary input …………………………………………. 48
Chapter 5 Testing the communication connection and time synchronization ……………………. 49
1 Testing the communication connection ………………………………………………………………………….. 50
1.1 Testing the Ethernet communication ……………………………………………………………….. 50
1.1.1 Testing the electrical Ethernet communication ………………………………………….. 50
1.1.2 Testing the optical Ethernet communication ……………………………………………… 50
1.2 Testing the RS485 port ……………………………………………………………………………………. 50
1.3 Testing the RS232 port ……………………………………………………………………………………. 50
2 Testing the time synchronization ……………………………………………………………………………………. 52
2.1 Network mode …………………………………………………………………………………………………. 52
2.2 Pulse mode …………………………………………………………………………………………………….. 52
2.3 IRIG-B mode …………………………………………………………………………………………………… 52
Chapter 6 IED testing ………………………………………………………………………………………………………. 53
1 Introduction ……………………………………………………………………………………………………………………. 54
2 Points for attention during testing ………………………………………………………………………………….. 56
3 Preparing for test …………………………………………………………………………………………………………… 58
3.1 Introduction ……………………………………………………………………………………………………… 58
3.2 Connecting test equipment to IED …………………………………………………………………… 58
4 Testing the power supply ……………………………………………………………………………………………….. 60
4.1 Checking the self-startup performance ……………………………………………………………. 60
4.2 DC power on and power off testing …………………………………………………………………. 60
4.3 Checking the expiry date of power supply ……………………………………………………….. 60
5 Checking the analog channel ………………………………………………………………………………………… 61
5.1 Checking the zero drift …………………………………………………………………………………….. 61
5.2 Calibrating ………………………………………………………………………………………………………. 61
5.3 Checking the accuracy and the linearity of analog quantitis …………………………….. 61
5.4 Checking the polarity of analog quantities ……………………………………………………….. 62
6 Testing binary input ……………………………………………………………………………………………………….. 63
7 Testing binary output ……………………………………………………………………………………………………… 64
8 Verifying the IED functions …………………………………………………………………………………………….. 65
8.1 Differential current protection ………………………………………………………………………….. 65
8.1.1 Loop test mode ………………………………………………………………………………………… 65
8.1.2 Normal mode ……………………………………………………………………………………………. 74
8.1.3 Completing the test ………………………………………………………………………………….. 83
8.1.4 Reference setting list for test ……………………………………………………………………. 83
8.2 Distance protection …………………………………………………………………………………………. 85
8.2.1 Verifying the settings ………………………………………………………………………………… 85
8.2.2 Completing the test ………………………………………………………………………………… 108
8.2.3 Reference setting list for test ………………………………………………………………….. 108
8.3 Power swing function …………………………………………………………………………………….. 111
8.3.1 Verifying the power swing function settings…………………………………………….. 111
8.3.2 Completing the test ………………………………………………………………………………… 111
8.3.3 Reference setting list for test ………………………………………………………………….. 111
8.4 Teleprotection for distance protection ……………………………………………………………. 112
8.4.1 Verifying the settings ………………………………………………………………………………. 112
8.4.2 Completing the test ………………………………………………………………………………… 124
8.4.3 Reference setting list for test ………………………………………………………………….. 124
8.5 Teleprotection for earth fault protection …………………………………………………………. 125
8.5.1 Verifying the settings ………………………………………………………………………………. 125
8.5.2 Completing the test ………………………………………………………………………………… 129
8.5.3 Reference setting list for test ………………………………………………………………….. 130
8.6 Overcurrent protection …………………………………………………………………………………… 130
8.6.1 Verifying the settings ………………………………………………………………………………. 131
8.6.2 Completing the test ………………………………………………………………………………… 135
8.6.3 Reference setting list for test ………………………………………………………………….. 136
8.7 Earth fault protection ……………………………………………………………………………………… 137
8.7.1 Verifying the settings ………………………………………………………………………………. 137
8.7.2 Completing the test …………………………………………………………………………………. 141
8.7.3 Reference setting list for test ………………………………………………………………….. 141
8.8 Emergency/backup overcurrent protection …………………………………………………….. 143
8.8.1 Verifying the settings ………………………………………………………………………………. 143
8.8.2 Completing the test …………………………………………………………………………………. 148
8.8.3 Reference setting list for test ………………………………………………………………….. 148
8.9 Emergency/backup earth fault protection ………………………………………………………. 149
8.9.1 Verifying the settings ………………………………………………………………………………. 149
8.9.2 Completing the test …………………………………………………………………………………. 153
8.9.3 Reference setting list for test ………………………………………………………………….. 153
8.10 Switch-onto-fault protection ……………………………………………………………………………. 154
8.10.1 Verifying the settings ………………………………………………………………………………. 154
8.10.2 Completing the test …………………………………………………………………………………. 164
8.10.3 Reference setting list for test ………………………………………………………………….. 165
8.11 Overload protection ……………………………………………………………………………………….. 166
8.11.1 Verifying the settings ………………………………………………………………………………. 166
8.11.2 Completing the test …………………………………………………………………………………. 168
8.11.3 Reference setting list for test ………………………………………………………………….. 168
8.12 Overvoltage protection …………………………………………………………………………………… 168
8.12.1 Verifying the settings ………………………………………………………………………………. 168
8.12.2 Completing the test …………………………………………………………………………………. 173
8.12.3 Reference setting list for test ………………………………………………………………….. 173
8.13 Undervoltage protection …………………………………………………………………………………. 174
8.13.1 Verifying the settings ………………………………………………………………………………. 174
