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the complete sequences and providing an end to end, integrated view of the entire distribution spectrum. In the UK, by contrast, the much denser and more meshed network topologies, combined with stronger Health & Safety regulation, had led to early centralisation of high-voltage switching operations, initially using paper records and schematic diagrams printed onto large wallboards which were 'dressed' with magnetic symbols to show the current running states. There, DMSs grew initially from SCADA systems as these were expanded to allow these centralised control and safety management procedures to be managed electronically. These DMSs required even more detailed component/connectivity models and schematics than those needed by early OMSs as every possible isolation and earthing point on the networks had to be included. In territories such as the UK, therefore, the network component/connectivity models were usually developed in the DMS first, whereas in the USA these were generally built in the GIS.
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or lower voltage as is necessary. Capacitor banks manage voltage by “generating” reactive power, and have thus far been the primary tools through which true Volt/VAR control is carried out. These large capacitors are connected to the grid in shunt configuration through switches which, when closed, allow the capacitors to generate VARs and boost voltage at the point of connection. In the future, further VVC might be carried out by smart inverters and other distributed generation resources, which can also inject reactive power into a distribution network. A VVC application helps the operator mitigate dangerously low or high voltage conditions by suggesting required action plans for all VVC equipment. The plan will give a required tap position and capacitor switching state to ensure the voltage stays close to its nominal value and thus optimize Volt-VAR control function for the utility.
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periodic or real time data with each other for assessing present operation condition of the network, workflows and resources (like crew, assets, etc.). Unlike other power system segments, distribution system changes or grows every day, and this could be due to the addition of a new consumer, a new transmission line or replacement of equipment. If the different functional modules are operating in a non-standard environment and uses custom APIs and database interfaces, the engineering effort for managing shall become too large. Soon it will become difficult to manage the growing changes and additions which would result in making system integrations non- functional. Hence utilities cannot make use of the complete benefit of functional modules and in some cases; the systems may even need to be migrated to suitable environments with very high costs.
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crux of IEC 61968 standards is the
Interface Reference Model (IRM) that defines various standard interfaces for each class of applications. Abstract (Logical) components are listed to represent concrete (physical) applications. For example, a business function like Network Operation (NO) could be represented by various business sub-functions like Network Operation Monitoring (NMON), which in turn will be represented by abstract components like Substation state supervision, Network state supervision, and Alarm supervision.
503:. Due to several network and operational constraints utility network may be operated to its maximum capability without knowing its consequences of losses occurring. The overall energy losses and revenue losses due to these operations shall be minimized for effective operation. The DMS application utilizes switching management application for this, the losses minimization problem is solved by the optimal power flow algorithm and switching plans are created similar to above function
435:) that strain the grid. This is because the reactive portion of these loads causes them to draw more current than an otherwise comparable, purely resistive load would draw. The extra current can result in heating up of equipment like transformers, conductors, etc. which might then need resizing to carry the total current. An ideal power system needs to control current flow by carefully planning the production, absorption and flow of reactive power at all levels in the system.
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model. Switching schedules can combine telecontrolled and manual (on-site) switching operations. When the required section has been made safe, the DMS allows a Permit To Work (PTW) document to be issued. After its cancellation when the work has been finished, the switching schedule then facilitates restoration of the normal running arrangements. Switching components can also be tagged to reflect any
Operational Restrictions that are in force.
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energy delivery in the electric distribution system and identify problem areas. A Feeder Load
Management monitors the vital signs of the distribution system and identifies areas of concern so that the distribution operator is forewarned and can efficiently focus attention where it is most needed. It allows for more rapid correction of existing problems and enables possibilities for problem avoidance, leading to both improved reliability and
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a transformer. When a distribution network is complex and covers a larger area, emergency actions taken downstream may reduce burden on upstream portions of the network. In a non-automated system, awareness and manual operator intervention play a key role in trouble mitigation. If the troubles are not addressed quickly enough, they can cascade exponentially and cause major catastrophic failure.
36:
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the exact operational requirement. Network connectivity analysis is an operator specific functionality which helps the operator to identify or locate the preferred network or component very easily. NCA does the required analyses and provides display of the feed point of various network loads. Based on the status of all the switching devices such as
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interest are indicative of parameters like margins to operating limits, health of equipment and required operator action. State estimators allow the calculation of these variables of interest with high confidence despite the facts that the measurements may be corrupted by noise, or could be missing or inaccurate.
