Data System
Resume:
Data Integration Used in New Applications and
Control Center Visualization Tools
Ce Zheng, Yimai Dong, Ozgur Gonen, and Mladen Kezunovic, Fellow, IEEE
are necessary additions to the data recording infrastructure
needed for performing a comprehensive analysis of substation
Abstract Nowadays, most substations are equipped with
Intelligent Electronic Devices (IEDs) performing data collection. equipment operation. The merging of various substation data
With the advancement of measurement techniques and growing with the data from SCADA solutions to enhance EMS
availability of information captured by newly emerged IEDs such
functions has not yet been explored adequately [1].
as Phasor Measurement Units (PMUs), it is imperative to
A few studies have been reported that address this topic.
integrate the various data sources with traditional Supervisory
They primarily discuss how to extract desired information
Control and Data Acquisition (SCADA)/Energy Management
from field measurements and improve the quality of control
System (EMS) structure. This paper explores several possible
solutions for data integration and its applications in power center visualization tools in terms of good graphical
system. Also addressed is a set of new visualization tools to be representations [2]-[4]. In [2], the inefficiency of using
used in power system control center. It shows that the merging of
numerical data to display system conditions is identified, and
Remote Terminal Unit (RTU), PMU and other substation IED
three key characteristics of effective graphical representations
data could effectively improve the ability to detect cascades,
are illustrated. In [3] and [4], the concept of Geographic Data
efficiently process alarms, and accurately determine the location
Views (GDVs) has been introduced, which uses dynamically
of faults. The resulted intelligent control center visualization tools
could enrich monitoring capabilities and help operators maintain created visualization tools to display a wider range of power
adequate situational awareness. system information than what is possible using the existing
geographically based visualization tools. In particular, the
Index Terms IEDs, data integration, alarm processing, fault
research of [4] utilizes GPS-based information provided by
location, cascading event analysis, visualization tools
PMUs to display power system status in real-time. In some
other research, high-resolution satellite images are used to
I. INTRODUCTION
provide 2-D and 3-D representations [5, 6].
P OWER system is featured by numerous data collecting With the growth of its complexity, power systems are
points and a variety of measurement devices. Beyond the becoming more stressed and exposed to all kinds of
traditional Supervisory Control and Data Acquisition disturbances. To adapt to the emerging situation, several new
(SCADA) system composed of Remote Terminal Units applications deploying integration of field measurements have
(RTUs), there are many other substation Intelligent Electronic been introduced both in research and practice [7]-[12]. They
Devices (IEDs) serving the function of data collection. These utilize data from SCADA RTUs, PMUs and other IEDs to
modern IEDs can record and store a huge amount of data with analyze alarms, detect cascades and locate faults. Traditionally
a periodicity depending upon the intended purpose of the the substation data are acquired using RTUs of SCADA and
device: Digital Protective Relays and Digital Fault Recorders sent to the EMS in every two to ten seconds. But the SCADA
(DPRs and DFRs) capturing data during fault occurrence measured data does not have the characteristics needed to
(termed as non-operational data), and Phasor Measurement implement the new analysis and control tools due to the lack
Units (PMUs) capturing continuous time-synchronized of time-synchronized sampled waveform data. The purpose of
phasors (termed as situational awareness data). this paper is to investigate the integration of various data with
SCADA system solution has been used to provide real-time traditional SCADA system data, and its utilization in
information about power system states since the late sixties. applications, as well as the control center visualization tools to
The implementation of SCADA solutions improved the enhance EMS functions.
performance of Energy Management System (EMS) functions. The paper starts with an investigation of specific field data
Although the newly emerged multifunctional IEDs are not requirements for different applications. After that a framework
standardized regarding the functions they perform, they indeed of data integration used in applications is proposed. The
development of new control center visualization tools is
introduced then. Implementation considerations of how to
The reported development was coordinated by the Consortium for Electric
Reliability Technology Solutions (CERTS), and funded by the Office of
bind the visualization tools with application modules through
Electric Transmission and Distribution, Transmission Reliability Program of
communication channels are discussed at the end.
the U.S. Department of Energy.
