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The Role of Advanced DMS/SCADA Software and Systems
in Building a Resilient and Reliable Power Distribution Grid By Chuck Newton Newton-Evans Research Company
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Where Do ADMS and D-SCADA Fit in the Scheme of Grid Control and Monitoring Systems?
AGC/DCS GMS Market Management System DERMS EMS D-SCADA SSA IED Coordination DA ADMS OMS HEMS Customer Info System Field Force Automation MDMS GIS ISO/RTO Systems Demand Response There are additional applications and sub-systems that do or will be linked in with the above – e.g., BEMS,
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Key Findings from Recent Newton-Evans DMS Studies
Based on this mid-late 2014 study and multiple earlier studies, increasing numbers of large utilities have indicated the following: Integrated systems are becoming more desirable Entrenched suppliers of large control systems (EMS primarily) have an "in" but often cannot provide the required component systems for an integrated approach to DMS-OMS-GIS. Many mid-size utilities consider their DSCADA systems (primarily the ACS, OSI, Telvent and Survalent communities) as suitable platforms for DMS/DA. A high proportion of all respondents do not yet see a need for a separate DMS. This is especially true among the mid-tier utilities. Summary of Observations from mid-2014 Study
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Key Findings from Newton-Evans DMS Studies
Based on this 2014 study and multiple earlier studies, increasing numbers of large utilities have also indicated the following: DMS systems can be (and most often are) implemented in a single control center that cuts across state lines in the United States. Typically, operating companies under a large holding corporation operate their own DMS or DSCADA installations.
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Attributes of an Advanced Distribution Automation Capability
Here are the 10 attributes of an advanced distribution automation capability based on IntelliGrid’s definition. 1. Real-time Distribution Operation Model and Analysis (DOMA) 2. Fault Location, Isolation and Service Restoration (FLISR/FDIR) 3. Voltage/var Control (VVC/VVO) 4. Distribution Contingency Analysis (DCA) 5. Multi-level Feeder Reconfiguration (MFR) 6. Relay Protection Re-coordination (RPRC) 7. Pre-arming of Remedial Action Schemes (PRAS) 8. Coordination of Emergency Actions (CEmA) 9. Coordination of Restorative Actions (CRA) 10. Intelligent Alarm Processing (IAP) While ADMS platforms are increasingly used by Tier One utilities, many other utilities continue to rely on their DSCADA system to manage a growing portfolio of ADA functions. Sources: IntelliGrid, Newton-Evans Research Company, Alstom Grid, ABB, GE
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The total North American DMS market is made up of ADM and DSCADA, with some overlapping providers and some different market participants in each category: When you add in the field components and the associated telecommunications costs, the total expenditures for Distribution Network Management exceed one billion dollars in North America.
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Use of DMS as of Mid-2014 (Participants in Newton-Evans’ Study)
Just over 40% of all respondents indicated use of a DMS as of June 2014. IOUs were more likely to indicate having a DMS installation than were respondents from other utility types. Nonetheless, all of the surveyed utilities do have a DSCADA capability and are likely to be applying SCADA control over basic DA functions such as capacitor bank control and recloser control. The survey sample consisted of 56 completed surveys, of which only 23 utilities cited current use of a “true” DMS (and these were mainly IOUs). However, all other participating utilities do operate a distribution SCADA, or DSCADA, many of which are used as a platform for some basic distribution automation (DA) functions, including capacitor bank control and recloser control. These DSCADA installations also support data acquisition from pole-top and line-mounted DA devices. DSCADA platforms are typically - but not always - limited in the extent to which they can perform advanced or complex DA (Advanced DA) functions such as switching analysis and FLISR.
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DMS Functionality in Current Deployments
0% 10% 20% 30% 40% 50% 60% 70% 80% SCADA Unbalanced Distribution Powerflow Unbalanced Distribution State Estimator VVO/VVC FLISR Switching Analysis, Planning and Execution DMS Training Simulator DERMS Network Topology Processor Load Relief/Management Event Replay Smart Meter/AMI Integration Other Three major functions implemented in at least 50% of DMS user sites and others moving up in usage.
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Level of IT/OT Systems Integration with DMS
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Near-Term and Mid-Term Priorities and Challenges for DMS Installations
NEAR TERM PRIORITIES Leveraging smart grid initiatives in DA and AMI, mentioned by nearly 60% of the group; Integration with legacy IT/OT systems; Enhancement of storm preparation and restoration processes. MID TERM: CHALLENGES: Managing EV charging stations; Managing microgrid deployments Distributed Energy Resources (DER) Demand Response/Management Knowledge capture Integration of automated devices at customer premises locations.