8.13.2 Completing the test …………………………………………………………………………………. 179
8.13.3 Reference setting list for test ………………………………………………………………….. 180
8.14 Circuit breaker failure protection ……………………………………………………………………. 181
8.14.1 Verifying the settings of stage 1 of CBF protection………………………………….. 181
8.14.2 Completing the test …………………………………………………………………………………. 185
8.14.3 Reference setting list for test ………………………………………………………………….. 185
8.15 Dead zone protection …………………………………………………………………………………….. 186
8.15.1 Verifying the settings ………………………………………………………………………………. 186
8.15.2 Completing the test …………………………………………………………………………………. 187
8.15.3 Reference setting list for test ………………………………………………………………….. 187
8.16 STUB protection …………………………………………………………………………………………….. 188
8.16.1 Verifying the settings ………………………………………………………………………………. 188
8.16.2 Completing the test …………………………………………………………………………………. 189
8.16.3 Reference setting list for test ………………………………………………………………….. 189
8.17 Poles discordance protection …………………………………………………………………………. 190
8.17.1 Verifying the settings ………………………………………………………………………………. 190
8.17.2 Completing the test …………………………………………………………………………………. 193
8.17.3 Reference setting list for test ………………………………………………………………….. 193
8.18 Synchro-check and energizing check function ………………………………………………. 193
8.18.1 Verifying the settings ………………………………………………………………………………. 193
8.18.2 Completing the test ………………………………………………………………………………… 204
8.18.3 Reference setting list for test ………………………………………………………………….. 204
8.19 Auto-reclosing ……………………………………………………………………………………………….. 205
8.19.1 Verifying the settings ………………………………………………………………………………. 205
8.19.2 Completing the test ………………………………………………………………………………… 207
8.19.3 Reference setting list for test ………………………………………………………………….. 207
8.20 Current transformer secondary circuit supervision …………………………………………. 209
8.20.1 Verifying the settings ………………………………………………………………………………. 209
8.20.2 Completing the test ………………………………………………………………………………… 210
8.20.3 Reference setting list for test ………………………………………………………………….. 210
8.21 Voltage transformer secondary circuit supervision ………………………………………… 210
8.21.1 Verifying the settings ………………………………………………………………………………. 211
8.21.2 Completing the test ………………………………………………………………………………… 216
8.21.3 Reference setting list for test ………………………………………………………………….. 217
8.22 Monitoring function ………………………………………………………………………………………… 217
8.22.1 Phase sequence of voltage and current monitoring ………………………………… 217
8.22.2 3I0 polarity monitoring ……………………………………………………………………………. 218
8.22.3 Monitoring third harmonic of voltage ………………………………………………………. 218
8.22.4 Reference voltage monitoring…………………………………………………………………. 219
8.22.5 Auxiliary contact of circuit breaker monitoring ………………………………………… 220
8.22.6 Broken conductor monitoring ………………………………………………………………….. 220
9 Checking before operation …………………………………………………………………………………………… 223
9.1 Checking the LED …………………………………………………………………………………………. 223
9.2 Checking the display on LCD ………………………………………………………………………… 223
9.3 Checking the clock ………………………………………………………………………………………… 223
9.4 Checking the voltage and current ………………………………………………………………….. 223
9.5 Checking the setting group ……………………………………………………………………………. 223
9.6 Checking the setting ……………………………………………………………………………………… 223
9.7 Checking the binary input ………………………………………………………………………………. 224
9.8 Checking the normal operation mode ……………………………………………………………. 224
9.8.1 Trip and close test with the circuit breaker ……………………………………………… 224
9.9 Put into operation ………………………………………………………………………………………….. 224
Chapter 7 Operating maintenance …………………………………………………………………………………. 225
1 Attentions during operating ………………………………………………………………………………………….. 226
2 Routine checking …………………………………………………………………………………………………………. 228
3 Periodical checking ……………………………………………………………………………………………………… 229
4 Operation after updating software or replacing modules ……………………………………………… 230
4.1 Operation after updating software or replacing CPU module …………………………. 230
4.2 Operation after updating software or replacing communication module…………. 230
4.3 Operation after replacing the binary input or output module ………………………….. 231
4.4 Operation after replacing the analog input module ………………………………………… 231
4.5 Operation after replacing power supply module …………………………………………….. 231
5 The alarm information and measure …………………………………………………………………………….. 232
5.1 Alarm information class I and the measure ……………………………………………………. 232
5.2 Alarm information class II and the measure …………………………………………………… 232
Chapter 8 Transportation and storage ……………………………………………………………………………. 235
1 Transportion…………………………………………………………………………………………………………………. 236
2 Storage ………………………………………………………………………………………………………………………… 237
Chapter 9 Appendix ……………………………………………………………………………………………………….. 239
1 Arrangement diagram of modules ………………………………………………………………………………… 240
2 Typical diagram ……………………………………………………………………………………………………………. 241
Trainer: Dr. Saeed Roostaee
Course outline
Electrical System
- Introduction to Electrical System
- Construction of Electrical System
- Single and Three-Phase electrical circuit basics
ETAP
- Fundamentals of Power System Analysis
- Design and Simulate Electrical Power System Using ETAP Software
- Creating New Project in ETAP
- Understanding ETAP Software Overview & Toolbars
- Create Single Line Diagram in ETAP With Conventional Modelling Method & Auto-Build (Time Saving)
