A general presentation on IEC 61850 application to substation automation.
Describes Data Semantics, communication services and the substation configuration language
IEC-61850 defines standards for communication in substations. It includes a data model for logical nodes and common data classes. The communication model uses MMS and ACSI for configuration/maintenance, with GOOSE and GSSE for fast transmission of status events. Sampled values can be transmitted via multicast or unicast. IEC-61850-compliant Ethernet switches support functions like GOOSE messaging with low latency. Serial device servers provide an opportunity to connect legacy serial devices and map their protocols to IEC-61850.
Overview Of I E C61850 Presentation..... W S Mginquesada
This document provides an overview of IEC 61850 and its benefits. IEC 61850 is a framework for substation automation that standardizes object models, data meanings, services, and device configurations. This standardization allows devices from different vendors to interoperate and reduces engineering and configuration costs. The benefits of IEC 61850 include lower installation, maintenance, wiring, and commissioning costs through the use of self-describing devices and a common configuration language.
The document discusses the IEC 61850 standard for substation automation. It describes the key requirements for communication systems in substations, including high-speed device communication, networkability, availability, and support for functions like file transfer. It then explains the use of Ethernet and serial-based networks in substations and discusses communication protocols. A key aspect of IEC 61850 is that it provides a model for how devices should organize data in a consistent way across all device types and brands. IEC 61850 also enables the introduction of process bus networks that connect merging units and sensors directly into the communication infrastructure.
1. Faults on 11kV or 33kV power lines can be caused by conductors clashing in wind, breakdown of conductors, tree branches falling, animals or birds, careless drivers, lightning strikes, insulator cracks, or operating errors.
2. Faults can result in damage to equipment from short circuits, fire hazards, loss of system stability and blackouts, and interruption of power to consumers causing revenue loss.
3. Protective relays automatically detect faults and cause circuit breakers to isolate faulty elements to protect the system and may alert operators. Common relays used include overcurrent, earth fault, and differential relays.
This document describes the new compact CPUs that supplement the S7-300 small control system. It provides an overview of the different CPU models, their specifications and onboard I/O, counting, communication, and memory capabilities. The compact CPUs offer a low-cost control solution for automation applications with integral analog and digital I/O, counting, PWM, basic motion control, and MPI or PROFIBUS DP communications without additional hardware.
This document discusses approaches and best practices for substation integration and automation. It provides an overview of system architecture, communication protocols, and a utility case study. The key points are:
- There are different levels of integration, from individual IED implementation to full substation automation and connection to the utility enterprise.
- Protocols like DNP3 and IEC 61850 are important for allowing devices from different vendors to communicate. Care must be taken that devices support the same protocols and versions.
- A case study of Omaha Public Power District's project demonstrates integrating IEDs using the IEC 61850 protocol over Ethernet networks for two substations and a training simulator.
This document provides an overview of motor control centers, including:
1. Motor control centers centralize control of multiple motors from a single location for convenience and efficiency.
2. Siemens TIASTAR motor control centers offer innovative features and advantages like easier installation and future modifications.
3. Power supplies provide three-phase voltage to motor control centers from large generators through complex distribution systems.
A general presentation on IEC 61850 application to substation automation.
Describes Data Semantics, communication services and the substation configuration language
IEC-61850 defines standards for communication in substations. It includes a data model for logical nodes and common data classes. The communication model uses MMS and ACSI for configuration/maintenance, with GOOSE and GSSE for fast transmission of status events. Sampled values can be transmitted via multicast or unicast. IEC-61850-compliant Ethernet switches support functions like GOOSE messaging with low latency. Serial device servers provide an opportunity to connect legacy serial devices and map their protocols to IEC-61850.
Overview Of I E C61850 Presentation..... W S Mginquesada
This document provides an overview of IEC 61850 and its benefits. IEC 61850 is a framework for substation automation that standardizes object models, data meanings, services, and device configurations. This standardization allows devices from different vendors to interoperate and reduces engineering and configuration costs. The benefits of IEC 61850 include lower installation, maintenance, wiring, and commissioning costs through the use of self-describing devices and a common configuration language.
The document discusses the IEC 61850 standard for substation automation. It describes the key requirements for communication systems in substations, including high-speed device communication, networkability, availability, and support for functions like file transfer. It then explains the use of Ethernet and serial-based networks in substations and discusses communication protocols. A key aspect of IEC 61850 is that it provides a model for how devices should organize data in a consistent way across all device types and brands. IEC 61850 also enables the introduction of process bus networks that connect merging units and sensors directly into the communication infrastructure.
1. Faults on 11kV or 33kV power lines can be caused by conductors clashing in wind, breakdown of conductors, tree branches falling, animals or birds, careless drivers, lightning strikes, insulator cracks, or operating errors.
2. Faults can result in damage to equipment from short circuits, fire hazards, loss of system stability and blackouts, and interruption of power to consumers causing revenue loss.
3. Protective relays automatically detect faults and cause circuit breakers to isolate faulty elements to protect the system and may alert operators. Common relays used include overcurrent, earth fault, and differential relays.
This document describes the new compact CPUs that supplement the S7-300 small control system. It provides an overview of the different CPU models, their specifications and onboard I/O, counting, communication, and memory capabilities. The compact CPUs offer a low-cost control solution for automation applications with integral analog and digital I/O, counting, PWM, basic motion control, and MPI or PROFIBUS DP communications without additional hardware.
This document discusses approaches and best practices for substation integration and automation. It provides an overview of system architecture, communication protocols, and a utility case study. The key points are:
- There are different levels of integration, from individual IED implementation to full substation automation and connection to the utility enterprise.
- Protocols like DNP3 and IEC 61850 are important for allowing devices from different vendors to communicate. Care must be taken that devices support the same protocols and versions.
- A case study of Omaha Public Power District's project demonstrates integrating IEDs using the IEC 61850 protocol over Ethernet networks for two substations and a training simulator.
This document provides an overview of motor control centers, including:
1. Motor control centers centralize control of multiple motors from a single location for convenience and efficiency.
2. Siemens TIASTAR motor control centers offer innovative features and advantages like easier installation and future modifications.
3. Power supplies provide three-phase voltage to motor control centers from large generators through complex distribution systems.
Power line carrier communication (PLCC) allows data transmission over existing power lines. It developed from early 20th century power companies using telephone lines for operational communications. A PLCC system includes terminals, coupling equipment, and power transmission lines. Coupling equipment includes line traps to block power frequencies while allowing carrier signals, and coupling capacitors for physical coupling between transmission lines and terminals. Line tuners match impedances between the PLC terminal and power line. PLCC provides communication without additional wiring and can transmit between substations over power lines.
This document discusses power distribution substation automation using a SCADA system. It defines substation automation as automatically controlling the power system via monitoring with SCADA and intelligent electronic devices. The SCADA system gathers operational information from substations through RTUs and microwave links to monitor and control the distribution network from a central location. It provides benefits like improved reliability and reduced costs but also has limitations like initial costs and security issues due to using open network protocols.