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Benefit Perception for a single, off-the-shelf integrated SCADA, DMS and OMS
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ADMS as Centerpiece System
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ADMS as Centerpiece System (w SCADA Integrated/Embedded in DMS)
O M S
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ADMS as Centerpiece System
O M S G I S CSR Desk AM/FM M D M S FWMS
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ADMS as Centerpiece System
DA Device Controls Automatic Circuit Reclosers Voltage Regulators Capacitor Banks Faulted Circuit Indicators Poletop RTUs Line/Post Monitors How do we communicate?? (1 way, 2 way) back to SCADA, to the poletop, to an SAS ?? OMS G I S
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ADMS as Centerpiece System
DA Device Controls Automatic Circuit Reclosers Voltage Regulators Capacitor Banks Faulted Circuit Indicators Poletop RTUs Line/Post Monitors OMS G I S Cost differentials, Communications options, experience with one approach over another. Perhaps co-mingiing of two or all three of these. Placement of DA Device Controls Field Substation Control Center
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ADMS as Centerpiece System
Placement of DA Device Controls Field-Based Control Center-Based Substation-Based Examples of suppliers for each approach to field device controls S&C Intelliteam II, L+G Grid Stream; SCADA center product suite, Cooper/Yukon Feeder Automation, G&W/Survalent Lazer Automation) ADMS or DSCADA GE and Others Alstom Grid-ASAT Cooper Cybectec GE Digital Energy Novatech SEL Subnet Solutions
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Placement of DA/DMS Controls
Findings from 2015 DA Study Three approaches in use today Trending toward Control Center in future Here are summary charts from our Feb 2015 DA study. You can see the trends over time point to increased placement of controls back at the control center
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“SMART GRIDS Infrastructure, Technology
Excerpt from: “SMART GRIDS Infrastructure, Technology and Solutions” Here are some of the devices with control logic imbedded or added to the infrastructure devices. © 2013 by CRC Press
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ADMS as Centerpiece System
DA Device Controls Distribution Network Analysis Advantica Stoner Cherry Tree CYME EDSA Milsoft Power Tech SKM Automatic Circuit Reclosers Voltage Regulators Capacitor Banks Faulted Circuit Indicators Poletop RTUs Third Party Sources of DNA OMS G I S
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ADMS as Centerpiece System
DA Device Controls Distribution Network Condition Monitoring Subsystem Bentley Nevada (GE) ETAP InStep Others Automatic Circuit Reclosers Voltage Regulators Capacitor Banks Faulted Circuit Indicators Poletop RTUs Third Party Sources of Distribution Network Condiction Monitoring Subsystems OMS G I S
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ADMS as Centerpiece System
DA Device Controls Distribution Network Fault Characterization and Location BPL Global CYME ETAP GE Multilin Milsoft Oracle Automatic Circuit Reclosers Voltage Regulators Capacitor Banks Faulted Circuit Indicators Poletop RTUs Third Party Sources of Fault Location and Fault Descriptor Data OMS G I S
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ADMS as Centerpiece System
Telecomm Options ADMS DA Device Controls Distribution Network Analysis Distribution Network Condition Monitoring Subsystem Automatic Circuit Reclosers Voltage Regulators Capacitor Banks Faulted Circuit Indicators Poletop RTUs Distribution Network Fault Characterization and Location Telecomm Options Vary Widely – by Size and Type, Spectrum Availability, Terrain, Service Area Geo-Characteristics, Customer Density and Device Density OMS G I S
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ADMS as Centerpiece System
Telecomm Options ADMS DA Device Controls Distribution Network Analysis Distribution Network Condition Monitoring Subsystem Automatic Circuit Reclosers Voltage Regulators Capacitor Banks Faulted Circuit Indicators Poletop RTUs Distribution Network Fault Characterization and Location Engineering Services Options – Third Party Consulting Engineers (as in EMS) or Reliance on DMS Vendors OMS G I S Engineering Services Options
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Drivers of Growth in ADMS Usage
Regulatory Actions aimed at increasing reliability and grid resilience. Increased use of “smart” field devices on the poles and on the lines, Development of integrated device controllers. Ability to monitor and control feeder activity. DOE Program Funding as part of ARRA Availability of newer apps that work well to enable . . . • FDIR and FLISR • VVC/VVO • CVR
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Development and Availability of Advanced Field Devices
Reclosers and Sectionalizers – Bi-Directional Voltage Regulators – Bi-Directional Sensor-Based Tools and Instruments Automatic Fault Sensors (Indicators, Locators) Advanced Poletop Data Aggregators Pole and Line Mounted Monitoring Devices
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DA Device Installation Points
Poletops Main Feeder Lines Secondary Lines Laterals Pole-Top RTUs Line Monitors Capacitor Bank Controls Automated Recloser Controls Sectionalizers Fault Indicators Voltage Regulators Apparatus Monitors DA Devices are installed at/mounted on these locations: Examples of DA Field Devices in Use today
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Figure 5. Density of Field Devices on a “per feeder” basis in American Electric Utilities: Mid-2014 Estimates by Type/Size of Utility (Basis: Newton-Evans study of FDIR in 2007; Newton-Evans-Motorola Study of 2009; Newton-Evans Study of 2010; Update of Aug 2013, June 2014, Feb 2015) Type of Utility Density of Poletop RTUs Density of Pole-Top Switches Density of Line Reclosers Density of Sectionalizers Density of Fault Interrupters Density of Capacitor Controllers Density of Overhead Switchgear Density of OH/MV Distribution Transformers Meter Density per square mile Investor-Owned-TOP 50 3-5 6-10 2-4 5-7 70-100 Investor-Owned – Other 1-2 5-9 4-6 40-65 Public Power Large(Munis) 50-70 Public Power –Other 1-3 25-50 Cooperatives-Large 30-50 10-50 Cooperatives - Other 1-4 20-40 3-25 Length of feeders also plays a role – especially if we add VRs to this mix!