- Load Flow Analysis – Theory, Comparison of Hand Calculations and ETAP Results
- Load Flow Analysis Example
- Short Circuit Analysis – Theory, Comparison of Hand Calculations and ETAP Results
- Short Circuit Analysis Example
- Protection and Coordination
- Protection Coordination (Relay Coordination) Analysis – Theory
- Protection Coordination Analysis Example
- Protection Coordination Analysis – Auto Star Evaluation
Electrical substation
- Introduction to Electrical System
- Construction of Electrical System
- Substation configurations
- Instrument Transformers and Principle of Operation of Trip Circuit
- Types of Circuit Breakers
- Types of Relays According to Function, Construction, and Time Characteristics
- CT & PT Design
- CT Protection Class
- PT Protection Class
- Numerical protection relays
- Definition of Busbar and Different Busbar Schemes
Electricity Generation
- Introduction to Electrical Power Systems and Why We Need High Voltage
- Introduction to Generating Power Plants
- Hydroelectric Power Plants and Their Types
- Hydraulic Head in Hydroelectric Power Plants
- Diesel Generators
- Fossil Fuel – Conventional Power Plants
- Gas-Fired Power Plants and their Types
- Nuclear Power Plants
- Geothermal Power Plant and its Types
- Solar Energy
- Wind Energy
Synchronous Generator
- Synchronous Generator Working Principle and Its Types
- Faraday’s Law of Induction and Lenz’s Law
- Wound Rotor and Squirrel Cage Induction Machines
- Doubly-Fed Induction Generator
- Self-Excited Induction Generator
- Generator Load Sharing
- Generator faults
- Generator protecion relay IEDs
- Generator Protection functions
Transformers
- Transformer Introduction
- Transformer design
- Sizing & Selection
- Transformer Design Calculation
- Transformer MVA Sizing using ETAP
- Transformer X/R Ratio Calculation
- Transformer Faults
- Transformer Protection Functions
- Transformer Protection Relay IEDS
Cable & Overhead Transmission Lines
- Construction of Overhead Transmission Lines
- Introduction of Cable
- Voltage Drop Calculation
- Example Cable Sizing Calculation
- Cabling and Wiring Method
- Jointing of Cables
- Cable Schedule
- Cable Tray Layout
- Construction of Underground Cables
- Cable Sizing Analysis using ETAP
Motor
- Basics of Synchronous and Asynchronous Motors
- Motor Nameplate
- Motor Connections
- Motor Sizing and Selection
- Motor Design Calculation
- Motor Starting Analysis
- Motor Starting Analysis Examples
- Motor Faults, Faults, and Protection Functions
- Overview of the Motor Protection Functions
Power factor correction
- Power Triangle & Power Factor Improvement
- Method for Improving Power Factor & Types of Capacitors
- Reason for Failure of Capacitors
- Low Voltage Capacitor Construction
- Capacitor Sizing Calculation
Earthing system design
- Effect of Current on the Human Body
- Types of Electric Hazards
- Classification of Earthing Systems
- Components of Earthing System
- Design and Resistance of Earthing Electrode
- Design and Resistance of Earthing Conductor
- Measurement of Earth Resistance by Megger and Three Point Method
- Design Earthing or Ground Grid Using ETAP
- Course Name: SIEMENS SAS
- Pre-requisite training: DIGSI 4, DIGSI 5, IEC61850
- Language: English
- + Supporting Files
- + Certificate of completion
- Delivery: Face-to-face / Online
- Duration: 8 Days
- Trainer: Dr. Saeed Roostaee (Profile)
Substation Automation System
- Substation Automation System-an overview
- SIEMENS SAS In the past
- SIEMENS SAS Nowadays
- Network Theory (Types of Communications, Data Transmission Types, MAC Address, IP Address, Subnet Mask)
- Fundamentals of Communication Via Ethernet Various Topologies
- Ethernet and IEC 61850 Concepts (The EN100 Communication Module, Time Server, Switch, Network Card)
- Important Factors for Choosing a Topology
- Star Topology
- Ring Topology
Hardware
- RUGGEDCOM Ethernet Switch RS900
- RUGGEDCOM Ethernet Switch RS8000
- RUGGEDCOM Ethernet Switch RSG2100
- SIPROTEC Communication Modules
- Hirschmann Switches
- Siemens Scalance – Switches
- Modems
- I/O-Box 6MD61
- Bay Controller 6MD66
- Transformer Regulators
- SICAM 1703 device series – TM 1703 mic
- SICAM 1703 device series – TM 1703 ACP
- SICAM 1703 device series – BC 1703 ACP
- SICAM 1703 device series – AK 1703 ACP
- Siemens Serial Modem 7XV5655
- Siemens converter – Mini star coupler
- Com-Expander: Comtrol Rocket Port
- Operator Desk / Engineering PCs
- Time receiver
- external time masters
- NTP-time synchronization with SICLOCK
- Modem Splitter
- Station Unit 6MD9101
- SICAM PAS Station Unit
Bay Level Engineering (IEC 61850 and Modbus)
- Sample IEC 81850 Configuration
- Setting the Network Parameters for Ethernet Switches
- Modbus Connection of Measuring Centers
- Serial/Ethernet Converter (7XV5655)
- GPS Satellite Clock
- IEC 61850 – The Configuration Language SCL File Types at a glance
- ICD file – IED Capability Description
- SSD file – Substation Specification Description
- CID file – Configured IED Description
- SCD file – Substation Configuration Description
- IEC 61850 Services in IEDs and SICAM PAS
- Updating ICD – Files
- IEC 61850 – creating PAS configuration data
- Client/Server Communication
- Publisher / Subscriber Communication
- Logical Node
- Data Objects
- Standardizing Communication with Logical Nodes
- Addressing control of a circuit breaker
