1. 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

2. 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,

3. 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

4. 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.

5. 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

6. 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.

7. 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.

8. DMS Functionality in Current Deployments0%
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.

9. Level of IT/OT Systems Integration with DMS

10. 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.

11. Benefit Perception for a single, off-the-shelf integrated SCADA, DMS and OMS

12. ADMS as Centerpiece System

13. ADMS as Centerpiece System (w SCADA Integrated/Embedded in DMS)
O M S

14. ADMS as Centerpiece System
O M S
G I S
CSR Desk
AM/FM
M D M S
FWMS

15. 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

16. 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

17. 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

18. 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

19. “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

20. 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

21. 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

22. 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

23. 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

24. 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

25. 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

26. 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

27. 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

28. 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!

29. 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.

30. 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

31. 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.

32. 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.

33. 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

34. Telecoms – Key to DA Success
Issues:
Capacity
Latency
Security (Isolated Operation?)
Shared Network Services
(With AMI? Alone?)

35. Telecommunications Options for DA/DMS
DA “Last Mile” Telecoms
DA Backhaul

36. 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

37. 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)

39. Our Newest Report on DA/DMS
Source for today’s
Discussion

40. The Role of Advanced DMS/SCADA Software and Systems
Thanks for Sitting in on This Session!
By Chuck Newton
Newton-Evans Research Company