The authors are with the Department of Electrical and Computer
Engineering, Texas A&M University, College Station, TX 77843 USA (e-
mails: *******@****.***; *********@****.***; *****.*****@*****.***;
*******@***.****.***).
2
II. NEW APPLICATIONS USING DATA INTEGRATION B. Optimized Fault Location
The optimized fault location method selects a suitable Fault
Knowing the potential benefits that data integration may
Location (FL) algorithm from three types of algorithms: two-
provide to the power industry, several issues still remain to be
end FL algorithm based on synchronized phasors or samples,
solved in this regard: (1) For a particular application, which
single-end phasor based FL algorithm, and system-wide sparse
data should be used and when; (2) How to glean useful
measurement based FL algorithm. Details of this application
information from huge amounts of original measurements and
are reported in [9]. The measurement equipments used are
(3) How to handle the extracted information in applications. A
sparsely located Digital Fault Recorders (DFRs) or other GPS-
review of recently published literature reveals that three new
synchronized IEDs (e.g. PMUs). Commercial software like
applications could become the beneficiaries of data
PSS/E and PowerWorld have been utilized to run power flow
integration. They are intelligent alarm processor, optimized
analysis and display the fault location respectively [13, 14].
fault location and cascading event analysis [8, 9, 12]. Their
The requirements of the field data needed for this application
data requirement specification and data integration framework
are listed in Table II.
will be explored in this section.
At the substation level, the availability of data collected
A. Intelligent Alarm Processor
from DFRs and PMUs makes it possible to implement some
The requirement for power system operators to respond new fault location algorithms. Integrating the data from these
more efficiently to the stressed power system conditions may IEDs with traditional SCADA solution data enables real-time
create need to process large number of alarms. This asks for monitoring of power system and fast operator actions. It could
implementation of advanced alarm processor that can help also be observed from Table II that data interpretation is an
operators recognize the nature of disturbance quickly and important issue when implementing the new fault location
reliably. Such an application of an intelligent alarm processor algorithm.
is reported in [8]. TABLE II
DATA REQUIREMENTS FOR OPTIMIZED FAULT LOCATION
In order to implement this intelligent alarm processor at
both system and local levels, different types of data from Function
Inputs Description
various sources are required, which are naturally divided into Module
two classes: system level data and substation data. The data Power Flow Power flow raw data This file contains power flow
requirements for the new implementation of the intelligent Analysis from input data files data for the establishment of an
alarm processor are specified and described in Table I. (System Level) for PSS/E (*.raw) initial case.
At the system level, information that is required by
Tuning of Static RTU measurements This file contains the latest
different functional modules is extracted from field System Model from SCADA load, branch and generator data
measurements according to their respective needs. At the local (System Level) Historian Database to tune the static system data
level, it could be observed that the data required by this alarm Sequence This file contains the negative
Short Circuit
processor is a combination of RTU measurements and impedance data and zero sequence impedance
Study
from input data files data needed for short circuit
measurements from other IEDs (e.g. DPRs). Currently in (System Level)
for PSS/E (*.seq) study.
United States, a common practice in power industry is to only
System binary data These files are used by the
automate the sending of data collected by RTUs to control Visualization of and graphical data PowerWorld Retriever to
center through SCADA system. All other IED data remain in Fault Location from input files for visualize the fault location. It
the device memory to be uploaded manually at a later time. If (System Level) PowerWorld (*.pwb contains power system binary
and *.pwd) and graphical data.
data stored in these IEDs could be integrated with the SCADA
system data, and uploaded automatically whenever needed, it Recorded data These are the fault event data to
during faults from be used in optimized fault
will greatly reduce the response time and improve the
DFRs and PMUs location algorithm.
efficiency of the analysis tools such as intelligent alarm Optimized Fault
1. Relates the channel numbers
Location
processor. Substation
to the monitored signals;
(Local Level) interpretation data
TABLE I
2. Correspondence between the
from Interpretation
DATA REQUIREMENTS FOR INTELLIGENT ALARM PROCESSOR
nomenclature used in DFR files
Data (*.int)
and those used in PSS/E.
Function
Inputs Description
Module
Circuit Breaker This input file includes the
C. Analysis of Cascading Events
(CB) status opening and closing information
Power system cascading event is quite often a very
change alarms of circuit breakers
Control Center
complex phenomenon with low probability of occurrence but
Alarm Over-current The data and alarms are obtained
may potentially cause catastrophic social and economical
Processor alarms and provided by SCADA
(System Level) impacts. Recent study reveals that early and proper control
While this file is always used to
Relay operation actions at the steady state stage may prevent the possible
verify the correctness of the
related alarms
cascading events. However, power system operators lack
analysis it is not used in IAP.
sufficient analysis and decision support tools to take quick
Data Collection
RTU data and selected data from DPRs
(Local Level) corrective actions needed to mitigate unfolding events.