- Ethernet switches according to IEC61850 specification
- Ethernet Master clocks
- IEC61850 Engineering
- Process of IEC61850 Engineering
- Diagnosis Tool Networkview
- Diagnosis Tool IEC-Browser
- Config signals in the DIGSI 4 Matrix
- Config signals in the DIGSI 5 IEC61850 structure
- System Configurator in DIGSI
- Assign IEDs to the IEC 61850 Station
- Mapping GOOSE messages
- Updating device parameter files
- IEC 61850 Ethernet Medium: FO Ring
- IEC 61850 Ethernet Configuration: Electrical Star
- IEC 61850 Ethernet FO-Ring with RuggedCom
- IEC 61850 Ethernet FO-Ring with optical EN100
- IEC 61850 Ethernet – Partial Redundant FO-Ring
- IEC 61850 Ethernet – Redundant FO-Ring
- IEC 61850 Ethernet – with redundant PAS
- Sample Real Projects
- Export of Station Information
- Import of SCD-File into the SICAM PAS
Station Level Engineering SICAM PAS
- Introduction to SICAM PAS Automation System
- SICAM PAS Tasks
- Fields of Application
- SICAM PAS Features
- Scalability – Software and Hardware Configuration for Small to Large Applications
- Basic Package “ Full Server”
- Distributed system with higher performance (Full Server + DIP (Device Interface Processor))
- High availability by Redundancy
- High flexibility through further interfaces
- Optional Packages (IEC 61850, Profibus FMS (SICAM/SIPROTEC specified protocols), IEC 60870-5-103, DNP V3.00, Profibus DP, Modbus, ILSA (Internal LSA protocol, OPC-Client, Automation CFC)
- Substation Automation Functions (Control Authority, Bay Blocking, Telecontrol Blocking, Time Synchronization, Fault Recording, Redundancy)
- SICAM PAS in Star Configuration
- SICAM PAS in (Fiber Optic) Ring
- SICAM PAS FO Station LAN
- SICAM PAS Installation
- Licensing
- Licensing With Feature Enabler
- SICAM PAS Basic packet and options
- SICAM PAS Configuration User Administration Tool
- IEC 61850 Services in IEDs and SICAM PAS
- SICAM PAS Configuration (Working with Project Databases, Creating a New Database, Adding and Managing Systems, Adding an Application (IEC 61850 Client), Importing a SCD file, Updating One or Several Device(s), Adding ModbusApplication, Parameterizing ModbusApplication, Added EMA90 ModbusMap, Defining the Device Template (ModbusMap), Adding IEC 60870-5-101 Slave Application, Inserting the Control Center of IEC 60870-5-101 Slave, Inserting the SNMP Application, Monitoring IEC 61850 IEDs Connection Status With SNMP, Inserting a PASCC Application to Full Server System, Inserting Control Center to PASCC Application, Inserting a PASCC to a New System (DIP)
- Creating a Full Server Computer
- Creating an IEC101-Master to connect the RTU
- Importing the RTU file
- Communication IEC 60870-5-103
- Communication OPC-Client (based on COM/DCOM)
- Communication OPC-XML-Server
- SICAM PAS Configuration (Topology Management, Filtering, Topology Tree Structure, Selection of Signals for Each Sub-Level, Modbus (Measuring) Signals
- SICAM PAS Configuration (Automation (Soft PLC), Logic Processing with CFC, Info to / Com from SoftPLC (Mapping), Creating New CFC Program, Connection of Source and Destination Variables
- Routing messages from/to SoftPLC
- Renaming duplicated message
- Creating a CFC file
- CFC block
- Inserting Variable into interconnection column
- Grouping with a “PAS_GROUPI”-Function Block
- Converting a Counter Differential Value to a Counter Final Value
- Interlocking
- Run Sequence
- Online Mode
- Watchlist
- CDA (Control Data Analyzer) Necessary settings
- Mapping an output to CDA
- Human-Machine Control Center Mapping, Exporting of HMI1 Interface
- How to select a group of messages
- Normalization
- Create a Normalization Template
- Scaling a measured value
- Normalization as a multiple-used template
- Assignment of normalization in Mapping
- Adaptation of transformer tap position indications
- Archiving Configured Project, Un-archiving Project
SICAM PAS UI-Operation
- Updating the System
- Symbols in the tree view
- Operation – functions
- Exporting messages from PAS UI Configuration
SICAM PAS Value Viewer
- Mapping shows the Information Volume
- SICAM PAS Value Viewer
- The properties of a message
- Control function
- Testing data
- Important columns
- ValueViewer: Communication diagnostics
SICAM PQS
- Fault recording with SICAM PQS
- SICAM PQS – Functional Overview
- Incident Explorer
- PQ Explorer
- Grid Code Viewer
- Report Browser
- PQ Inspector
SCADA
- IEC 60870-5-101, the telecontrol profile
- IEC 60870 – 5 – 101 The most important features
- IEC 60870 – 5 – 101 telegram structure
- Type Identification in monitoring direction
- Type Identification in command direction
- Type Identification for organization objects
- Type Identification for parameters
- Quality Information
- IEC 60870-5-102, the counter profile
- IEC 60870-5-103, the IED/protection relay profile
- Creating an IEC103-Master and Interface
- Communication Parameters
- Data Units specified in IEC 60870-5-103
- Info Identification in PAS for IEC 60870-5-103
- IEC 60870-5-104, the network profile (based on 60870-5-101)
- Software IECTEST
- Settings for IEC 60870-5-104
- IEC 60870-5-104 Slave – Control Center Simulation
SICAM SCC
- Export of HMI information from SICAM PAS
- Check the content of a PXD file
- Introduction to SICAM PASCC Control Center
- SICAM PASCC Control Center ‐ Overview
- SIMATIC WinCC
- SICAM PASCC Components
- SICAM PASCC Communication
