Terry Bilke, Midwest ISO

1
NASPI Operations Initiatives Task Team
Display/Tool Conventions, Guidelines and
Management
January 3, 2007

• by
• Terry Bilke, Midwest ISO
• Manu Parashar, EPG

2
Overview

• Display and Tool Objectives
• RDTMS Display Concepts
• RTDMS Visualization
• RTDMS Daily Summary Reports
• Visualization in Other Applications
• Linkage to the RTDMS
• Display Management

3

• Display and Tool Objectives

4
Display and Tool Objectives

• Provide integrated information and alerts (Red,
  Yellow, Green) in a common centralized display -
  Dashboard Summary
• Alert operators to significant changes, unusual
  conditions and encroachment of identified limits
• Maintain consistent wide area user displays
  throughout the Interconnections
• Some ability to customize RTDMS
• Users can still tap into data stream for local
  applications

5

• RDTMS Display Concepts

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RDTMS Display Concepts

• Based on User Needs
• Provide an information hub for operators
• There may be 20 or more parameters that can be
  monitored with phasor data, some may reside
  external to the RTDMS
• Display Real Estate limited - It is likely only
  one window will be made available for NASPI
  applications
• Bring operators attention to situations where
  something is beyond a hard limit or has changed
  significantly
• E-mail alerts to bring more eyes in the control
  room for significant problems
• Obtain Human Factors input

7
RDTMS Display Concepts (Continued)

• Common wide-area displays with one layer of local
  configurability
• Additional information can be found within 2-3
  mouse-clicks
• Provide a backup layer of local visibility
• Goal to make displays robust (problem with a
  single PMU in a zone will not defeat
  functionality)
• Open architecture to accept alarms, alerts and
  information from companion technologies and
  vendors and researchers that tap into data stream

8

• RTDMS Visualization

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Display Visualization StructureTiered Approach
(Drill-Down from Wide Area to Local displays)

• Develop set of displays that allow the user to
  monitor the entire Interconnection, Reliability
  Coordinator regions and local systems.
• Display Tier 1 Situational Awareness Dashboard
  Display (Default) Through simplistic traffic
  light type visual concepts, provides information
  on the overall system status using a set of
  predefined metrics, as well as information on the
  associated geographic region(s), and the time
  history of these metrics. Responsible group will
  approve and configure this display.
• Display Tier 2 Interconnection Displays A set
  of geo-graphic displays showing information on
  frequency and voltage related information at key
  PMUs across the Interconnection, as well as angle
  differences across reliability regions.
  Responsible group will approve and configure this
  display.
• Display Tier 3 Reliability Coordinator Displays
  For each Reliability Coordinator region, a set
  of geo-graphic displays showing information on
  frequency and voltage related information at PMUs
  within the Reliability Coordinator region, as
  well as angle differences across reliability
  regions. Responsible group will approve and
  configure this display.
• Display Tier 4 Local Displays A single set of
  regional displays showing frequency, voltage and
  angle differences for user selected PMUs and
  Paths. User will be able to configure this set
  of displays.

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Tiered Visualization Architecture (cont.)

• Display Tier 1 Dashboard Summary Display
  (Default)
• Display Tier 2 Eastern Interconnection Displays
• Display Tier 3 Reliability Coordinator Displays
• Display Tier 4 Local Displays (User to configure
  this set of displays)

Drill down to a geographic region (EI, RC,
Regional) and appropriate metric (Freq, Voltage,
Angles, MW, MVAR)
Monitor overall system status within dashboard
display
Configure Regional display using the
configuration utility
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TIER 1 Situational Awareness
Dashboard (Centrally Configured Display)
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Sample Dashboard Summary Display
Visualization Tiers Dashboard Summary,
Interconnection, Reliability Coordinator, Local
Area
Partitioned into RC Regions Angle Difference
Paths Shown in Geographic Display
Gauges to quantify worst performing metric (i.e.,
current value, mean, standard deviation, etc)
Indicators above gauges provides information on
the location
Monitor status of key EI metrics
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TIER 2 Interconnection Tier (Centrally
Configured Displays)
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Real-Time Phasor Monitoring Application- Path
Dynamics (Angle Difference) Monitoring Display

• historical tracking and comparison over specified
  time duration
• quickly identify interfaces affected by an event

• Monitor
• angles across predefined flowgates or interfaces
• Alarming
• color coded on proximity to alarming thresholds
• immediately identify areas of stress

compare angles across selected interfaces
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Real-Time Phasor Monitoring Application- Voltage
Monitoring Display