447:, multiple injection points and fluctuating consumer demand. These features are inherently vulnerable to instabilities or unpredicted system conditions that may lead to critical failure. Instability usually arises from power system oscillations due to faults, peak deficit or protection failures. Distribution
624:(XML). One of its primary uses is information exchange between different and potentially incompatible computer systems. XML is thus well-suited to the domain of system interfaces for distribution management. It formats the message payloads so as to load the same to various messaging transports like SOAP (
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In the legacy grid, there are three primary tools for carrying out voltage management: Load Tap
Changers (LTCs), voltage regulators, and capacitor banks. LTCs and voltage regulators refer to transformers with variable turns ratios that are placed at strategic points in a network and adjusted to raise
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An automated Load
Shedding Application detects predetermined trigger conditions in the distribution network and performs predefined sets of control actions, such as opening or closing non-critical feeders, reconfiguring downstream distribution or sources of injections, or performing a tap control at
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levels are the key deliverables of a DMS. Given the complexity of distribution grids, such systems may involve communication and coordination across multiple components. For example, the control of active loads may require a complex chain of communication through different components as described in
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As these problems came to light, various standardization processes for inter application data exchanges were initiated. It was understood that a standard based integration shall ease the integration with other functional modules and that it also improves the operational performance. It ensures that
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The network component/connectivity model, and associated diagrams, must always be kept absolutely up to date. The switching schedule facility therefore also allows 'patches' to the network model to be applied to the live version at the appropriate stage(s) of the jobs. The term 'patch' is derived
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In territories such as the UK a core function of a DMS has always been to support safe switching and work on the networks. Control engineers prepare switching schedules to isolate and make safe a section of network before work is carried out, and the DMS validates these schedules using its network
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DMSs access real-time data and provide all information on a single console at the control centre in an integrated manner. Their development varied across different geographic territories. In the US, for example, DMSs typically grew by taking Outage
Management Systems to the next level, automating
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As per IEC 61968, a DMS encapsulates various capabilities like monitoring and control of equipment for power delivery, management processes to ensure system reliability, voltage management, demand-side management, outage management, work management, automated mapping and facilities management. The
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via feeder reconfiguration is an essential application for utilities where they have multiple feeders feeding a load congested area. To balance the loads on a network, the operator re-routes the loads to other parts of the network. A Feeder Load
Management (FLM) is necessary to allow you to manage
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DMS needs to provide a modular automated load shedding & restoration application which automates emergency operation & control requirements for any utility. The application should cover various activities like Under
Frequency Load Shedding (UFLS), limit violation and time of day based load
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Even though we may not be able to directly observe the state, it can be inferred from a scan of measurements which are assumed to be synchronized. The algorithms need to allow for the fact that presence of noise might skew the measurements. In a typical power system, the State is quasi-static. The
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Distribution network usually covers over a large area and catering power to different customers at different voltage levels. So locating required sources and loads on a larger GIS/Operator interface is often very difficult. Panning & zooming provided with normal SCADA system GUI does not cover
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are key parameters which need to be ensured by any utility. Reduced outage time duration to customer, shall improve over all utility reliability indices hence FMSR or automated switching applications plays an important role. The two main features required by a FMSR are: Switching management &
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In any integrated energy delivery utility operation model, there are different functional modules like GIS, Billing & metering solution, ERP, Asset management system that are operating in parallel and supports routine operations. Quite often, each of these functional modules need to exchange
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systems. These two quantities are related, because as reactive power flows over an inductive line (and all lines have some inductance) that line sees a voltage drop. VVC encompasses devices that purposely inject reactive power into the grid to alter the size of that voltage drop, in addition to
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factor could be added as an explanatory variable in addition to those used in the summer model. In transitional seasons such as spring and fall, the transformation technique can be used. For holidays, a holiday effect load can be deducted from the normal load to estimate the actual holiday load
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Load forecasting is classified in terms of different planning durations: short-term load forecasting or STLF (up to 1 day, medium-term load forecasting or MTLF (1 day to 1 year), and long-term load forecasting or LTLF (1–10 years). To forecast load precisely throughout a year, various external
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is an integral part of the overall monitoring and control systems for transmission networks. It is mainly aimed at providing a reliable estimate of the system voltages. This information from the state estimator flows to control centers and database servers across the network. The variables of
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decay away quickly (with respect to measurement frequency). The system appears to be progressing through a sequence of static states that are driven by various parameters like changes in load profile. The inputs of the state estimator can be given to various applications like
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by the applications. The action plan includes switching ON/OFF the automatic load break switches / RMUs/Sectionalizer . The action plan can be verified in study mode provided by the functionality . The switching management can be manual/automatic based on the configuration.