- SICAM PAS Wizard
- WinCC Explorer
- Graphic Objects Library
- Switchgear Objects
- Schwitchgear Objects – Styles and States
- Alarm Logging – Message List
- Control & Monitoring
- WinCC & PASCC Licensing
- SIMATIC WinCC / SICAM PASCC Installation Steps
- Transfer The License Keys
- SIMATIC WinCC / SICAM PASCC Time Synchronization & NTP
- SICAM PASCC Starting The WinCC/PASCC Software
- SICAM PASCC Creating/ Opening a New Project
- SICAM PASCC Defining The Computer Properties General Tab, Startup Tab, Parameters Tab, Graphics Runtime Tab
- Adding a Communication Driver
- Connection Properties
- Entering the IP Address of SICAM PAS Servers
- SICAM PAS Wizard Opening
- Error Log File of SICAM PAS Wizard
- Select a Right SICAM PAS Protocol Suite
- Set PAS IP Connection
- Importing of the Sample Pilot Project .pxd File
- Redefining the failed Sample Project
- Checking Structure Tags of a New Project
- Structure Tag Elements
- Symbol Library
- SICAM Administrative Internal Tags
- Schwitchgear Objects – Tag Connection
- Design of Graphical Objects
- Switchgear Objects – Sychro-Check
- Alarm Logging – Events & Alarms
- Alarm Logging – Message Queue & Mes Ack Tags
- Tag Logging – Measured Values
- WinCC Horn Tools– Sound File
- Tag Logging – Archive Configuration
- Trends Picture
- Topological coloring
- Event List
- Alarm List
- Protection Message List
- Horn, Alarm Acknowledgment
- Creating an Event List in the Graphics Designer
- How to scale analog values
- User Administrator
- Login-Function via key combination
- Login via button
- Defining level of rights
- Entering the requested right
- Displaying the current operator
- Report Designer – Print Job
- Project Archive, Duplicator
- Automatic Start of WinCC Project
- Recpro
- Setting Up SICAM PAS Recpro
- SICAM VALPRO
- SICAM VALPRO – Graphic functions
- Bay Blocking
Redundancy
- Redundancy Definition
- Dependency Definition
- Redundant Communication
- System Switchover
- Manual Switchover
- Redundant “Full Server – DIP” Configuration
- Configuring a Redundant System
- Transferring a database to a Redundant System
- Status indication in a redundant system
- Single Channel IEDs
- IED Redundancy
- System Redundancy
- Communication with Control Center
- Control Center with one interface
- Control Center with 2 Interfaces
- Communication via WAN Network
Example: Switching Authority in SICAM PAS
- Switching Authority Group
- Routing to PAS CC
- Switching Authority Tag
- SICAM PAS CC symbol library
- Configuring Button Switching Authority
- Test the Switching Authority
OPC Communication
- What is OPC ?
- OPC Applications
- Overview of OPC data flow
- OPC Server & Client
- Config OPC Server in the SICAM PAS UI-Configuration
- OPC Client
- OPC-XML-Server
- Difference between the OPC-XML-Server with the previous OPC
- Creating OPC XML Server in SICAM PAS
Additional Information
- Automation License Manager
- Tasks to be started with the Runtime
- Language and Key Disabling
- Graphics Runtime
- Data structure (monitoring/control direction)
Hardware Setup for SIEMENS SAS training
- SIPROTEC 5 Multifunction Relay IED
- Fiber optic to Ethernet converter
- Ethernet Switch
- PLC S7-1200
- PC (IEDScout, DIGSI4, DIGSI5, SICAM PAS, WinCC, TIA Portal, SICAM SCC, Wireshark, IEC61850 Configurator …)
Technical brochure SPRECON-E-C
Technical brochure SPRECON-E-P_DS6
Technical brochure SPRECON-E-P_DD6
Technical brochure SPRECON-E-P_DQ6
Technical brochure SPRECON-E-P_DL6
Requirements: Knowledge of the most important terms of automation technology.
- Introduction
- Typical solution with SPRECON-E
- Process level, Bay level, and station level
- Interface to the Dispatching Center
- Network architecture
- Hardware modules (CPU, IO modules, Control panel)
- IEC 60870-5-101
- IEC 60870-5-104
- IEC 61850
- Impemmenation in the SPRECON-E
online course + pre-recorded videos
For more info about this training package, please contact us
- Trainer: Dr. Saeed Roostaee
- Comment on this post or contact us for more details
- Duration: 4 days
- Type: Face to face
Parts of the course topics:
⦁ Introduction to power system
⦁ The Per-Unit System
⦁ Per Phase Analysis
⦁ Symmetrical Components
⦁ Fourier Transform signal
⦁ Faults in Electrical System
⦁ Consequences of SC Faults
⦁ Types of Electric Faults
⦁ Establishment of SC
⦁ SC Calculation IEC 60909
⦁ Typical Fault criteria
⦁ Intro Power Sys Protection
⦁ Electromechanical Relays
⦁ Numerical Relays
⦁ Current Transformers
⦁ Voltage Transformers
⦁ Overcurrent
⦁ DOC (ANSI 67)
⦁ Coordination
⦁ Earthing
⦁ Line-To-Ground Faults
⦁ Earth Fault 50N 51N
⦁ Sensitive Earth Fault 50Ns 67Ns
⦁ Power Transformer Faults
⦁ Winding & Terminal Failures
⦁ The Effect of Through Faults on Power Transformers
⦁ Tap Changer (OLTC) Failure
⦁ Transform Miscellaneous Failures
⦁ How do we Protect Transformers?
⦁ ABB RET 670
⦁ Differential Protection
⦁ Transformer Differential Protection
⦁ Differences between digital transformer differential relays
⦁ Simulate different cases and test the differential transformer protection function
⦁ Restricted Earth Fault Protection(REF) in Transformer
⦁ High Impedance Restricted Earth Fault Protection working principle
⦁ Stability Resistance and Metrosil Resistance in REF Protection
⦁ Low impedance REF
⦁ Transmission Lines
⦁ Line Constants
⦁ Transmission Line Faults
⦁ How do we Protect Transmission Lines?