• Monitor
• voltage angles and magnitudes
• color coded
• quickly identify low or high voltage regions

voltage angle and magnitude tracking at selected
location
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Real-Time Phasor Monitoring Application- MW/MVAR
Flows Monitoring Display

• Monitor
• MW/MVAR flows on monitored lines
• Alarming
• color coded on proximity to transfer limits as
  established by offline studies
• quickly identify heavily loaded lines

• historical tracking over specified time duration
• track changing flows on selected line

MW/MVAR histogram/duration curve over specified
time duration
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TIER 3 Reliability Coordinator
Tiers (Centrally Configured Displays)
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Real-Time Phasor Monitoring Application-
Frequency Monitoring Display

• local frequency tracking

• Monitor
• Interconnection
• Frequency
• Deviation and the
• Associated
• Generation/Load
• Imbalance

Frequency rate-of-change measured in mHz/sec.
frequency duration curve or histogram to
assess performance
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Real-Time Phasor Monitoring Application- MW/MVAR
Flows Monitoring Display

• Monitor
• MW/MVAR flows on monitored lines
• Alarming
• color coded on proximity to transfer limits as
  established by offline studies
• quickly identify heavily loaded lines

• historical tracking over specified time duration
• track changing flows on selected line

MW/MVAR histogram/duration curve over specified
time duration
20
Real Time Alarming

• Real Time Alarming on Threshold Rate-of-Change
  Violations

Centrally configured alarming parameters at Server
21
Alarm Summary Reports
Select Alarm Types Date/Time
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Reports on Long-Term Trends Statistics
Baseline System create trends by time of day,
peak load, major line outages, etc.
Select Signals Date/Time
- Create trend plots - Export data into excel or
text files
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• RTDMS Daily Summary Reports

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Daily Summary Reports

• Intended to provide operators, engineers and
  NASPI teams daily summaries of infrastructure and
  grid performance
• Following slides are examples of what is planned
  for deployment in 2007

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Daily Report
26
Daily Report (continued)
27
Daily Report (continued)
28
Daily Report (continued)
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Daily Report (continued)
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Daily Report (continued)
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• Visualization in other Applications

32
Visualization in other Applications
This section reserved for input from vendors and
researchers on things they are trying to achieve
in their applications.
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• Linkage to the RTDMS

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Linkage to the RTDMS
The Spring 2007 version of the RTMS will have the
first test of accepting information from external
applications (FNet in this case). This section
reserved for results of that effort and
specification information to replicate this with
other vendors and researchers applications.
35

• Display Management Process and Guidelines

36
Display Modification Guidelines

• Interconnection tier to include
• Objective High level display of the EI power
  flow between sources and sinks,
• level of stress between regions and critical
  voltage levels
• Display only those PMUs installed at key high
  voltage transmission facilities (765kV, 500kV)
  and generation plants.
• Angle differences between PMUs directly/indirectly
  connected between major source and sink areas.
• MW/MVAR flows at critical monitored tie-lines at
  RC boundaries.
• Voltage levels at and between critical sources
  and sinks
• Exclude PMU signals with poor data quality or
  availability.

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Display Modification Guidelines (cont.)

• Reliability Coordinator tiers to include
• Objective Provide each RC with adequate
  information so they have a clear
• understanding of the level of stress within its
  area of responsibility and between
• adjacent RCs
• Monitor and display information from a sufficient
  number of PMUs at voltages between 230kV
• and 765kV in order to
• Provide a clear picture of source-sink power
  flows between both control areas and adjacent RC
  regions
• Angle differences along major transmission paths,
  between control areas and adjacent RC regions
  directly/indirectly connected by transmission
  lines.
• MW/MVAR flows across all monitored transmission
  lines within RC region or tie-lines to
  neighboring RC regions.
• Voltage levels at critical facilities within each
  control area and at RC boundaries
• Exclude PMU signals with poor data quality or
  availability.
• Local tier individually configured by end user on
  local client application.

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Display Management Process

• TVA to coordinate integration of new PMUs into
  the SuperPDC.
• CERTS provide assist to TVA in calibrating the
  new devices through comparisons with State
  Estimator snapshots and monitor data quality
  performance for these new devices.
• Reliability Coordinators and Transmission Owner
  representatives to suggest critical paths for
  monitoring and threshold limits.
• Develop draft displays incorporating information
  from new PMUs.
• NASPI OI Team to review and validate selected
  paths, and threshold limits.
• EPG and TVA to implement new displays at the
  central RTDMS Server.