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and defines standards for information exchanges between electrical distribution system applications. It is intended to support the inter-application integration of a utility enterprise that needs to collect data from different applications which could be new or legacy.
201:(IVRS). An outage management system has a network component/connectivity model of the distribution system. By combining the locations of outage calls from customers with knowledge of the locations of the protection devices (such as circuit breakers) on the network, a
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networks efficiently and reliably. It acts as a decision support system to assist the control room and field operating personnel with the monitoring and control of the electric distribution system. Improving the reliability and quality of service in terms of reducing
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the utility can be in a vendor neutral environment for future expansions, which in turn means that the utility can easily add new functional modules on top of existing functionality and easily push or pull the data effectively without having new interface adapters.
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rather than voltage and current. It analyzes the power systems in normal steady-state operation. The goal of a power flow study is to obtain complete voltage angle and magnitude information for each bus in a power system for specified load and generator
644:
Yih-Fang Huang; Werner, S.; Jing Huang; Kashyap, N.; Gupta, V., "State
Estimation in Electric Power Grids: Meeting New Challenges Presented by the Requirements of the Future Grid," Signal Processing Magazine, IEEE, vol.29, no.5, pp.33,43, Sept.
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that affect the topology of the network modeled, the prevailing network topology is determined. The NCA further assists the operator to know operating state of the distribution network indicating radial mode, loops and parallels in the network.
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Distribution Load
Forecasting (DLF) provides a structured interface for creating, managing and analyzing load forecasts. Accurate models for electric power load forecasting are essential to the operation and planning of a
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increased exponentially and customer requirement and quality definitions of power were changed enormously. As electric energy became an essential part of daily life, its optimal usage and reliability became important.
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Improve service reliability by tracking all customers affected by an outage, determining electrical configurations of every device on every feeder, and compiling details about each restoration process.
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The DMS application receives faults information from the SCADA system and processes the same for identification of faults and on running switching management application; the results are converted to
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Due to the nonlinear nature of this problem, numerical methods are employed to obtain a solution that is within an acceptable tolerance. The load model needs to automatically calculate loads to match
620:(CIM), which is currently maintained as a UML model, to meet the needs of electrical distribution. For structured document interchange particularly on the Internet, the data format used can be the
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and forecasting capabilities that is configured to address today's requirements and adapt to address future requirements and should have the capability to produce repeatable and accurate forecasts.
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Beyond maintaining a stable voltage profile, VVC has potential benefits for the ampacity (current-carrying capacity) of power lines. There could be loads that contain reactive components like
616:(UML). UML includes a set of graphic notation techniques that can be used to create visual models of object-oriented software-intensive systems. The IEC 61968 series of standards extend the
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or forecasted feeder currents. It utilises customer type, load profiles and other information to properly distribute the load to each individual distribution transformer. Load-flow or
516:. DLF helps an electric utility to make important decisions including decisions on purchasing electric power, load switching, as well as infrastructure development.
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have become instrumental for optimizing resources and managing demands, leading to the need for distribution management systems in large-scale electrical networks.
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applied to a power system. The load flow study usually uses simplified notations like a single-line diagram and focuses on various forms of
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is used to predict the locations of outages. Based on this, restoration activities are charted out and the crew is dispatched for the same.
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A DMS incorporates IVR and other mobile technologies, through which there is an improved outage communications for customer calls.
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are important for planning future expansion of power systems as well as in determining the best operation of existing systems.
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In order to support proper decision making and O&M activities, DMS solutions should support the following functions:
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IEC 61968 recommends that system interfaces of a compliant utility inter-application infrastructure be defined using
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Volt-VAR Control or VVC refers to the process of managing voltage levels and reactive power (VAR) throughout the
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IEC-International Standards and Conformity Assessment for all electrical, electronic and related technologies
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IEC 61968 is a standard being developed by the Working Group 14 of Technical Committee 57 of the
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flow on each branch as well as generator reactive power output can be analytically determined.