⦁ Distance Protection for Transmission Lines
⦁ Earth-Faults and Fault Resistance
⦁ Residual Compensation Factors
⦁ Short Zone
⦁ STUB
⦁ SOTF
⦁ Power Swing
⦁ Tele-Protection and weak infeed
⦁ Fault locator
⦁ Line diff
⦁ ABB REL 670
⦁ An overview of the PCM 600 functionality as well as how to get the software
⦁ Communication and Project setup, establish communication between the physical IED and PCM 600, Manage project with PCM 600, Hardware configuration
⦁ How to use the Application configuration tool in the PCM 600
⦁ How to use the Graphical Display editor tool in the PCM 600
⦁ How to use the Read and Write tool in the PCM 600
⦁ How to use the user management in the IED and PCM 600
⦁ IED online monitoring, event viewer, signal monitoring, disturbance handling
⦁ signal matrix editor tool in the PCM 600
⦁ The parameter setting tool in the PCM 600
⦁ Writing configuration into IED
⦁ IED compare
⦁ Config a simple distance protection function (SMAI, SMBI, SMBO, ZMMAPDIS, ZMMPDIS, FUFSPVC, …), configure sample signals based on the 7SA diagram
⦁ Config a simple 67N protection function, config disturbance reports (ARDAR, BRDAR, LED)
⦁ Parameter settings, XRIO format
⦁ Product guide for a pre-configured distance relay, and ordering, and modifying pre-configured distance relay based on our projects, Analog inputs (current &s for voltage), Distance Protection functions, and Communication logic
⦁ Current and Voltage protection functions and Earth Fault Protection Communication logic, Circuit Breaker Autorecloser and Tripping logics, Signal Logic and General IED functions, Virtual Binary inputs and outputs, Disturbance report analog and binary inputs
⦁ Function Block ActiveGroup
⦁ Function Block CMMXU
⦁ Function Block DRPRDRE
⦁ Function Block FXDSIGN
⦁ Function Block INTERRSIG
⦁ Function Block LEDGEN
⦁ Function Block LHMICTRL , LocalHMI
⦁ Function Block SINGLECMD
⦁ Function Block SMBI
⦁ Function Block SMBO
⦁ Function Block TESTMODE
⦁ Function Block TIMEERR
⦁ Function Block TIMER
⦁ ABB RET 670 Transformer Protection Application Template
⦁ ABB RET 670 Configuration and T2WPDIF Function block
⦁ ABB RET 670 Parameters and T2WPDIF parameters
⦁ Simulation of the differential protection algorithm in the ABB RET 670 relays
⦁ Omicron Test Universe Start page
⦁ Omicron Test Universe General settings
⦁ Omicron Test Universe Phasor view, Impedance view
⦁ Omicron CMC Hardware connection
⦁ Omicron Test Universe Test object, Overcurrent RIO block, testing of overcurrent
⦁ Omicron Test Universe Settings of the Overcurrent test module
⦁ Omicron Test Universe Diff parameters
⦁ Omicron Test Universe Diff RIO block
⦁ Omicron Test Universe Diff configuration
⦁ Omicron Test Universe Diff Operating Characteristic
⦁ Omicron Test Universe Diff Trip Time Characteristic & Diff Harmonic Restraint
⦁ RIO and XRIO history and why we should use this format for relay testing, RIO structure, XRIO structure, Differences between RIO and XRIO files, XRIO features & benefits, LinkToXRIO
⦁ XRIO template, How to Import Relay Settings, How to find a proper XRIO template and filter based on the relay
⦁ Common problems while loading the relay settings into a template and how to solve the issues, XRIO template based on the relay versions
⦁ Explain a case study XRIO file
⦁ Modify a case study XRIO file
⦁ Modify the XRIO template, RIO blocks
⦁ Distance RIO block
⦁ Advance Distance Test Module settings
⦁ Distance protection function principal, Impedance View
⦁ Analysis of several faults visually in the impedance view
⦁ Analysis of several distance relays (RAZOA, ABB REL670, SEL421, Siemens 7SA8x, MiCOM P442, NR PCS 931S, Protecta)
⦁ Distance Test Module settings
⦁ Preparing XRIO file for testing of impedance protection functions
IEC 61850 is an international standard for communication and interoperability of substation automation systems. It is developed by the International Electrotechnical Commission (IEC) and is widely used in the electrical power industry. The standard defines a comprehensive set of protocols and data models for the exchange of information within and between electrical substations.
Purpose and Benefits of IEC 61850:
IEC 61850 aims to standardize the communication between various devices in a substation, such as protection relays, intelligent electronic devices (IEDs), and control systems. It provides a common language and framework for integrating different substation automation functions, including protection, control, monitoring, and maintenance.
The standard promotes interoperability, allowing devices from different vendors to communicate and work together seamlessly.
IEC 61850 enables advanced functionalities like centralized control, system-wide monitoring, and improved fault diagnosis in substations.
It supports the move towards digital substations, where traditional analog signals are replaced by digital data exchange, leading to increased efficiency and flexibility.
Communication Architecture:
IEC 61850 defines a client-server-based communication architecture. The devices in a substation are categorized as servers (IEDs) and clients (control systems or HMIs). Communication between devices is facilitated through Ethernet-based networks. Data is organized into logical devices, which represent different functional units within a substation, such as circuit breakers, transformers, or measurement points.
Each logical device contains data objects, which represent specific information like status, measurements, settings, or control commands.
Data Modeling:
IEC61850 utilizes the Common Information Model (CIM) as the foundation for data modeling. CIM provides a standardized representation of power system information.
Services and Protocols:
IEC 61850 specifies a set of services and protocols for communication between devices. These include Generic Object Oriented Substation Event (GOOSE), Sampled Values (SV), and Manufacturing Message Specification (MMS).
GOOSE enables fast and reliable transmission of real-time information, such as trip signals or alarm messages, using multicast communication. the exchange of sampled analog and digital values between devices for real-time monitoring and control applications.MMS provides a comprehensive set of services for configuration, control, and data exchange between clients and servers.
IEC 61850 plays a crucial role in the modernization and standardization of substation automation systems. It enables efficient and reliable communication between devices, facilitates advanced automation functionalities
PSS SINCAL, a product of Siemens, is a simulation software for electricity and piping networks for generation, transmission, and distribution. PSS®SINCAL is used by transmission and distribution planning engineers, protection engineers, consultants, power plant and industrial grid operators, operations planning engineers, information technology specialists, researchers, and more. This software is part of the Siemens Xcelerator modular series. Siemens Xcelerator is an open digital business platform that enables you to accelerate your digital transformation easier, faster, and at scale. The software is also very flexible and customizable through its modular design.