3
TABLE III by GPS-enabled IEDs, and measurements collected by other
DATA REQUIREMENTS FOR CASCADING EVENT ANALYSIS
IEDs. In our proposed framework, all the recorded
measurements need to be sent to the Central Server Database
Function
Inputs Description
for incorporation. Time-correlated data are re-arranged and
Module
This file contains power flow queued according to their type and time tag, waiting for next
Power flow raw
system specification data for the
processing step: interpretation.
data
Power Flow establishment of an initial case.
Three reasons make data interpretation necessary:
Analysis
Slider binary data This file is used to create and
(System Level) The data recording equipments are very versatile, since
or drawing modify one-line diagrams and to
they came from various vendors with little interoperability;
coordinate data display a variety of results.
Utilities keep upgrading or constructing substations based
Description of These three data files are used to
system, elements, build Distribution Factor Data
on their operation needs, causing different IED types to
Contingencies
and contingency File (*.dfx)
have been installed in different time periods;
Analysis
This file contains the bus load
(System Level) Load throwover At the system level, different data formats are needed in
throwover data for use in
data file
different application groups, which depend on the
contingency analysis.
Fault Analysis Sequence Same as the data file used in operation procedures that the group adopted.
(System Level) impedance data optimized fault location
The diversity of data formats is one major problem. Non-
It contains dynamic data of
operational data usually comes in the COMTRADE data
Dynamics Data synchronous machines and other
Dynamic
format and IEC 61850 object model metadata standard for
system components.
Analysis
This data describes the unit IEDs that are IEC 61850 compatible [15, 16], whereas the data
(System Level) Machine
configuration at the generator
collected from PMUs follows the format for synchrophasors
Impedance Data
buses.
[17]. In addition, data may be further formatted using the
Event file output The relay event file contains the
Neural Network
IEEE File Naming Convention Standard [18]. To solve this
from DPRs report of relay operations.
based Fault
problem, a data interpreter is required to convert field
Detection and Recorded data DPRs and DFRs data used for
measurements with various formats into applicable data files
Classification from DFRs and evaluation of relay operations
for future uses.
(Local Level) DPRs using NNFDC.
With regard to the above three tasks involved in the data
Synchronized
Synchronized
integration process, the conceptual framework for data
Sampling based Synchronized samples used for
samples from
Fault Location evaluation of SSFL collection, incorporation and its interpretation in applications
GPS-based IEDs
(Local Level)
will be proposed first, which is shown in Fig. 1.
As depicted in Fig. 1, data sources like SCADA RTUs,
Recently a novel interactive scheme of system and local
PMUs and other IEDs are at the bottom layer. Central Server
monitoring and control tools for detection, prevention and
Database is responsible for concentrating and maintaining
mitigation of cascading events was introduced in [12]. The
substation data. Data interpreter is located at the top layer to
data requirements for this scheme are clarified in Table III.
convert original field measurements into applicable data files
From Table III it can be observed that the substation level
based on the needs of different applications.
function modules will need to take use of data coming from
It should be noted that this framework is at a conceptual
PMUs and other IEDs, including synchronized phasors and
level. In Section IV, implementation and communication
synchronized samples. Integrating such data with the
schemes to realize this framework will be explored in detail.
traditional SCADA data could produce a lot of benefits.
Compared to the fault location algorithm that use one-end or
two-end data, the Synchronized Sampling FL (SSFL) method
using synchronized samples, which is adopted in cascading
event analysis, is transparent to the assumptions about fault
condition and system operating state. Therefore it is less
affected by those factors and utilizes the useful time-domain
information in the waveform to locate the fault precisely.
D. Data Integration Framework
Now that data requirements for each application have been
specified, the issue of how to integrate data to benefit different
applications needs to be explored. The concept of Data
Integration in this research is in fact consisting of three
consecutive tasks: data collection, data incorporation and data
interpretation.
The task of data collection is executed at the substation
level. The recorded data could be divided into three
categories: SCADA data collected by RTUs (termed as Fig. 1. Data integration and interpretation for the use in different applications
operational data), synchronized samples and phasors captured
4
III. DATA INTEGRATION USED IN CONTROL CENTER Topological View module
VISUALIZATION TOOLS This module displays the connectivity of the various
components in the power system. The breaker/switch position
Real-time visualization of power system conditions is
will be shown to facilitate retrieving fault event information.
essential during the decision-making process in the system
control center. With growing availability of various data
Aerial View module
collected by traditional and innovative devices, how to glean
Satellite images will be processed and displayed in this
useful information from the huge amount of measurements for
module. A clear view of the terrain and power lines
the use of effective visualization still remains a problem to be
connection around fault location will be provided.
solved. To improve the effectiveness of control center
monitoring, a set of new graphical tools is developed in this Equipment Model View module
research. Three areas where accomplishments are achieved In this module, 3-D models are designed and created to
include: provide constructional and operational view of the power
Seamless incorporation of novel applications with the system equipment of interest.
new visualization tools;
B. Implementation structure of the software
Design and development of six Graphical User Interface
(GUI) modules with respective functionalities; The implementation structure of the proposed graphical
Identification of the implementation sequence for tools is shown in Fig. 3.
different applications and arrangements of visualization
modules.
A. Design of Graphical User Interfaces
With the purpose of providing operators an effective view
of the system states, six Graphical User Interfaces (GUIs) are
designed and developed in this research. Following is a brief
introduction of these visualization modules and their
respective functions:
Hierarchical View module
This module is used to monitor system behavior while
system is in steady state. Real time data are imported from
SCADA database.
Electrical View module
Real time power flow is shown on system one-line diagram
Fig. 3. Implementation structure of the control center visualization tools with
in the Electrical View interface. When event occurs, alarms
applications utilizing data integration
and faulted lines will be displayed.
Ontological View module With data collected from substations and processed in
application tools, the analysis results will be displayed using
This module displays how the Petri-net Logic is executed
the six proposed visualization modules to provide operators
in Intelligent Alarm Processor, i.e. how the irrelevant alarms
with comprehensive representations of the system states.
are suppressed and how the essential alarms are extracted. Fig.
Implementation details, in particular the communication
2 depicts the GUI integrated in this module.
schemes to realize this structure will be explained later in
Section IV.
C. Case Demonstration
A case demonstration by running the proposed software for
a given event scenario is provided in this section. A line-to-
line fault event has been created and simulated. After
automatic actions of relays and circuit breakers, at 1.437s the
fault evolved into a cascading event and system lost its
stability. Fault event data are recorded by various IEDs and
sent to different application groups. Analysis reports are
presented to control center operators via a set of GUIs, which
are shown in Fig. 4.
Fig. 2. Petri-net alarm processing diagram shown in the Ontological View
module of the user interface
5
By clicking the Circuit Breaker (CB) icon on the interface
f), the construction and operation models for circuit
breaker will pop up (shown by the interface h)).
By clicking the tower icon on the interface g), interface i)
will pop up, which displays the 3-D construction model of
towers and fault type demonstration.
Interactive functions such as zooming, clicking and
dragging are available in most of the developed GUIs.
Using the real-time information provided by the proposed
software, operators will have a better understanding of what is
going on in the system immediately after an event occurs.
Thus they will have enough time to constrain the impact of the
fault to local level. The possible occurrence of a cascading
event could be effectively detected and prevented in advance.
IV. IMPLEMENTATION CONSIDERATIONS
The data integration framework introduced in Section II
will be implemented in this section. Several issues need to be
considered when integrating data for the use of different
applications and related control center visualization tools:
Communication paths for optimizing data exchange
between substation, application groups and control room;
Congestion processing scheme for prioritizing analysis
reports in case of communication congestions;
New work flow management for utility groups for
making better use of extracted information.
Fig. 4. Case demonstration by running the visualization tools for a fault event
A. Communication Consideration
Pipeline of the software GUI activations shown in picture a) to
Communication Paths
i) is described next:
Interface a) is the system topological view, and b) is the A conclusion of data flow study is listed in Table IV. Data
system electrical view. They are used for monitoring the is categorized into four classes: 1) raw data, 2) pre-processed
normal state of the system, which constitutes the data from substation 3) reports and 4) historical data. Raw data
Hierarchical View module. is the data collected by SCADA RTUs without pre-processing
When an event/disturbance occurs, immediate notification at substation level. It is not directly engaged in functionalities,
is presented to operators, and related system elements will but is used only for archiving. Substation information package
be highlighted in the Hierarchical View interfaces contains information about CB Status, power flow (PF) data,
(interface a) and b)). DFR event reports, alarms, relay operation reports,
Interface c) shows the incorporation of the three new synchronized samples, real-time load and connectivity
applications in the software. By selecting corresponding information and other information that has been received from
menu items, operators could import analysis reports from substation RTUs and other IEDs, and selected and processed
different applications whenever a fault happens. at the substation level. Reports refer to the analysis reports
If the analysis report from the Intelligent Alarm Processor generated by different applications and being exchanged
is imported, the animated process of alarm filtering will be among departments in the control center. Historical data is the
displayed on the interface c), as shown in Fig. 2, which data retrieved from the database and serves in some of the
constitutes the Ontological View module. algorithms for the optimized fault location.
After importing the report from cascading event analysis,
interfaces d) and e) will pop up, which displays the TABLE IV
CONTROL CENTER LEVEL DATA FLOW
cascading event analysis results, including Critical
Clearance Time (CCT), Machines Angle Curve, Automatic Require
NO Name From To Class
Control Scheme, etc. (During steady state, this will enable ments
displaying the results of N-1 Contingency Analysis) Substation Alarm Real-
1 CB Status 2
Package Processing Time
After importing the report from the Optimized Fault
Location module, if the operator clicks highlighted lines, Substation Alarm Real-
2 OC Alarm 2
Package Processing Time
interface f) will pop up to display the fault details.
Relay Substation Alarm Real-
By clicking the fault icon on the interface f), interface g) 3 2
Operation Package Processing Time
pops up, which displays the satellite images around the Substation Real-
4 PF Data Fault Location 2
fault. This constitutes the Aerial View module. Package Time
6
Congestion Process
5 Historian Database Fault Location 4 Offline
Substation Real- Table V shows the priorities of different data flows and
6 Event files Fault Location 2
Package Time
processing scheme in case of congestions.
System Substation Real-
7 Fault Location 2
Info. Package Time
TABLE V
Fault
8 Request Database -- -- CONGESTION PROCESSING SCHEME
Location
Synchroniz Substation Cascading Synchro
9 2 Order of
ed Samples Package Event Analysis nization Data Flow Processing Method
Priority
Substation Cascading Real-
10 PF Data 2 Once the report is generated, it
Package Event Analysis Time Cascading Event
1 should be sent to visualization
System Substation Cascading Real- Report
11 2 unit with top priority
Information Package Event Analysis Time
Alarm and Fault Wait until cascading report is
Substation Cascading Real- 2
12 Event files 2 Location report sent out
Package Event Analysis Time
Alarm Alarm Substation package 3 Wait until no reports are in queue
13 Fault Location 3 --
report Processing
Historical data Wait until no real-time data
Alarm Alarm Cascading 4
14 3 -- retrieval package is in queue
Report Processing Event Analysis
Wait until the congestion is
Alarm Alarm Visualization Data storage 5
15 3 -- cleared
Report Processing Unit
Fault
Fault Visualization
In case of network congestions, data flows with less
16 Location 3 --
Location Unit
Report significance should make way to prioritized ones. For
Cascading Visualization
instance, cascading events will affect the stability and integrity
17 Cascading 3 --
Report Unit
of the entire grid, and the cascading event prevention and
Substation
18 Raw Data Database 1 -- mitigation requires fast reaction. So once cascading events are
Package
detected, the report should be sent to operators with top
Fig. 5 is a diagram of the communication paths. Arrows priority. Substation information package contains information
represent the direction of the data flow, and the numbers on for real-time analysis, so its priority should be next to the
the paths are consistent with the numbering of data in Table reports but higher than other flows. Raw data sent to database
IV. The Common Information Model (CIM), which is defined should be halted until other communication is complete.
in IEC-61970 [19], is utilized as standard data modeling
B. Work Flow Management
format. As shown in Table IV and Fig. 5, information from
In future, not only control room operators, but also each
substation is requested by multiple application tools. As a
utility group, including protection engineers, dispatchers,
result, substation information packages are designed to be
maintenance technicians, etc., will be equipped with a
multicast to IP addresses, addressing the host with
computer with GUI client installed. The clients together with
corresponding applications. Data retrieval from database is
the server are interconnected through a local area network.
realized using Peer-to-Peer communications [20]. If the
Operator is at the top level and responsible for monitoring
optimized fault location unit decides that an algorithm using
real-time system conditions. Other utility groups also receive
historical data is implemented, a request will be sent to server
information from client computers. The information they
database, and historian data will be sent back as an answer to
receive is not necessarily the same as the one received by the
the call.
operator, but it is the most relevant information that pertains to
their particular responsibilities.
Once an event occurs, the visualization tools will send a
notification to operator immediately. Operator could then
assign tasks to different groups according to the fault reports
and recommended solutions. The maintenance crew will be
requested to repair system components identified with
accurate fault location while protection engineers will be
asked to analyze the fault clearance sequence and dispatchers
will be required to re-dispatch the power generation and power
flow to balance the whole system.
The control center equipped with the new visualization
tools will now have two distinct features comparing with those
using traditional EMS system:
The substation data and extracted information are shared
with different utility groups, making sure the
Fig. 5. Communication paths between substation data processing package,
data/information are presented in the form most suitable
application modules and visualization units
for a given group;
7
[11] M. Kezunovic, B. Perunicic, "Automated transmission line fault analysis
Each group receives the best information since the origin
using synchronized sampling at two ends," IEEE Trans. Power Systems,
of substation data becomes transparent to the users and Vol. 11, No. 1, February 1996
what they receive is the best information obtained using all [12] H. Song, and M. Kezunovic, "A New Analysis Method for Early
available data. Detection and Prevention of Cascading Events," Electric Power Systems
Research, Vol. 77, Issue 8, Pages 1132-1142, June 2007
[13] PTI, PSS/E Application Guide, Vol. I [M], PSS/E Brochure, 2002
V. CONCLUSIONS [14] PowerWorld Retriver, User s Guide, PowerWorld Corporation, 2006
[15] IEEE Standard for Common Format for Transient Data Exchange
This paper investigates the integration of various data with
(COMTRADE) for Power Systems, IEEE Std. C37.111-1999 (Revision
traditional SCADA system data, and its utilization in of IEEE Std. C37.111-1991)
applications as well as the control center visualization tools to [16] IEC 61850 Communication networks and Systems in Substations, IEC
Standard, 14 parts, 2002 -2004
enhance EMS functions. Accomplishments reported in this
[17] IEEE Standard for Synchrophasors for Power Systems, IEEE Std.
paper include: C37.118-2005 (Revision of IEEE Std. 1344-1995)
Detailed data requirements for intelligent alarm processor, [18] IEEE Recommended Practice for Naming Time Sequence Data Files,
optimized fault location and cascading event analysis IEEE Std. C37.232-2007
[19] IEC 61970: Energy Management System Application Program Interface
have been specified respectively;
(EMS-API) Part 301: Common Information Model (CIM) Base,
The integration framework for PMU and other IED data Revision [6]
with traditional SCADA system data has been proposed [20] J. I. Khan and A. Wierzbicki, "Foundation of Peer-to-Peer Computing,"
for the use in new applications ; Special Issue, Journal of Computer Communication, Vol. 31, Issue 2,
The development of new control center visualization tools February 2008
is described. Six user graphics modules performing
different functions have been designed; BIOGRAPHY
Case demonstration of the visualization tools is Ce Zheng (S 07) received his B.S. and M.S. degrees from North China
illustrated; Electric Power University, Beijing, China, in 2005, 2007 respectively, all in
Communication paths and congestion processing scheme electric engineering. He has been with Texas A&M University pursuing his
Ph.D. degree since August 2007. His research interests include applications in
are designed to optimize data flows;
power system protection, digital simulation, power system voltage stability
New work flow management is suggested which makes
and control.
better use of information extracted from the source data.
Yimai Dong (S 07) received her B.S. and M.S. degrees from North China
ACKNOWLEDGMENT Electric Power University, Beijing, China, in 2005, 2007 respectively, all in
electric engineering. She has been with Texas A&M University pursuing her
The authors gratefully acknowledge the contribution of Ph.D. degree since August 2007. Her research interests include distribution
Yufan Guan, Papiya Dutta, and Chengzong Pang for their system operation, digital simulation, and smart grid applications.
work on the intelligent alarm processor, optimized fault
Ozgur Gonen received his B.A. in Visual Communication Design from
location, and cascading event analysis respectively. Istanbul Bilgi University with a minor in Computer Science in 2004. He got
his MS degree in Visualization Sciences from Texas A&M University in
REFERENCES 2007. His research interests include scientific visualization, solid modeling,
and user centric interface design.
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[2] P.M. Mahadev, R.D. Christie, Envisioning Power System Data: respectively. Currently, he is the Eugene E. Webb Professor and Site Director
Concepts and a Prototype System State Representation, IEEE Trans. of Power Engineering Research Center (PSerc), an NSF I/UCRC.at Texas
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PSerc Project S-25 Final Report (08-12), [Online]. Available: sabbatical at EdF in Clamart 1999-2000. He was also a Visiting Professor at
http://www.pserc.org Washington State University, Pullman, 1986-1987 and The University of
[4] T.J. Overby, E.M. Rantanen, S. Judd, "El
Contact this candidate