The PSTN is a network that connects customer equipment together through lines, trunks, and switches to allow communication. It has four major elements: customer premises equipment, the access system, transport, and signaling. The access system provides the wiring that connects customer equipment to the central network, including lines and trunks. It terminates at central office equipment. The transport component transmits signals through the core of the network using various transmission speeds and media between switches. A cellular call placed to a landline passes through the radio access network, mobile switching office, and the PSTN using its lines, trunks, and switches to connect the calls.
ETAP - Short circuit analysis iec standardHimmelstern
The document discusses short-circuit analysis based on the IEC standard. It describes the purpose of short-circuit studies including verifying protective device ratings and settings. The types of short-circuit faults covered include three-phase, phase-to-phase, and phase-to-ground faults. The IEC method for calculating short-circuit currents is explained including initial, peak, and steady-state currents. Considerations for near-generator and far-from-generator faults are also covered.
This document discusses the cyber security risks of smart grids and proposes an integrated security framework to address these risks. Smart grids integrate information infrastructure with electrical infrastructure, improving performance but also increasing vulnerability to cyber attacks. The framework features security agents, managed security switches, and a security manager to provide layered protection, intrusion detection, and access control across the power automation network in a scalable and extensible manner. This integrated approach is needed as power systems have different security needs than traditional IT networks.
Scada Industrial Control Systems Penetration Testing Yehia Mamdouh
Scada Industrial Control Systems Penetration Testing
Start from Types of Scada Networks, then Penetration testing, finally what Security should be follow
This Presentation is about l.v switch gear design, presented during the graduation project final discussion 15/7/2018.
It presented a good summary of switch gear components and types and practicing on AL.HAMOOL W.T.P M.D.B design using SIEMENS SIVACON S8
SCADA systems gather data from widely distributed processes and provide limited control capabilities over distant facilities. They consist of field instruments that collect data and control loops that regulate processes. Remote Terminal Units (RTUs) gather information from field devices and send it to a Master Terminal Unit (MTU) via communications networks. The MTU allows operators to monitor and control the system through a human-machine interface. SCADA systems are used to supervise critical infrastructure like pipelines and power grids over large areas.
This document discusses cyber security issues in smart grids. It begins with an introduction to smart grids and their reliance on information and communication technologies. It then discusses three key security objectives for smart grids: data availability, confidentiality, and integrity. Several types of cyber attacks on smart grids are described, including denial-of-service attacks, random attacks, and false data injection attacks. The document concludes by evaluating techniques for detecting attacks, such as using chi-square tests and cosine similarity matching to compare expected and measured smart grid data.
Cause: A software defect in a control room.
Restoration: Some customers after 6 hours, some after 2 days, some remote places after nearly a week.
Consequences (among other):
•45M people in 8 US states
•10M people in Canada
•Healthcare facilities experienced $100M lost revenue
•6 hospitals bankrupt one year after
The document is a report summarizing Shuvam Pathania's industrial training at the 220/132/33 KV Grid Sub Station in Jassure. It includes an acknowledgements section thanking those who contributed, a certificate of completion, and a contents listing the topics covered in the report such as the functions of a substation, elements of a substation like circuit breakers and transformers, and an overview of the Jassure Substation.
The document provides details on WCDMA, including:
- WCDMA has two modes - FDD and TDD, characterized by duplex method. The chip rate is 3.84 Mcps.
- Spreading factors range from 256 to 4 in the uplink and from 512 to 4 in the downlink, allowing variable symbol rates. OVSF codes are used for channelization and Gold codes are used for cell/user separation.
- Modulation is QPSK. Carrier spacing can vary from 4.2 to 5.4 MHz. Larger spacing is used between operators to avoid interference.
The document provides an erection sequence for a 400kV GIS substation. It outlines the step-by-step process for assembling and installing the various components of the substation, including unpacking GIS carts, aligning circuit breakers, erecting current transformers and disconnectors, assembling walkway platforms, installing internal and main buses, erecting bus ducts and supports, testing and filling circuit breakers with SF6 gas, installing gas insulated buses, erecting bushing, line traps, and testing equipment. The sequence shows the substation being fully assembled and tested over numerous steps.
This document discusses supervisory control and data acquisition (SCADA) systems. SCADA systems are used to monitor and control industrial processes and infrastructure by collecting data from remote field devices and sensors. The document outlines the key components and functions of SCADA, including data acquisition, communication between remote terminal units and the central control system, data presentation to operators, and remote control capabilities. Examples are given of SCADA applications in various industries such as water distribution, manufacturing, oil and gas, and railways.
The substation is the part of a power system in which the voltage is transformed from high to low or low to high for transmission, distribution, transformation, and switching..etc
The document discusses relay coordination and grading methods for protective relays in power systems. It describes various coordination techniques including current grading, time grading, and a combination of time and current grading using inverse definite minimum time (IDMT) characteristics. The key aspects covered are:
1) Current grading sets relays closer to the power source to operate at higher fault currents. Time grading sets relays to operate at progressively longer times closer to the source.
2) IDMT coordination uses inverse-time overcurrent relays set to different time multiples and pickup currents to achieve coordination over a wide range of fault levels.
3) Proper coordination requires isolating the faulty section, preventing tripping of healthy equipment, and
This document provides an overview of the key components of a 132kV substation, including: circuit breakers, protective relays, lightning arresters, bus bars, switches, the control room, transformers, power line carrier communication (PLCC), and remote terminal units (RTU). It describes the basic functions of these components in powering homes and businesses safely and efficiently.
Power system automation refers to using instrumentation and control (I&C) devices to perform automatic decision making and control of the power system. Data is acquired from devices throughout the system and used for supervision and control by operators, engineers and automated processes. Intelligent electronic devices (IEDs) like remote terminal units, meters, and protective relays incorporate microprocessors to process and communicate data to monitor, control and protect the power system.
Cables are often the last component considered during system design even if in many situations cables are the true system’s lifeline: if a cable fails, the entire system may stop. Cable reliability is therefore extremely important, then a cable system should be engineered to last the life of the system in the installation environment for the required application. Environments in which cable systems are being used are often challenging, as extreme temperatures, chemicals, abrasion, and extensive flexing. These variables have a direct impact on the materials used for cable insulation and jacketing as well as the construction of the cable. Using a systematic approach will help ensure that designer select the best cable for the required application in the installation environment. This lessons will provide students main guidelines for perform this approach.
Ema best practices_for_utilizing_network_monitoring_switches_in_cisco_environ...Anand Raj
This document discusses best practices for utilizing network monitoring switches in Cisco environments. It describes how network monitoring switches can help address limitations of Cisco's SPAN port mirroring functionality, such as port limits and packet duplication. It also explains how network monitoring switches can help with monitoring virtualized and high-density computing environments that incorporate Cisco technologies like Nexus switches, Fabric Extenders, and VN-Link encapsulation. Specifically, it outlines how the Ixia Anue Net Tool Optimizer network monitoring switch can collect, filter, and distribute packet streams to multiple monitoring tools while addressing challenges in Cisco-based networks.
QLogic and Oracle have partnered for over 18 years to deliver storage and networking solutions for Oracle customers. QLogic provides Fibre Channel and converged networking adapters, switches, and silicon that are qualified with Oracle products. Their current focus areas include driving adoption of 8Gb Fibre Channel, delivering converged networking adapters through their FCoE technology, and expanding their InfiniBand networking solutions. QLogic resources are available to Oracle customers to assist with solution design, deployment, and support of QLogic products.
Power line carrier communication (PLCC) allows data transmission over existing power lines. It developed from early 20th century power companies using telephone lines for operational communications. A PLCC system includes terminals, coupling equipment, and power transmission lines. Coupling equipment includes line traps to block power frequencies while allowing carrier signals, and coupling capacitors for physical coupling between transmission lines and terminals. Line tuners match impedances between the PLC terminal and power line. PLCC provides communication without additional wiring and can transmit between substations over power lines.
This document discusses power distribution substation automation using a SCADA system. It defines substation automation as automatically controlling the power system via monitoring with SCADA and intelligent electronic devices. The SCADA system gathers operational information from substations through RTUs and microwave links to monitor and control the distribution network from a central location. It provides benefits like improved reliability and reduced costs but also has limitations like initial costs and security issues due to using open network protocols.
The PSTN is a network that connects customer equipment together through lines, trunks, and switches to allow communication. It has four major elements: customer premises equipment, the access system, transport, and signaling. The access system provides the wiring that connects customer equipment to the central network, including lines and trunks. It terminates at central office equipment. The transport component transmits signals through the core of the network using various transmission speeds and media between switches. A cellular call placed to a landline passes through the radio access network, mobile switching office, and the PSTN using its lines, trunks, and switches to connect the calls.
ETAP - Short circuit analysis iec standardHimmelstern
The document discusses short-circuit analysis based on the IEC standard. It describes the purpose of short-circuit studies including verifying protective device ratings and settings. The types of short-circuit faults covered include three-phase, phase-to-phase, and phase-to-ground faults. The IEC method for calculating short-circuit currents is explained including initial, peak, and steady-state currents. Considerations for near-generator and far-from-generator faults are also covered.
This document discusses the cyber security risks of smart grids and proposes an integrated security framework to address these risks. Smart grids integrate information infrastructure with electrical infrastructure, improving performance but also increasing vulnerability to cyber attacks. The framework features security agents, managed security switches, and a security manager to provide layered protection, intrusion detection, and access control across the power automation network in a scalable and extensible manner. This integrated approach is needed as power systems have different security needs than traditional IT networks.
Scada Industrial Control Systems Penetration Testing Yehia Mamdouh
Scada Industrial Control Systems Penetration Testing
Start from Types of Scada Networks, then Penetration testing, finally what Security should be follow
This Presentation is about l.v switch gear design, presented during the graduation project final discussion 15/7/2018.
It presented a good summary of switch gear components and types and practicing on AL.HAMOOL W.T.P M.D.B design using SIEMENS SIVACON S8
SCADA systems gather data from widely distributed processes and provide limited control capabilities over distant facilities. They consist of field instruments that collect data and control loops that regulate processes. Remote Terminal Units (RTUs) gather information from field devices and send it to a Master Terminal Unit (MTU) via communications networks. The MTU allows operators to monitor and control the system through a human-machine interface. SCADA systems are used to supervise critical infrastructure like pipelines and power grids over large areas.
This document discusses cyber security issues in smart grids. It begins with an introduction to smart grids and their reliance on information and communication technologies. It then discusses three key security objectives for smart grids: data availability, confidentiality, and integrity. Several types of cyber attacks on smart grids are described, including denial-of-service attacks, random attacks, and false data injection attacks. The document concludes by evaluating techniques for detecting attacks, such as using chi-square tests and cosine similarity matching to compare expected and measured smart grid data.
Cause: A software defect in a control room.
Restoration: Some customers after 6 hours, some after 2 days, some remote places after nearly a week.
Consequences (among other):
•45M people in 8 US states
•10M people in Canada
•Healthcare facilities experienced $100M lost revenue
•6 hospitals bankrupt one year after
The document is a report summarizing Shuvam Pathania's industrial training at the 220/132/33 KV Grid Sub Station in Jassure. It includes an acknowledgements section thanking those who contributed, a certificate of completion, and a contents listing the topics covered in the report such as the functions of a substation, elements of a substation like circuit breakers and transformers, and an overview of the Jassure Substation.
The document provides details on WCDMA, including:
- WCDMA has two modes - FDD and TDD, characterized by duplex method. The chip rate is 3.84 Mcps.
- Spreading factors range from 256 to 4 in the uplink and from 512 to 4 in the downlink, allowing variable symbol rates. OVSF codes are used for channelization and Gold codes are used for cell/user separation.
- Modulation is QPSK. Carrier spacing can vary from 4.2 to 5.4 MHz. Larger spacing is used between operators to avoid interference.
The document provides an erection sequence for a 400kV GIS substation. It outlines the step-by-step process for assembling and installing the various components of the substation, including unpacking GIS carts, aligning circuit breakers, erecting current transformers and disconnectors, assembling walkway platforms, installing internal and main buses, erecting bus ducts and supports, testing and filling circuit breakers with SF6 gas, installing gas insulated buses, erecting bushing, line traps, and testing equipment. The sequence shows the substation being fully assembled and tested over numerous steps.
This document discusses supervisory control and data acquisition (SCADA) systems. SCADA systems are used to monitor and control industrial processes and infrastructure by collecting data from remote field devices and sensors. The document outlines the key components and functions of SCADA, including data acquisition, communication between remote terminal units and the central control system, data presentation to operators, and remote control capabilities. Examples are given of SCADA applications in various industries such as water distribution, manufacturing, oil and gas, and railways.
The substation is the part of a power system in which the voltage is transformed from high to low or low to high for transmission, distribution, transformation, and switching..etc
The document discusses relay coordination and grading methods for protective relays in power systems. It describes various coordination techniques including current grading, time grading, and a combination of time and current grading using inverse definite minimum time (IDMT) characteristics. The key aspects covered are:
1) Current grading sets relays closer to the power source to operate at higher fault currents. Time grading sets relays to operate at progressively longer times closer to the source.
2) IDMT coordination uses inverse-time overcurrent relays set to different time multiples and pickup currents to achieve coordination over a wide range of fault levels.
3) Proper coordination requires isolating the faulty section, preventing tripping of healthy equipment, and
This document provides an overview of the key components of a 132kV substation, including: circuit breakers, protective relays, lightning arresters, bus bars, switches, the control room, transformers, power line carrier communication (PLCC), and remote terminal units (RTU). It describes the basic functions of these components in powering homes and businesses safely and efficiently.
Power system automation refers to using instrumentation and control (I&C) devices to perform automatic decision making and control of the power system. Data is acquired from devices throughout the system and used for supervision and control by operators, engineers and automated processes. Intelligent electronic devices (IEDs) like remote terminal units, meters, and protective relays incorporate microprocessors to process and communicate data to monitor, control and protect the power system.
Cables are often the last component considered during system design even if in many situations cables are the true system’s lifeline: if a cable fails, the entire system may stop. Cable reliability is therefore extremely important, then a cable system should be engineered to last the life of the system in the installation environment for the required application. Environments in which cable systems are being used are often challenging, as extreme temperatures, chemicals, abrasion, and extensive flexing. These variables have a direct impact on the materials used for cable insulation and jacketing as well as the construction of the cable. Using a systematic approach will help ensure that designer select the best cable for the required application in the installation environment. This lessons will provide students main guidelines for perform this approach.
Ema best practices_for_utilizing_network_monitoring_switches_in_cisco_environ...Anand Raj
This document discusses best practices for utilizing network monitoring switches in Cisco environments. It describes how network monitoring switches can help address limitations of Cisco's SPAN port mirroring functionality, such as port limits and packet duplication. It also explains how network monitoring switches can help with monitoring virtualized and high-density computing environments that incorporate Cisco technologies like Nexus switches, Fabric Extenders, and VN-Link encapsulation. Specifically, it outlines how the Ixia Anue Net Tool Optimizer network monitoring switch can collect, filter, and distribute packet streams to multiple monitoring tools while addressing challenges in Cisco-based networks.
QLogic and Oracle have partnered for over 18 years to deliver storage and networking solutions for Oracle customers. QLogic provides Fibre Channel and converged networking adapters, switches, and silicon that are qualified with Oracle products. Their current focus areas include driving adoption of 8Gb Fibre Channel, delivering converged networking adapters through their FCoE technology, and expanding their InfiniBand networking solutions. QLogic resources are available to Oracle customers to assist with solution design, deployment, and support of QLogic products.
Cisco Connect Halifax 2018 Cisco dna - deeper diveCisco Canada
This document provides a summary of a session on Cisco's Digital Network Architecture. The session discusses how Cisco's latest advances in programmable ASIC hardware and software-defined technologies are driving innovations in their Catalyst 9000 switches and solutions like Encrypted Traffic Analytics and Software-Defined Access. It outlines how the session will provide insight into Cisco's ASIC design process and the capabilities of their latest switching silicon. The session aims to show Cisco's evolution from application-specific integrated circuits to advanced graphical user interfaces that enable customers to more quickly innovate and reduce costs with solutions enabled by their Digital Network Architecture.
This document discusses trends in high performance computing (HPC) and big data analytics. It notes that while HPC and big data have different resource needs and programming models traditionally, they are converging as big data workloads require more real-time processing and HPC workloads incorporate more data-driven analytics. The document outlines challenges in both HPC and big data such as system bottlenecks, energy efficiency, and barriers to wider usage. It advocates for more integrated solutions that combine storage, networking, processing and memory to address these challenges.
With the advent of SDN driven network programmability and abstraction, IT operations management is poised for a transformation to higher levels of agility and automation.
This document summarizes Paddy Power Betfair's private OpenStack cloud called i2. Key points:
1) i2 provides an extensible, scalable platform to host all development, test, and production applications on OpenStack. It uses software defined networking and automation to improve provisioning speed and flexibility.
2) Major technologies used include Red Hat OpenStack Platform, Arista switching, Nuage Networks SDN, Citrix load balancing, Pure Storage, and HP servers.
3) Benefits include faster provisioning, standard tooling, security, availability, scalability, and improved performance.
4) The approach included vendor selection, proof of concept, a production pilot, and migration of applications to
The document is a presentation on IEC 61850 given at the UCAIug Summit in Austin, TX on November 15, 2011. It provides an overview of IEC 61850 and related IEC standards including IEC 61970 CIM, IEC 62351 communications security, and how they work together. The presentation establishes guidelines for questions and discusses key concepts such as object models, logical nodes, common information models, profiles and how standards help achieve interoperability and integration.
Xavier van Ruymbeke, App. Engineer, Arterischiportal
This document discusses enhancing data reliability in data center flash storage controllers through network-on-chip (NoC) interconnect data protection features. It describes the increasing complexity of flash controller designs, which raises the probability of on-chip errors. Implementing data protection directly in the NoC interconnect using techniques like parity checking, error correction codes, and logic duplication can help make the system more reliable compared to software-only solutions. The document provides examples of different data protection techniques that can be applied to transaction payloads, packet headers, and ARM Cortex cores to safeguard data as it travels across the on-chip network.
STRATEGY FOR OPTIMIZED BMS SYSTEMS - 800V EV BATTERY ARCHITECTUREiQHub
NXP is a global semiconductor company with over 31,000 employees specializing in secure connections for a smarter world. The document discusses challenges for battery management systems (BMS) in shifting to 800V systems, such as increased complexity and functional safety risks. It presents NXP's solutions that support 800V systems while meeting functional safety goals through techniques like independent cell voltage measurements that meet ISO 26262 ASIL D requirements. NXP's novel MC33665 BMS gateway is highlighted as supporting various battery architectures with synchronous measurements without losing bandwidth.
The document discusses data interoperability challenges in the aerospace and defense industry. It finds that:
- Data exchange takes place less than 50% of the time seamlessly between suppliers and customers due to different tools and formats used.
- Manual interpretation is still the dominant method for "translating" data between systems.
- Improved interoperability through standards like STEP and PLCS could provide significant benefits, according to respondents, but investment in interoperability is currently minimal.
This document summarizes Academia Sinica Computing Centre's experience transitioning their network to support IPv6. It discusses upgrading their backbone routers to support IPv6, developing an IPv6 addressing plan and allocating address space. It also covers transitioning customer networks, managing and monitoring IPv6 traffic and services, and security considerations. It provides an overview of Academia Sinica's IPv6 network status, including their participation in the 6bone test network and running a multicast testbed.
The document discusses building a resilient unified communications network with an integrated approach to high availability, security, and quality of service. It recommends a network design that leverages modular platforms to dynamically configure endpoints for proper power, VLANs, security, QoS, and registration. An optimal unified communications network requires high availability, quality of service, and embedded security features to be implemented consistently across the network infrastructure.
The document discusses Cisco's Hadoop as a service offering on their Intercloud platform. Some key points:
- Cisco provides managed Hadoop, including Cloudera's distribution, on optimized instances with local storage and object storage. This offers a scalable, reliable, and secure environment for Hadoop workloads.
- Use cases discussed include predictive maintenance using IoT data and analyzing customer journeys across multiple channels.
- A pilot test showed Cisco's platform could process over 100 million records from production data across various Hadoop jobs.
- Cisco also discusses their data virtualization product CiscoDV, which can integrate data across on-premises, cloud sources on Cisco and AWS.
-
Addressing Issues of Risk & Governance in OpenStack without sacrificing Agili...OpenStack
Addressing Issues of Risk, and Governance in OpenStack without sacrificing Agility
Audience: Intermediate
Topic: Public & Hybrid Clouds
Abstract: OpenStack has rapidly moved beyond the “science project” label that many of its detractors’ use, but for many stakeholders there are still many uncertainties around governance, compliance, data security and data retention. These issues are the biggest inhibitors to adoption of any cloud technology and left unanswered will slow down the adoption of OpenStack, particularly within government and highly regulated industries such as healthcare. In this presentation NetApp outlines a hybrid approach that leverages the best of open-source and next generation technologies within an OpenStack deployment, as well as a way of unifying data management across OpenStack, HyperScale public cloud and traditional Enterprise architecture that addresses these questions while providing a solid platform for rapid innovation.
Speaker Bio: John Martin, NetApp
John Martin is NetApp’s Director of Strategy and Technology, working as part of the Office of the CTO. Based in Sydney, John is responsible for developing and advocating NetApp’s flash portfolio across the APAC region.
John is one of the driving forces behind NetApp’s continued expansion into flash and works closely with field sales, the channel and alliance technology partners to provide innovative solutions that solve customer business challenges.
While John is NetApp’s flash champion, he continues to provide technology insights and market intelligence to trends that impacts both NetApp and its customers.
Prior to his current role, John was NetApp’s ANZ’s principal technologist for over six years and has over 20 years experience working in the IT industry.
John joined NetApp in 2006 as a systems engineer. Prior to this, he was a principal of GRID IT, where he built relationships with a variety of major storage vendors while also helping to start two storage-related businesses. At GRID IT, John was involved in senior pre-sales, consulting and training for Legato, Veritas, and StorageTek.
In his spare time, John enjoys singing, writing and cooking. He also spends time researching modernist and post modernist philosophy, ancient history, social justice and global development.
OpenStack Australia Day Government - Canberra 2016
https://events.aptira.com/openstack-australia-day-canberra-2016/
Cisco products and solutions enable Industrial IT – convergence
of information technology (IT) and operational technology (OT).
This discussion reviews the Cisco solutions within the Cisco and
Rockwell Automation CPwE architectures, including the Catalyst
family of switches and Adaptive Security Appliance (ASA)
firewalls. Prior attendance of the NS05 - Building Converged
Plantwide Ethernet Architectures session is recommended.
Deep dive into the new Cisco Catalyst 6840-X Series Switch and see how it delivers more for less with up to 40 high-density 10G ports plus 40G native uplinks in a compact 2-rack (2RU) form factor that fits both tight spaces and limited IT budgets.
Miss the webcast? View the replay>> http://cs.co/9002ByM1i
The document discusses digital transformation trends and Cisco's next generation networking products. It covers topics like mobility, BYOD, IoT, and virtualization trends influencing IT. It then summarizes Cisco's switching and routing portfolio for access, aggregation, and core networks. This includes product lines for wired and wireless access, data center/virtualization, and IoT.
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5. Is 61850 a protocol, a standard, or what?
Framework for interoperability
Substation Data Model
Suite of communication protocols
Defines performance in harsh environments
Ethernet based
www.casco-systems.comApril 11, 2016
9. What were the Lessons Learned?
EXPERIENCE WITH IEC-61850
www.casco-systems.comApril 11, 2016
10. Hardware design can be greatly simplified.
Software design complexity is significantly increased.
Network design is critical.
What design resources are needed?
www.casco-systems.comApril 11, 2016
12. That depends on vendor implementation.
Examples:
GOOSE Message Failure Indication from SEL-421:
S99_21LA.ANN.ASVGGIO4.Ind07 = S99_21LA_GSE_FAIL
GOOSE Message Failure Indication from GE-L90:
S99_87LB.GEN.GGIO1.Ind6 = S99_87LB_GSE_FAIL
Is 61850 self-documenting?
www.casco-systems.comApril 11, 2016
13. DNP Obj 30, Var 1, Index 3
Modbus Coil 10003
IEC-61850 Relay1/XCBR1$Health$stVal
Status Value
Health
Circuit Breaker
Logical Device
Protocol Naming Conventions
www.casco-systems.comApril 11, 2016
14. No
MPRP used IEC-61850 equipment from multiple vendors:
• GE Proficy Driver Server w/ CIMPLICITY HMI
• SEL RealTime Automation Controller
• SEL 400 & 487 Series Protective Relays
• SEL 2411 Programmable Automation Controller
• GE Multilin UR Protective Relays
• Qualitrol Intelligent transformer monitor
• Beckwith DigitalTapchangerControl
• CalistoGas Monitor
• MESA Battery Charger
Is vendor interoperability easy and are
all 61850 IED’s interoperable?
www.casco-systems.comApril 11, 2016
15. PRODUCT FAMILY EXAMPLE BINARY POINT
SEL 400 Series Relays
KT1H_11KA.ANN.PLTGGIO2.Ind17
SEL 487 Series Relays
T3_87TA.ANN.IN1GGIO14.Ind05
SEL 2411 PAC
T3_74TA_2.ANN.SVTGGIO4.Ind24
SEL 651R Recloser
L230D1_51LR.PRO.LOPPTUV1.Op
GE Multilin UR Relays
T3_87TB.GEN.GGIO1.Ind105
Qualitrol Intelligent Monitor
T3_23TA.Relay3.GGIO0.SPCSO1.status
CalistoGas Monitor
T3_99TA.LDev1.GGIO40.Ind_stVal
Example MMS binary point:
www.casco-systems.comApril 11, 2016
16. PRODUCT FAMILY EXAMPLE BINARY POINT
SEL 400 Series Relays
S49_21LA.MET.METMMXU1.TotW_instMag_f
SEL 487 Series Relays
T3_87TA.MET.METSMMXU1.TotW_instMag_f
SEL 651R Recloser
L230D1_51LR.MET.METMMXU1.TotW
GE Multilin UR Relays
T2_87TB.GEN.MMXU2.A.phsA
Qualitrol Intelligent Monitor
T3_23TA.In6MX.STMP0.Tmp
BeckwithTapchangerControl
M2001.D.ATCC0.LodCtrV_mag_i
Example MMS analog point:
www.casco-systems.comApril 11, 2016
17. More so than ever!
New types of documents are necessary.
Much of the hardwired complexity has moved to the software,
how will you document this?
Is documentation important?
www.casco-systems.comApril 11, 2016
21. SCADA & IED Data Maps
www.casco-systems.comApril 11, 2016
22. No
New skills are required
Additional functionality creates added complexity
Closely linking protection and integration functions via CID file
Added 61850 computing overhead requirements exposed
weaknesses in protective relay, RTU & HMI platforms.
Does 61850 make integration simpler?
www.casco-systems.comApril 11, 2016
23. Yes
Standardization of specific hardware platforms and firmware
Standardization of specific software versions
Added cost to track, evaluate and install upgrades
Is firmware & software control needed?
www.casco-systems.comApril 11, 2016
24. Not in all cases
Some data not available via communication interface
Other data needed to be remapped to make it available
Is all of the required data exposed?
www.casco-systems.comApril 11, 2016
29. Yes
Only way to ensure consistency
Only way to capture lessons learned
Only way to reduce costs through reuse
Are standards & examples necessary?
www.casco-systems.comApril 11, 2016
30. Is vendor support necessary?
Yes
Increasing vendor count adds complexity & integration issues
Vendor selection should include consideration of support
Key vendors for tools, RTU, & HMI must be willing to help with
problems encountered with 3rd party products
www.casco-systems.comApril 11, 2016
31. Yes on detailed design, hardware, and installation
No on relay and integration settings design & programming
No on network design, hardware and support
No on increased NERC/CIP compliance costs
Will we save money?
www.casco-systems.comApril 11, 2016
32. IEC-61850 is a multifaceted standard covering the full range of
communication services necessary for substation automation
While physical design needs decrease somewhat, virtual
design complexity increases dramatically
New documentation, tools, test beds, training, and vendor
support are keys to project success
Opportunity for costs reduction, in particular with GOOSE.
Opportunity for enhanced functionality and data collection.
Conclusion
www.casco-systems.comApril 11, 2016
Good morning and thank you for your interest in today’s presentation. My name is Kevin Mahoney, President and Integration Specialist at Casco Systems., the Control & Automation Solutions Company. For the past 15 years Casco’s team of engineering and integration specialist have worked extensively providing solutions to the power generation and transmission industry. Today we offer a range of services for protection, control, automation, integration and operational technology applications.
First I would like to thank our hosts from the University of Maine for the opportunity to be here today and our sponsors from the Maine IEEE & OMICRON for their generous support. Most importantly I would like to thank you, the attendees, for helping to make this a successful and informative event.
Like most of you here today our focus at Casco is on the power industry. We are excited by the prospect of employing technology in an intelligent way to address the industry’s need for advanced automation, protection, control and security solutions. Our topic for this conference, IEC-61850, is a technology that will enable the industry to provide more efficient, reliable and secure power delivery & production.
This morning I plan to share with you some of the lessons learned as Casco Systems developed a new automation & integration platform for Central Maine Power Company’s next generation substation. This journey began over six years ago when Casco was selected as the system integrator for the Maine Power Reliability Program (MPRP). Along with our associates at Relay Application Innovation, Burns & McDonnell and CMP’s Protection & Control Engineering Department; we were tasked with not only developing a platform with enhanced functionality, but also implementing new and evolving technology used to underpin the entire system. The core of this platform, as John Freeman explained, was based on the IEC-61850 standard which we will discuss, and Alex will review in detail later today.
The goal of my presentation is to review many of the “Lessons Learned” as we executed the design, programming and testing of 345/115kV bulk power substations for MPRP. To best illustrate the lessons learned, I will present a series of questions that were answered during the development, implementation and commissioning process. These questions and the corresponding answers embody the lessons learned over the course of this five year, $1.4B project; and subsequent projects that were constructed using the resulting reference design.
So what exactly is IEC-61850?
The following is a brief overview of the IEC-61850 standard which will be covered in greater detail by Alex later today.
In a complicated industry with many facets, it is useful to put 61850 and other standards into context. The IEC has developed a graphical overview of the more than 300 standards that apply to “Smart Grid” applications. This Reference Architecture may be found online at http://smartgridstandardsmap.com.
With this tool you are able to identify any given standard in relation to its role within the Smart Grid. The map defines the entire industry from generation through consumption on the horizontal axis, and from markets to field devices along the vertical.
The stated goal of this map is to allow users to “Easily and instantly identify the standards that are needed for any part of the Smart Grid – no need to be a standards expert”. While I question the later part of that statement, this graphic does a great job of defining the use cases each standard addresses and can be filtered to show the portions defined by 61850.
IEC-61850 is a communication and engineering standard for electrical substation automation systems. It defines a common set of features and functions that allow interoperability between different vendors and products.
This view of the reference architecture diagram filters out areas not directly impacted by 61850. As you can see the standard touches upon a wide cross section of the industry but is primarily focused on the Operation, Field, Station and Process levels.
So what exactly is IEC-61850? Is it a Modbus or DNP style communication protocol on steroids, a design standard, or something else altogether?
The first "Lesson Learned" was that IEC 61850 offers a complete set of specifications covering all communication issues inside a substation. The objective of the IEC group that developed and continues to enhance 61850 was to specify requirements and to create a framework necessary to achieve interoperability between IEDs designed by different suppliers. So the IEC-61850 standard is much more than just a communication protocol such as DNP3 or Modbus. IEC-61850 comprehensively defines the engineering process, data and service models, conformance testing, and the entire communication process within substations.
Included in the standard are a station data model and multiple messaging services to address the needs of different applications within a typical substation. In short, IEC-61850 is much more than a protocol. It is a standard that defines a communication approach for electrical substations which includes data modeling, a family of protocols, and associated performance requirements.
We’ll look at each of these aspects of IEC-61850 briefly and then review many of the Lessons Learned along the way.
NOTES ON IEC-61850 STANDARD UPDATES
Per the IEC website the most recent release of the standard is the IEC 61850:2016 SER series which has the following sections.
IEC TR 61850-1:2013
IEC TS 61850-2:2003
IEC 61850-3:2013
IEC 61850-4:2011
IEC 61850-5:2013
IEC 61850-6:2009
IEC 61850-7-1:2011
IEC 61850-7-2:2010
IEC 61850-7-3:2010
IEC 61850-7-4:2010
IEC 61850-7-410:2012+AMD1:2015 CSV
IEC 61850-7-420:2009
IEC TR 61850-7-510:2011
IEC 61850-8-1:2011
IEC 61850-9-2:2011
IEC PAS 61850-9-3:2015
IEC 61850-10:2012
IEC TS 61850-80-1:2008
IEC TR 61850-80-3:2015
IEC TS 61850-80-4:2016
IEC TR 61850-90-1:2010
IEC TR 61850-90-2:2016
IEC TR 61850-90-4:2013
IEC TR 61850-90-5:2012
IEC TR 61850-90-7:2013
IEC TR 61850-90-8:2016
IEC TR 61850-90-12:2015
Technical Specifications (TS) - Technical Specifications are often published when the subject under question is still under development or when insufficient consensus for approval of an International Standard is available. Technical Specifications approach International Standards in terms of detail and completeness, but have not yet passed through all approval stages either because consensus has not been reached or because standardization is seen to be premature.
Technical Reports (TR) - Technical Reports contain collected data of a kind different from that normally published as an International Standard, for example data obtained from a survey carried out among national committees, data of work in other international organizations or data on "the state of the art" in relation to standards of national committees on a particular subject.
A Publicly Available Specification (PAS) is a publication responding to an urgent market need, representing either a consensus in an organization (e.g. manufacturers or commercial associations, industrial consortia, user group and professional and scientific societies) external to the IEC or a consensus of experts within a working group.
Key features of IEC 61850 from the IEC website:
As in an actual project, the standard includes parts describing the requirements needed in substation communication, as well as parts describing the specification itself. The specification is structured as follows:
An object-oriented and application-specific data model focused on substation automation. This model includes object types representing nearly all existing equipment and functions in a substation – circuit breakers, protection functions, current and voltage transformers, waveform recordings, and many more.
Communication services providing multiple methods for information exchange. These services cover reporting and logging of events, control of switches and functions, polling of data model information.
Peer-to-peer communication for fast data exchange between the feeder level devices (protection devices and bay controller) is supported with GOOSE (Generic Object Oriented Substation Event).
Support of sampled value exchange.
File transfer for disturbance recordings.
Communication services to connect primary equipment such as instrument transducers to relays.
Decoupling of data model and communication services from specific communication technologies.
This technology independence guarantees long-term stability for the data model and opens up the possibility to switch over to successor communication technologies. Today, the standard uses Industrial Ethernet with the following significant features:
o 100 Mbit/s bandwidth
o Non-blocking switching technology
o Priority tagging for important messages
o Time synchronization of 1 ms
A common formal description code, which allows a standardized representation of a system’s data model and its links to communication services. This code, called SCL (Substation Configuration Description Language), covers all communication aspects according to IEC 61850. Based on XML, this code is an ideal electronic interchange format for configuration data.
A standardized conformance test that ensures interoperability between devices. Devices must pass multiple test cases: positive tests for correctly responding to stimulation telegrams, plus several negative tests for ignoring incorrect information.
IEC 61850 offers a complete set of specifications covering all communication issues inside a substation.
The Substation Data Model outlines a method for consistently defining data and attributes for any piece of equipment in the substation. The abstract data models defined in IEC 61850 can be mapped to any number of communication protocols.
As you can see from this graphic the Substation Data Model is used to represent real world, physical attributes of the substation in a virtual data structure. This data structure can then be easily mapped into various communication protocols and devices for consumption. While legacy protocols have typically defined how bytes are transmitted on the wire, they did not generally specify how data should be organized in devices in terms of the application.
This approach required engineers to manually configure objects and map them to variables and low-level register numbers, index numbers, I/O modules, etc. In this respect IEC-61850 is unique as in addition to the specification of the protocol elements (how bytes are transmitted on the wire), it provides a model for how power system devices should organize data in a manner that is consistent across all types and brands of devices. In theory this should eliminate much of the tedious system configuration effort because the devices can configure themselves and the data points are self-documenting.
The IEC 61850 device model begins with a physical device. A physical device is the device that connects to the communication network such as a protective relay or other IED. Within each physical device, there may be one or more logical devices. Each logical device contains one or more logical nodes. A logical node is a named group of data and associated services that is logically related to some power system function. For example there are logical nodes for protection, the names of which all begin with the letter “P”, logical nodes for metering and measurement, the names of which all begin with the letter “M”, and so on. In this way an entire power system can be represented in a abstract data model.
The abstract data models defined in IEC 61850 can be mapped to any number of protocols, including those defined in the standard. Current mappings in the standard include:
GOOSE (Generic Object Oriented Substation Event)
MMS (Manufacturing Message Specification)
SMV (Sampled Measured Values)
FTP (File Transfer Protocol)
HTTP (Web Services)
These protocols can run over TCP/IP networks using high speed switched Ethernet to obtain the response times appropriate for the application. This includes response times below four milliseconds necessary for protective relaying.
The transmission times specified in the requirements column of this table are the maximum times allowed for a data exchange through a communications system.
This term is vague but is usefully defined as the time duration between the action of communicating a value from the logic processing of one device to the logic processing within a second device as part of an application. As you can see the maximum times vary depending on the response requirements of a particular application.
So in summary IEC-61850 is a standard that defines a communication approach for electrical substations including data modeling, a family of protocols, and associated performance requirements.
So, what did we learn while applying IEC-61850 on multiple MPRP substations?
Our experience on MPRP showed that the nature of the design shifted complexity from the physical to virtual realms. While the hardware design was simplified the complexity of the network system and application software grew substantially. For example most “equipment to relay” and “relay to relay” interconnection wiring was eliminated, simplifying the hardware design, reducing cabling & component counts, and lowering installation costs.
However at the same time all of this functionality needed to be recreated in the virtual realm by the use of GOOSE messaging. IED settings now needed to incorporate messaging and logic to support the transfer of information and to allow for testing and maintenance features.
Of course with the Operational Technology Network (OT LAN) carrying this critical traffic, network design and redundancy became much more complex. The OT LAN must be fault tolerant with no single point of failure and guarantee performance to meet the <4ms response times dictated by the protection requirements.
An example of traditional, worse case hardwired implementations using cabling and serial connections is on the left. An advanced, 61850 based system is shown on the right. As you can see there are significant savings in wiring, components and complexity.
IEC-61850 is sometimes described as self-documenting. However a "Lesson Learned" from our experience is that while 61850 devices use human language naming conventions they are often far from intuitive or self documenting.
In general IEC-61850 names, while standardized, are not easy to use. And given that the standard allows each vendor latitude in naming, a wide variety of styles have been found. For example these two points represent the status of a GOOSE Message Failure indicating point in SEL-421 and GE-L90 relays. While the point means the same in both cases, the structure of the name is different depending on the vendor’s implementation.
That being said 61850 at least provides the framework within the standard for self-documenting naming conventions. Unlike legacy protocols that map data to indexes or addresses, 61850 allows vendors to select naming conventions suitable for the application.
In this example a single binary status point is mapped to DNP Object 30, Variation 1, Index 3; to Modbus Coil 10003, and to IEC-61850 variable name Relay1/XCBR1$Health$stVal.
The intent of the standard is that vendors will all use a common, standard naming convention. However to date many vendors have chosen to implement conventions that while meeting the standard’s technical requirements don’t achieve this goal.
While interoperability is the goal of 61850, it is far from assured or easy. Being a new protocol, the first edition of IEC 61850 had issues that each vendor solved differently, leading to more than a few interoperability issues. The second edition should solve that problem and lead to better vendor to vendor interoperability.
However even after adoption of the second edition, each vendor will be free to implement different subsets, meaning that interoperability will always be measured in degrees that need to validated. For utilities that are searching for exchangeability of IEDs from different vendors, much work remains to be done. It is possible to reach a level of system specification that will allow interoperability AND exchangeability of IEDs from multiple vendors! However to get there: You need to request something more than just "IEC 61850".
MPRP used IEC-61850 capable equipment from at least seven different vendors, each with their own unique implementation. Let’s explore some of the differences in naming conventions between them.
This table reflects binary status point naming conventions as implemented in various devices. While there are some similarities between names used in different devices there are also many differences. These inconsistencies make working with the software tools challenging for the human engineers and technicians who must use these tools!
This table reflects analog point naming conventions as implemented in various devices, in this case there are even greater variations.
Traditional documentation has shown to be insufficient for IEC 61850 applications and new forms need to be created to represent all features.
GOOSE MAPS:
With traditional documentation information on GOOSE messages would be scattered throughout multiple documents, different IED tools and specific descriptions. So, virtual wiring maps called "GOOSE Maps" were developed, with the information flow, sources, destinations, descriptions, addresses, etc, as shown. These documents associate the publishers and the subscribers, their messages, links and descriptions.
GOOSE MAPS:
With traditional documentation information on GOOSE messages would be scattered throughout multiple documents, different IED tools and specific descriptions. So, virtual wiring maps called "GOOSE Maps" were developed, with the information flow, sources, destinations, descriptions, addresses, etc, as shown. These documents associate the publishers and the subscribers, their messages, links and descriptions.
LOGIC DIAGRAMS:IED Logic Diagrams were developed to provide a graphical representation of the custom logic within each IED, as well as all real and virtual I/O points, LEDs’, etc. This is an invaluable tool for the design, commissioning and technical support staff working with these devices over their entire life cycle. While not unique to 61850 applications, the LD’s took on increasing importance as the relay’s logic escalated in complexity.
Memory Maps are critical to building the model of a particular relay or device. We learned that two types of maps where required.
SCADA MAPS: The first is the traditional SCADA map which defines all analog, status and control points provided to SCADA. This map was enhanced by providing additional information to aid in commissioning and troubleshooting, new data included the IED’s RTU Point Alias, IEC-61850 Point Name and IED Element Name. This allows tracing of a point from SCADA through the RTU and down to the IED.
IED MAPS: The second type of map defined all of the data available from a given IED. This was a superset of the data required by SCADA and included points for the local HMI, SCADA, DME, SER, and DSD systems. This map showed all of the data points being pulled from a particular IED and reflected where they would be used.
The local HMI’s on MPRP had anywhere from 1,500 to 11,000 tag names with the majority of these being IEC-61850 points. Data mapping was critical to organizing the design and ensuring that all desired functions were properly implemented.
The simple answer is NO, generally speaking the overall system is more complex. This complexity is driven by multiple factors:
The ability to work in the new “virtual” world requires a skill set that is different from traditional P&C systems.
The availability of additional data enables increased functionality necessary to address business drivers.
The implementation approach taken by some vendors ties protection functions much more closely with integration functions. With less separation between integration and protection complexity and risks increase.
The simple answer is NO, generally speaking the overall system is more complex. This complexity is driven by multiple factors:
The ability to work in the new “virtual” world requires a skill set that is different from traditional P&C systems.
The availability of additional data enables increased functionality necessary to address business drivers.
The implementation approach taken by some vendors ties protection functions much more closely with integration functions. With less separation between integration and protection complexity and risks increase.
We found over the course of MPRP that not all of the data we were interested in was exposed via the vendor’s IEC-61850 interface. In some cases the data existed in the relay but simply could not be provided from the relay’s logic to its communication interface. In other cases data was available but not in its native location within the relay, requiring remapping and additional logic to make the data available. In still others customization of the IED’s CID file was necessary to remap values.
Monitoring of IED and network status is critical. In our implementation every single communication circuit, device health status point and trip path was continually monitored to ensure system integrity. While the entire system was designed with no single point of failure, immediate detection of network or device problems was critical to ensuring the system performed as expected when faults occur.
We learned that at a minimum the following are required:
Device Health: Monitor each device for internal faults, power supply problems, or other issues typically monitored by the manufacture's watchdog functions
Communication Health: Monitor communication between all IED’s and other devices. For example IED to IED GOOSE message traffic is monitored and failures alarmed. Similarily RTU/HMI to IED traffic is monitored and alarmed.
Network Health: Monitor each communication path to ensure both primary and secondary links are functioning properly. The design provides for switchover to backup paths automatically when a primary fails. This insures correct system functionality, but also alerts operations staff so that repairs can be made in a timely fashion.
Trip Path Monitoring: With our 61850 implementation much of the tripping was done via GOOSE messages. Therefore features were built in to allow periodic testing of each relay’s trip path to verify system integrity.
Our experience indicates that interoperability tests in a lab setting are critical to project success. Our expectation is that the need for lab testing will decrease as the standard and vendor implementations mature, but for now this is an invaluable tool to ensure the SAS works as expected and the project is kept on schedule.
Implementation, commissioning and maintenance of 61850 systems requires a host of new tools. This includes items such as:
Protective Relay Test Sets such as OMICRON’s CMC 850 or Doble 6150
IED Browsers such as OMICRON’S IED Scout
Substation Configuration Language (SCL) Configuration Software such as SEL Architect or Triangle Microworks SCL Forge
Text Editing & Comparison Tools such as NotePad++ or WinMerge
Network Traffic Capture and Analysis tools such as WireShark
IED Specific Configuration Software
IEC-61850 requires the extensive use of networking and software tools not previously required. Therefore prior to the adoption of this new platform the technical work force necessary for the design, commissioning and maintenance of these systems requires extensive training. A mix of old and new skills is required. Basic automation coupled with advanced network communications, 61850 design philosophy, automated testing and configuration tools, and new testing skills for site engineers and technicians are needed. Overall there is a lack of technical knowledge on the IEC standard, computer networks and supporting tools. All of this combines to demand more training for all involved.
In every design there are literally 1,000’s of decisions to be made. When moving to a virtual platform the number of options grows exponentially. Therefore well written standards that consider the multitude of applications & options need to be constructed in order to bring a level of consistency across a given fleet of substations. While no two locations will ever be identical, the better samples and go-bye documentation is constructed the more consistent the end result.
Support from the vendor community is crucial. Over the course of MPRP we identified in excess of 100+ firmware or software bugs that could only be addressed by the hardware and software vendors. As products and standards mature this should become less of an issue, however; front line vendor support is critical to the success of a 61850 project for the foreseeable future.
We found significant differences in the support provided by various vendors. In particular smaller manufacturers tended to purchase 61850 interface modules from third parties and integrate them into their existing product. This results in another layer of integration problems (between the module and product) and a lack of understanding of 61850 at the IED vendor. Unlike DNP3 or ModBus which are well understood in the vendor community, support for 61850 is not as readily available.
The initial IEC 61850 projects were more costly than a traditional solution mainly because of the networking functionality and extensive configuration required; however, they provide greater flexibility to manage the system, along with requiring less maintenance and providing better monitoring and system performance. Important savings should be realized in subsequent projects from engineering design reuse and system cloning.
In addition IEC 61850 projects offer a simpler way to expand systems in the future as changes to interconnections can be done in software. Networked systems also increase system reliability by having IEDs close to switchyard equipment connected via fiber-optic cables, which reduces commissioning tasks and construction related work.