The system offers a wide range of analysis functions for the planning, design, and operation of power systems, allowing you to simulate and study the following: power quality, frequency stability, distributed generation connection, coordination Conservation, supply reconstruction, economic design decisions, etc. With PSS®SINCAL, the planner can collectively study the overall impact on both systems and enhance future grid planning about new renewable integration and energy storage strategies. Protection engineers can tackle the complex field of protection with powerful simulations and visualizations, from protection coordination, validation, and configuration calculation to automated system-wide protection studies, protection performance evaluation, and thermal degradation analysis.
Features and features of PSS SINCAL software package:
- Geographic visualization capability that reflects the interactivity of the GIS program
- Interactive web-based online and offline background maps
- Integrated grid editor and report generation (list and label) to simplify data presentation and analysis
- Network models can be placed in multidimensional view (schematic, geographical) for different tasks with comparison options.
- Specialized mode (ExMode) for dynamic engine
- Interactive visualization of network models in schematic, geographic, or multilayer diagrams
- Extensive data modeling of all types of equipment, including smart network data models
- Open architecture for easy data exchange and information technology integration including geographic information systems (GIS), SCADA, distribution management systems (DMS), and meteorological data management systems (MDMS).
https://www.youtube.com/playlist?list=PLJExit9rQ0EqWE5FfR_IVVVBv6j50DckY
PSS® SINCAL Platform 19.5
Face-to-face / Online
Trainer: Dr. Saeed Roostaee (Profile)
- Power System Automation communication protocol
- Open Protocol
- Introduction to DNP3 protocol
- Why DNP
- DNP3 overview
- DNP Stack
- DNP3 messages
- DNP3 Application Layer
- Transport Function
- Link Layer
- DNP3 protocol simulation
- Practical section with DNP3 protocol
- DNP Protocol translator
Online Sections:
Configuration in DIGSI 5 SIPROTEC 5: basic DNP3 settings of TIM/CP (Device Configuration); configuration of a DNP3 connection in DIGSI 5; SIPROTEC 5 time synchronization in the DNP3 protocol; transferring analog values, counter values, and Boolean values time stamping, and event-buffering; Transferring Commands and Setpoint; peer-to-peer communication; serial & IP/Ethernet-based communication;
Exercise for simple system configurations with Ethernet-based networks …
- Type: Online-Training
- Trainer: Dr. Saeed Roostaee (Profile)
- Language: En
- Duration: 3 days
- Dates and Registration: End of this post
SAS introduction:
- Substation Automation Structure
- Conventional Control & Protection
- Modern Substation Automation (SA)
- Implementation of Intelligent Technology
- Intelligent SA Architecture
- Digital Substation
- Monitoring via IEDs for Protection
- Block diagram for a typical numerical relay
- Analogue to digital conversion
- Digital Phasor Measurement
Communication Introduction
- Parallel interface example
- Serial interface example
- Communication Medium
- Frame
- Baud rate
- Baud rate effect on frames
- Medium Access Methods
- Industrial Communication Protocols
- Profi-bus
- Profi-net
- RS232
- SPI
- Ethernet
- Parity & CRC
- Basic Data Types in Power System
- Info Identification for IEC 60870-5-103
OSI model
- Physical Layer
- Data link Layer
- Network Layer
- Application Layer
- Ethernet Addressing
- Frame and Packet
- TCP and UDP
- TCP/IP & its application in SAS
- UDP/IP & its application in SAS
IEC 60870
- What is IEC 60870-5?
- Introduction in IEC 60870-5 protocol-101/104 protocol
- Standard Protocols based on IEC 60870-5
- IEC 60870-5-101 features
- IEC 101 Telegram structure
- Cause of transmission
- ASDU (Application Service Data Unit)
- ASDU type identification
- Quality description
- IEC 60870-5-101 physical layer
- IEC 60870-5-101 Data Link layer
- IEC 60870-5-101 Application layer
- IEC 60870-5-104 stack layer
- Installation guidelines and configuring aids
- Network examples and network configuring
- IEC 60870-5 Configuration in DIGSI 5
- configuration of an IEC connection
- time synchronization in IEC 60870-5 protocol
IEC 60870-104 simulation
- IEC104 slave device
- IEC 60870 – 5 – 104 Signals Type
- COMMAND – IEC 60870-5-101
- Command IEC 60870 – 5 – 104
- Master IEC 60870 – 5 – 104 Protocol Test
- Timeout
- DEVICE IEC 60870 – 5 – 104 SLAVE PROPERTIES
IEC 60870-104 config in SIPROTEC 5
- SIPROTEC 5 Hardware
- General Settings
- User interface
- SIPROTEC 5 Config Procedure
- IEC 60870-104 config
- IEC 60870-104 simulation
Dates and Registration
| Date | Status |
| 22-24 March 2024 | Full (no seats available) |
| 6-8 May 2024 | Open (EUR 1100) |
| 18-20 June 2024 | Full (no seats available) |
| 16-18 Aug 2024 | Open (EUR 1400) |
| 14-16 Nov 2024 | Open (EUR 1400) |
- Online+ Pre-recorded Training
- 3-5 April 2024
- 22-24 March 2024
- Pre-requisite training: DIGSI 4, DIGSI 5, IEC61850
- Language: English