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and restoration schemes play a vital role in emergency operation and control in any utility.
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212:(SCADA) systems, initially only at their higher voltage substations. Over time, use of
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seasons and holidays need to be considered. For example, in the winter season, average
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Government of India's multi million dollar Power Development & Reform Program
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The various sub functions of the same, carried out by the DMS are listed below:-
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560:. Amongst these, the most popular STLF were stochastic time series models like
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have been developed for load forecasting based on various techniques like
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Determine the crew resources necessary to achieve restoration objectives.
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has progressively extended downwards to sites at lower voltage levels.
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572:(ARIMA) model and other models using fuzzy logic and Neural Networks.
133:) is a collection of applications designed to monitor and control the
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from the method previously used to maintain the wallboard diagrams.
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Reduce crew patrol and drive times through improved outage locating.
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and voltage conditions. Once this information is known, real and
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Provide customers with more accurate estimated restoration times.
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In parallel with this, distribution utilities began to roll out
142:, minimizing outage time, maintaining acceptable frequency and
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shedding schemes which are usually performed by the operator.
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Most distribution utilities have been comprehensively using
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On a similar note, Feeder Reconfiguration is also used for
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Effectively utilize resources between operating regions.
57:
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Electric Distribution Systems have long stretches of
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Improve the speed and accuracy of outage predictions.
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Management system for electrical power distribution
235:(FEPs) & Field Remote Terminal Units (FRTUs).
296:Applications for Analytical & Remedial Action
265:Determine when best to schedule mutual aid crews.
484:Load Balancing via Feeder Reconfiguration (LBFR)
463:Fault Management & System Restoration (FMSR)
367:, Contingency Analysis, and other applications.
416:equipment that more directly controls voltage.
375:Load flow study is an important tool involving
358:time constants are sufficiently fast so that
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62:introducing citations to additional sources
231:(ISR) system, Communication (COM) Servers,
189:(OMS) that makes use of other systems like
332:Switching Schedule & Safety Management
570:Autoregressive integrated moving average
210:Supervisory Control and Data Acquisition
52:Relevant discussion may be found on the
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223:The typical data flow in a DMS has the
596:IEC 61968 Standards Based Integration
7:
566:Autoregressive moving average model
507:Distribution Load Forecasting (DLF)
310:Network Connectivity Analysis (NCA)
229:Information Storage & Retrieval
25:
199:Interactive Voice Response System
160:In recent years, utilization of
73:"Distribution management system"
45:relies largely or entirely on a
34:
659:IEEE Power & Energy Society
439:Load Shedding Application (LSA)
268:Increased customer satisfaction
195:Geographical Information System
558:knowledge based expert systems
244:Reduce the duration of outages
127:distribution management system
18:Distribution Management System
1:
626:Simple Object Access Protocol
520:factors including weathers,
371:Load Flow Applications (LFA)
583:Standards Based Integration
467:Reliability and quality of
191:Customer Information System
135:electric power distribution
700:
622:Extensible Markup Language
614:Unified Modelling Language
562:Autoregressive (AR) model
524:, population, per capita
472:Suggested switching plan
302:System Protection Schemes
618:Common Information Model
187:Outage Management System
185:solutions through their
150:US patent 11747849B2
526:gross domestic product
407:Volt-VAR Control (VVC)
299:Utility Planning Tools
255:operational efficiency
546:exponential smoothing
345:State Estimation (SE)
291:Network visualization
233:Front-End Processors
58:improve this article
542:multiple regression
293:& support tools
413:power distribution
401:Power flow studies
377:numerical analysis
365:Load Flow Analysis
538:predictive models
501:loss minimization
445:transmission line
171:dynamic decisions
167:Real-time network
162:electrical energy
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550:fuzzy logic
203:rule engine
114:August 2024
684:Automation
632:References
530:wind chill
425:capacitors
386:real power
197:(GIS) and
84:newspapers
431:(such as
429:inductors
397:telemeter
325:isolators
169:view and
54:talk page
678:Category
628:), etc.
568:(ARMA),
536:Various
533:better.
381:AC power
239:Why DMS?
177:Overview
193:(CIS),
144:voltage
98:scholar
319:(CB),
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225:SCADA
214:SCADA
105:JSTOR
91:books
645:2012
556:and
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349:The
77:news
602:IEC
131:DMS
60:by
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552:,
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183:IT
125:A
129:(
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