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Core SG Technology: Automated Field Devices (from DOE report prepared by Newton-Evans)
Technology Status: Emerging, Significant Deployment of one or more types of field automation devices by most utilities (serving >10,000 customers) Deployment Status: Some of each device type is deployed in each region of the U.S. Key Developments: Several smaller firms are manufacturing line monitors and fault indicators GridSense, GridSentry, GridCo, Tollgrade SCADA integrators provide monitoring and control software Larger national and international firms provide the field equipment (with controls) GE, Hubbell, S&C, Cooper Some specialists provide distribution apparatus monitoring capabilities. (GE, Serveron) Key Obstacles: Standards for conformance testing not yet defined. DA morphing into ADA with more devices, more linkages, active Volt-Var control, Fault detection, Isolation and Service Restoration. Timeline for Deployment Some utilities have hundreds or thousands of some - or all - of these devices.
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Longer Term Outlook Is For Widespread Use of these Field Devices (from DOE Report)
Pole-Top RTUs Line Monitors Capacitor Bank Controls Automated Recloser Controls Sectionalizers Fault Indicators Voltage Regulators Apparatus Monitors ADMS
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2015-2020 Outlook for DMS and DA Based on recent Newton-Evans surveys
(and findings from other research firms) The DA Equipment/Device Market is growing nicely Smarter Field Infrastructure Equipment … Apparatus, Switches, VRs, Reclosers, FCIs, Capacitors, et al The ADMS Market is growing moderately – with earlier implementations of DMS systems being migrated to ADMS. The D-SCADA Market is mature but systems are being updated regularly to manage more DA functions.
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Leading Suppliers of ADMS and D-SCADA
ADMS Developers include: GE, Alstom, ABB-Ventyx, Siemens, OSII GE alone offers uniqueness with internal capabilities for OMS and GIS. D-SCADA/DMS Advanced Control Systems, C-G Automation, Schneider-Telvent, Survalent, Distributed DA Device Management Software: S&C Intelliteam II, L+G Grid Stream suite, Cooper/Yukon Feeder Automation, G&W/Survalent Lazer Automation) Controller Devices/Systems: Field Devices: Line Monitors: All of the above plus specialist firms with sensor-based line mounted devices (Gridco, Gridsense, Tollgrade, Grid Sentry, PDP) Fault Indicators: Some of the above plus (Tollgrade, PDP, Eaton-Cooper, T&B) Poletop RTUs: (GE, ACS, Telvent, Siemens, OSI, NovaTech, DAQ) SAS Integration Specialists now also “host” DA control software (GE Multilin, Alstom ASAT, Subnet Solutions, NovaTech) and a new segment we call “enterprise-to-field” integrators led by firms including DigitaLogic.
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Excerpts from Series of DA Overviews
Feeder Automation – To What Ends? • Enabler for VVO/VVC • Enabler for FDIR/FLISR • Key to SAIDI and SAIFI improvements
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Telecoms – Key to DA Success
Issues: Capacity Latency Security (Isolated Operation?) Shared Network Services (With AMI? Alone?)
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Telecommunications Options for DA/DMS
DA “Last Mile” Telecoms DA Backhaul
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NAM Electric Power Data Communications Spending Outlook - by IT/OT Application
IT and OT Application 2014 Estimate 2020 Forecast IT Data Center Networks $205 M $275 M Enterprise Networks LAN/WANs $290 M $460 M AMI $105 M $185 M OT Control Systems $145 M $200 M Distribution Automation FAN $190 M $350 M Protection and Control -Teleprotection $ 95 M $ 105 M Demand Response $ 50 M $ 70 M Distributed Energy Resource Integration $65 M $110 M Field Workforce Automation $95 M $135 M IT/OT NERC CIP Operations Compliance $160 M IT+OT TOTALS $1,350 M $2,050 M
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Need for Multiple Tier Network Design as Smart Grid Applications Come Online
Wireline Approaches for Critical Operations Tier One Control Systems >>>>> Substations Tier Two Substations >>>>> Substations >>>>> Critical Customers Mixed Wireline and Wireless Approaches Dedicated Microwave links Substations in Mixed suburban/rural areas Tier Three Substations to Key DA points Tier Four CPE --- Meter Data Collection Points (NANs FANS)
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Our Newest Report on DA/DMS
Source for today’s Discussion
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The Role of Advanced DMS/SCADA Software and Systems
Thanks for Sitting in on This Session! By Chuck Newton Newton-Evans Research Company
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