- Supporting Files
- Trainer: Dr. Saeed Roostaee (Profile)
- Limited seats available
- Registration link: expired
Module I: Substation Automation System
- Substation Automation System-an overview
- Introduction to Communication
- Network Theory
- Fundamentals of Communication Via Ethernet Various Topologies in SIEMENS SAS
Module II: Bay Level Engineering (IEC 61850 and Modbus)
- Add SIPROTEC 4 6MD66 device
- Setting the Network Parameters
- 6MD configuration
- IEC61850 Configuration
- Updating ICD – Files
Module III: Station Level Engineering SICAM PAS
- Introduction to SICAM PAS Automation System
- SICAM PAS Tasks
- Fields of Application
- SICAM PAS Features
- Scalability – Software and Hardware Configuration for Small to Large Applications
- Basic Package “ Full Server”
- SICAM PAS Packages (IEC 61850, Profibus FMS (SICAM/SIPROTEC specified protocols), IEC 60870-5-103, DNP V3.00, Profibus DP, Modbus, ILSA (Internal LSA protocol, OPC-Client, Automation CFC)
- Licensing
- Licensing With Feature Enabler
- IEC 61850 Services in IEDs and SICAM PAS
- SICAM PAS Configuration (Working with Project Databases, Creating a New Database, Adding and Managing Systems, Adding an Application (IEC 61850 Client), Importing a SCD file, Updating One or Several Device(s), Adding ModbusApplication, Parameterizing ModbusApplication, Added EMA90 ModbusMap, Defining the Device Template (ModbusMap), Adding IEC 60870-5-101 Slave Application, Inserting the Control Center of IEC 60870-5-101 Slave, Inserting the SNMP Application, Monitoring IEC 61850 IEDs Connection Status With SNMP, Inserting a PASCC Application to Full Server System, Inserting Control Center to PASCC Application, Inserting a PASCC to a New System (DIP)
- Creating a CFC file
- Human-Machine Control Center Mapping, Exporting of HMI1 Interface
- Normalization
- Create a Normalization Template
- Scaling a measured value
- Assignment of normalization in Mapping
- Archiving Configured Project, Un-archiving Project
- SICAM PAS Value Viewer
- Control function
- Testing data
- ValueViewer: Communication diagnostics
Module IV: SICAM SCC
- Export of HMI information from SICAM PAS
- Check the content of a PXD file
- Introduction to SICAM PASCC Control Center
- SICAM PASCC Control Center ‐ Overview
- SIMATIC WinCC
- SICAM PASCC Components
- SICAM PASCC Communication
- SICAM PAS Wizard
- WinCC Explorer
- Graphic Objects Library
- Switchgear Objects
- Schwitchgear Objects – Styles and States
- Alarm Logging – Message List
- Control & Monitoring
- WinCC & PASCC Licensing
- SIMATIC WinCC / SICAM PASCC Installation Steps
- Transfer The License Keys
- SIMATIC WinCC / SICAM PASCC Time Synchronization & NTP
- SICAM PASCC Starting The WinCC/PASCC Software
- SICAM PASCC Creating/ Opening a New Project
- SICAM PASCC Defining The Computer Properties General Tab, Startup Tab, Parameters Tab, Graphics Runtime Tab
- Adding a Communication Driver
- Connection Properties
- Entering the IP Address of SICAM PAS Servers
- Error Log File of SICAM PAS Wizard
- Select the Right SICAM PAS Protocol Suite
- Set PAS IP Connection
- Importing of the Sample Pilot Project .pxd File
- Checking Structure Tags of a New Project
- Structure Tag Elements
- Symbol Library
- SICAM Administrative Internal Tags
- Schwitchgear Objects – Tag Connection
- Design of Graphical Objects
- Switchgear Objects – Sychro-Check
- Alarm Logging – Events & Alarms
- Alarm Logging – Message Queue & Mes Ack Tags
- Tag Logging – Measured Values
- WinCC Horn Tools– Sound File
- Tag Logging – Archive Configuration
- Trends Picture
- Topological coloring
- Event List
- Alarm List
- Protection Message List
- Horn, Alarm Acknowledgment
- Creating an Event List in the Graphics Designer
- User Administrator
- Login via button
- Report Designer – Print Job
- Project Archive, Duplicator
- Bay Blocking
- SIEMENS 7UT6X RELAY SETTING
SIEMENS 7UT6X DIFFERENTIAL SLOPE CURVE
SIEMENS 7UT6X SLOPE POINTS CALCULATION
SIEMENS 7UT6X PROTECTING TRANSFORMERS FROM INTERNAL FAULTS
SIEMENS 7UT6X VECTOR GROUP COMPENSATION / CORRECTION FACTOR - SIEMENS 7UT8X RELAY SETTING
SIEMENS 7UT8X DIFFERENTIAL SLOPE CURVE
SIEMENS 7UT8X SLOPE POINTS CALCULATION
SIEMENS 7UT8X PROTECTING TRANSFORMERS FROM INTERNAL FAULTS
SIEMENS 7UT8X VECTOR GROUP COMPENSATION / CORRECTION FACTOR - MICOM P6XX RELAY SETTING
MICOM P6XX DIFFERENTIAL SLOPE CURVE
MICOM P6XX SLOPE POINTS CALCULATION
MICOM P6XX PROTECTING TRANSFORMERS FROM INTERNAL FAULTS
MICOM P6XX VECTOR GROUP COMPENSATION / CORRECTION FACTOR - ABB RET615 RELAY SETTING
ABB RET615 DIFFERENTIAL SLOPE CURVE
ABB RET615 SLOPE POINTS CALCULATION
ABB RET615 PROTECTING TRANSFORMERS FROM INTERNAL FAULTS
ABB RET615 VECTOR GROUP COMPENSATION / CORRECTION FACTOR
The Transformer Protection Training training course explains how the Differential protection algorithm works.
- Pre-recorded videos with lifetime access
- Trainer: Dr. Saeed Roostaee (Profile)
- Course creation: April 2024
- Last update: April 2024
Prerequisite:
Course Content:
- Pre-recorded videos with lifetime access
- Trainer: Dr. Saeed Roostaee (Profile)
- Course creation: April 2024
- Last update: April 2024
Prerequisite:
