1. No category

EPRI Power Quality Applications (PQA) and
Advanced Distribution Automation (ADA)
2009 Conference and Exhibition
Review of Canadian Smart
Grid Initiatives
Chad Abbey
CanmetENERGY, Natural Resources Canada
July 1, 2009
Overview
• Overview of industry activities
• Specific Smart Grid initiatives
• DER and the Smart Grid
• Testing facilities
• Perspective from regulators
• Summary
2
Copyright © Her Majesty the Queen in Right of Canada, as represented by the Minister of
Natural Resources, 2009.
PQA/ADA Conference & Exhibition 2009
Smart Canadian Utility Projects
3
Smart Grid Technology
Utilities/Region
AMR/AMI
BC Hydro, Ontario, Hydro-Quebec
Automatic Fault Location
Hydro-Quebec
Fast Reconfiguration (e.g. S&C’s IntelliTEAM)
BC Hydro, ENMAX, Burlington, Toronto
Hydro
Voltage Reduction Schemes
BC Hydro, Hydro-Quebec
Remote monitoring
Hydro-Quebec
Planned Islanding
BC Hydro, Hydro-Quebec
Copyright © Her Majesty the Queen in Right of Canada, as represented by the Minister of
Natural Resources, 2009.
PQA/ADA Conference & Exhibition 2009
New Technology – Kinects
Feeder Current Monitoring (FCM)
• The feeder current meter primary
measurement and reporting is the line
current of the HV side (max, min,
accumulated)
• Granular data to be consolidate into one
central repository.
• Need to add analytical to improve
operation and planning (optimize
decision-making based on data)
Source: Leveraging Smart Meter Technology at Milton Hydro, R.
Brajovic, presented at EDIST 2009 Conference, Markam, Ontario
4
Copyright © Her Majesty the Queen in Right of Canada, as represented by the Minister of
Natural Resources, 2009.
PQA/ADA Conference & Exhibition 2009
Leveraging Smart Meter Technology
Milton Hydro Example
Source: Leveraging Smart Meter Technology at Milton Hydro, R.
Brajovic, presented at EDIST 2009 Conference, Markam, Ontario
5
Copyright © Her Majesty the Queen in Right of Canada, as represented by the Minister of
Natural Resources, 2009.
PQA/ADA Conference & Exhibition 2009
Comparing Smart Meter Customer Data and
Distribution Transformer Measurements
Source: Leveraging Smart Meter Technology at Milton Hydro, R. Brajovic,
presented at EDIST 2009 Conference, Markam, Ontario
6
Copyright © Her Majesty the Queen in Right of Canada, as represented by the Minister of
Natural Resources, 2009.
PQA/ADA Conference & Exhibition 2009
Transformer Monthly Loading
using hourly interval data from each customer
Source: Leveraging Smart Meter Technology at Milton Hydro, R.
Brajovic, presented at EDIST 2009 Conference, Markam, Ontario
7
Copyright © Her Majesty the Queen in Right of Canada, as represented by the Minister of
Natural Resources, 2009.
PQA/ADA Conference & Exhibition 2009
New Engineering Planning Tool (needs AMI)
Energy Profile Manager
• Metered load and generator profiles
•Meter demand and network demand profiles
Source: Leveraging Smart Meter Data, CYME International, St-Bruno, Quebec.
8
Copyright © Her Majesty the Queen in Right of Canada, as represented by the Minister of
Natural Resources, 2009.
PQA/ADA Conference & Exhibition 2009
CEATI Smart Grid Working Group
• Centre for Energy Advancement through
Technological Innovation (CEATI) International
• Objectives
– Definition of Smart Grid
– Action plan for development of the Smart Grid
– Identify technology gaps
– Share successful strategies for implementation of
the Smart Grid
• Initiated in 2008
9
Copyright © Her Majesty the Queen in Right of Canada, as represented by the Minister of
Natural Resources, 2009.
PQA/ADA Conference & Exhibition 2009
Ontario Smart Grid Forum
• Participation
– Led by IESO
– Utilities, suppliers, government
• Objectives
– Develop a high level vision of Ontario Smart Grid
– Educate industry leaders on drivers, technologies,
and opportunities
– Identify enablers and barriers
• Outputs
– Report on findings and recommendations
– Website:
www.theimo.com/imoweb/marketsandprograms/smart_grid.asp
10
Copyright © Her Majesty the Queen in Right of Canada, as represented by the Minister of
Natural Resources, 2009.
PQA/ADA Conference & Exhibition 2009
Utilities Telecom Council (UTC) Canada
request dedicated spectrum
• Spearheaded by 5 Canadian utilities
– Intelligent grid = Large data transfers
– Rural networks requires spectrum with good
propagation
• Industry Canada proposal
– Consultation process – Gazette Notice SMSE-008-08:
http://www.ic.gc.ca/epic/site/smt-gst.nsf/en/sf08972e.html
• 30 MHz contiguous frequency block in the 1.8 GHz band
• relax the SRSP (Standard Radio System Plans) 301.7 to
accommodate point-to-multipoint topologies
• Widely supported by respondents
11
Copyright © Her Majesty the Queen in Right of Canada, as represented by the Minister of
Natural Resources, 2009.
PQA/ADA Conference & Exhibition 2009
Smart Grid and DG Drivers
• Distribution System Automation
– Smart meter initiatives
– Reliability
– Ageing infrastructure – grid modernization
• Distributed Generation
– Predominantly policy push
– Secondary drivers: reliability, capacity
12
Copyright © Her Majesty the Queen in Right of Canada, as represented by the Minister of
Natural Resources, 2009.
PQA/ADA Conference & Exhibition 2009
Distributed Generation in Canada
• Technologies
– Wind, small hydro, PV, biogas
• Regions
– BC – small hydro, request for proposals
– Alberta – Distributed wind, biogas
– Manitoba – Distributed wind
– Ontario – Green Energy Act
– Québec – small hydro, wind, programs coming
13
Copyright © Her Majesty the Queen in Right of Canada, as represented by the Minister of
Natural Resources, 2009.
PQA/ADA Conference & Exhibition 2009
Example - Impact of SOP
West of Toronto (2005)
Location of Transformer Stations TS +
Source:
M.Dang, Hydro One, March 25, 2008
Copyright © Her Majesty the Queen in Right of Canada, as represented by the Minister of
14
Natural Resources, 2009.
PQA/ADA Conference & Exhibition 2009
Example - Impact of SOP
West of Toronto (2007)
Orangeville
Goderich
Source:
One,
March
25,
2008
Copyright M.Dang,
© Her Majesty the Hydro
Queen in Right
of Canada,
as represented
by the
Minister of
15
Natural Resources, 2009.
PQA/ADA Conference & Exhibition 2009
Issues and Barriers
• Drivers don’t encourage coordination between DG and
smart grid technologies
• Smart applications and DG compatibility
• DA is not necessary implemented where DG is
interconnected
• Standards and application guides needed that foster
integration of DG as opposed to simply connection (in
progress)
16
Copyright © Her Majesty the Queen in Right of Canada, as represented by the Minister of
Natural Resources, 2009.
PQA/ADA Conference & Exhibition 2009
NRCan DG Study Group
• Membership
– Utilities: BC Hydro, Hydro Quebec, NB Power
– Manufacturers: GE Multilink, SEL
– Private producers
• Activities
– Review of utility interconnection guidelines (Hydro
One)
– Provide advice on cost effective DG interconnection
technology
– Linking Smart Grid with DG
• Remote monitoring and control, advanced protection
17
Copyright © Her Majesty the Queen in Right of Canada, as represented by the Minister of
Natural Resources, 2009.
PQA/ADA Conference & Exhibition 2009
Canadian Test Facilities
¾Low voltage test facility (CanmetENERGY):
– Multiple inverters and interconnection testing
• 120-kVA, 3ph Grid
simulator
• 5kW/15kW Solar Simulator
• Adjustable RLC loads
ØMedium voltage test facility (IREQ-HQ):
– Distribution automation network testing
• A radial 25-kV feeder (20 poles,
370m)
• 300-kW, 600 V, resistive,
inductive and motor loads
• Induction and synchronous
generators
18
Copyright © Her Majesty the Queen in Right of Canada, as represented by the Minister of
Natural Resources, 2009.
PQA/ADA Conference & Exhibition 2009
IREQ Voltage Regulator Testing
• In-line VR control modes
• Real and reactive power flow
• DG location
1
X1
VR
X2
25/0.6 kV
Substation
125/25 kV
25/0.6 kV
2
3
DG1
Synchronous Generator
0 - 200 kW
19
Copyright © Her Majesty the Queen in Right of Canada, as represented by the Minister of
Natural Resources, 2009.
RL Load
0 - 200 kW
PQA/ADA Conference & Exhibition 2009
Canadian Association of Members of Public
Utility Tribunals (CAMPUT)
• CAMPUT purposes:
– to improve public utility regulation in Canada; and
improve education of commissioners and staff of
public utility tribunals
• Provinces at various stages
– Automated meter reading (AMR) and Automated
meter infrastructure (AMI)
– Distribution automation
– Link to improving integration of renewable energy
through legislation (eg. Green energy act, Ontario).
• Increasing interest in CAN-USA regulators working
together
– US FERC-NARUC established a collaborative on
Smart Grid
20
Copyright © Her Majesty the Queen in Right of Canada, as represented by the Minister of
Natural Resources, 2009.
PQA/ADA Conference & Exhibition 2009
Survey of Regulators (NARUC and CAMPUT)
• Background:
– Regulators are guided by legislation
– Utilities are guided by regulations
• Survey conducted by Capgemini between Sept.-Nov.
2008
• Results show that regulators are at the very early stages
of an education and valuation process.
• When under legislative and or regulatory mandated
renewable targets – then smart grid investments had
more appeal if direct links can be made (eg. portfolio
standards)
• “Goalpost” keeps moving from AMR to AMI to Smart Grid
21
Copyright © Her Majesty the Queen in Right of Canada, as represented by the Minister of
Natural Resources, 2009.
PQA/ADA Conference & Exhibition 2009
Ontario – Encouraging Smart Grid and
Renewables
• Smart Grid Forum releases its finding – February 2009
• Green Energy Act created – feed-in tariffs for renewables
– May 14, 2009
• Ontario Energy Board (OEB) - draft guidelines on
planning for smart grid architecture - June 16, 2009
• Important elements:
– Creation of new deferral accounts for capital
investments incurred related to the development of a
smart grid or the accommodation of new renewables.
– Introduction of a mechanism to provide advance
funding for expenditures to accommodate new
renewables or develop a smart grid.
– Initial guidance to distributors on planning to
accommodate new renewables and a smart grid.
22
Copyright © Her Majesty the Queen in Right of Canada, as represented by the Minister of
Natural Resources, 2009.
PQA/ADA Conference & Exhibition 2009
Summary
• Canada’s existing electricity infrastructure was designed
prior to advances of the information age.
• The “smart grid” includes improvement in metering,
monitoring and control technologies
• Smart Grid is needed for future operation and management
of electricity networks and for the integration of renewable
and distributed energy.
• Coordinated research and demonstration projects required to
support the transition towards a smarter grid
• Shared knowledge and progress reported
23
Copyright © Her Majesty the Queen in Right of Canada, as represented by the Minister of
Natural Resources, 2009.
PQA/ADA Conference & Exhibition 2009
Questions?
1615, Lionel-Boulet, Varennes,
Québec, Canada
Smart Grid contact: David Beauvais
Email: [email protected]
Tel. +1 450-652-5995
Website: http://canmetenergy.nrcan.gc.ca
24
Copyright © Her Majesty the Queen in Right of Canada, as represented by the Minister of
Natural Resources, 2009.
PQA/ADA Conference & Exhibition 2009
EPRI Power Quality Applications (PQA) and
Advanced Distribution Automation (ADA)
2009 Conference and Exhibition
Future of Fault Location
and
Data Integration
Cristiana Dimitriu & George Baroudi
Con Edison
July 1, 2009
Future of Fault Location and Data Integration
• Reactance-to-Fault Overview
• Relay Data Integration
• Other SCADA Data Integration
• Looking Forward
2
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
Con Edison Company of NY
ƒ NYC and Westchester
27,13, 4 kV
ƒ 3.2 million electric customers
ƒ System peak load 13,141 MW
27, 4 kV
33,13, 4 kV
13 kV
3
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
Power Quality History
• Beginning in the early 90’s, power quality monitors (PQ
Nodes) were placed in secondary networks to monitor
voltage.
• Monitors and software were developed by EPRI and cofunded by Con Edison to measure power quality.
• The high-definition data was also useful in analysis of
system events, and PQNodes were placed in substations to
capture additional data.
4
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
TR #1
TR #2
PQ
TR #3
TR #4
TR #5
PQView
5
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
PQ Monitors Coverage
6
Regions
Networks
Substations
Manhattan
37
26
Brooklyn
12
7
Queens
6
5
Bronx
6
6
Westchester
3
12
Staten Island
2
5
Total
66
61
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
RTF History
• In 2005, engineers from Distribution Engineering, Power Quality
and R&D envisioned a further use of the stream of highdefinition data
• Working with Electrotek engineers, they developed computer
algorithms and graphical interfaces to locate faults on network
feeders
• This is the Reactance-To-Fault (RTF) system
• First applied in Manhattan, where it reduced fault locating time
during the first summer (2006) by more than one hour, it is now
used by all operating regions in Con Edison.
7
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
In = 2kA
Total Current
In = 4x2 = 8kA
In = 2kA
In = 8kA
In = 2kA
A-Ph
TR Bus Current
In = 2kA
Va
8
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
Bus Voltage Sags
on faulted phase
PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
Present RTF Application
Feeder
trips
Display on
VDIS
9
PQNode
captures
amps/volts
at S/S bus
PQView
software
calculates
reactance
Display as
map and
tabulation
RTF
matches
reactance
to feeder
model
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
Present RTF Application
10
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
Visual Distribution Information System (VDIS)
11
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
Working Progress and Future Enhancements
• Expand substation monitoring capabilities
TR #1
12
TR #2
PQ
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
TR #3
PQ
TR #4
PQ
TR #5
PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
Relay / Comtrade Data
• Microprocessor Relay Data:
- Feeders
- Cap Banks
- Bus Sections
- Power Transformers
- Light & Power
• Recent Development
- All Relays Targets and Pickups (Digital Channels) are now
stored in PQView, along with fault waveforms and RMS data.
• Analog relay data (channels) provide info for:
Fault Locating (RTF), Inrush, and Sub-Cycle events.
13
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
Relay / Comtrade Data
• Relay Types:
- GE F60
- 32 samples/cycle
- Schweitzer SEL 351
- 4 samples/cycle
- Bassler (1 substation) - 24 samples/cycle
• 10 Substations equipped with Microprocessor Relays (New, Retrofit)
• Relay Data Integration issues:
- Date format in *.cfg file not per IEEE 1159 Standard and
Comtrade version not consistent (1997 vs. 1999)
- Data not being saved to folder with correct Date Modified
- Microprocessor Relays not equipped with voltage input
- Microprocessor Relays not equipped with LAN Lines
14
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
15
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
Feeder Fault – GE F60 Relay Targets
Murray Hill 12M77 - 9/10/2008 08:07:15.6374
15000
Va
Vb
Vc
Ia
Ib
Ic
Ires
Voltage (V)
10000
5000
0
-5000
-10000
-15000
Current (A)
20000
10000
0
-10000
0.50
16
C-Phase Fault
1C
-20000
0.52
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
0.54
0.56
Time (s)
0.58
0.60
0.62
PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
Feeder Fault Digital Relay Targets/Pick-up
C-phase Instantaneous-Over-Current Op
C-Phase Fault
17
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
Feeder Fault – GE F60 Relay Targets
Murray Hill 12M77 - 9/10/2008 08:07:15.6374
Va
Vb
Vc
Ia
Ib
Ic
Ires
15000
Voltage (V)
10000
5000
0
-5000
-10000
Digital Channel
Osc Trig On
PHASE IOC1 OP C
PHASE TOC1 PKP C
GROUND TOC1 PKP
Trip
On
-15000
Current (A)
20000
10000
0
-10000
PHASE IOC1 OP C On
-20000
0.50
0.55
PHASE IOC1 OP C Off
0.60
Time (s)
0.65
0.70
Q
18
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
Feeder Fault – GE F60 - Reactance Calculation
Murray Hill 12M77 - 9/10/2008 08:07:15.6374
Voltage (V)
Reactance to Fault
Va
Vb
Vc
Vab
Vbc
Vca
Ia
Ib
Ic
Iab
Ibc
Ica
Ires
XTF
10000
5000
Reactance (O)
Current (A)
15000
10000
5000
0
1.0
0.5
0.0
0.50
19
0.52
C-Phase Fault
0.05351 (k1=3.800)
1C
0.54
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
0.56
0.58
Time
0.60
0.62
0.64
PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
Feeder Fault – SEL (Schweitzer) – Relay Targets & Reactance Calculation
White Plains 8W70 SEL - 5/21/2009 10:13:23.7138
Duration: 4.500c
Va
Vc
Ia
Ib
Ic
Voltage (V)
5000
White Plains 8W70 SEL - 5/21/2009 10:13:23.7138
Reactance to Fault
-0
Voltage (V)
-5000
5000
0
-5000
Current (A)
Current (A)
Digital Channel
OUT1
50B1
50B
51P
51PR
51N
51NR
50P1
67P1
67P1T
50QF
50QR
50GF
50GR
50L
SV1
FSB
52A
3PO
TRIP
IN1
Vb
Va
Vb
Vc
Vab
Vbc
Vca
Ib
Ic
Iab
Ibc
Ica
XTF
Ia
8000
6000
4000
6000
0
Relay Targets
2
4
6
8
Time (c)
Reactance (O)
51P50GR
51N
51NR
50QF
50QR
50GF
OnFSB
51PR
50B1
On
On
Off
OnOn
On
OffTRIP
OUT1
50B
50P1
67P1
67P1T
SV1
On
On
On
On
On 50B OffSV1
50B1
50P1
67P1
67P1T
IN1Off
FSB
52A
Off
51P
51N
50GF
50GR
50L
3PO
Off
50QF
50QR
Off
Off
Off
Off
On
Off
Off
Off
Off
4000
10
12
14
2000
0
2
1
0.3906 (k1=1)
1B|Rs0=0.1246|Xs0=0.4237
2
20
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
4
6
8
Time (c)
RTF Calculation
10
12
14
PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
Feeder Fault – GE & SEL - Reactance Calculation
White Plains 8W70 - 5/21/2009 10:13:22.9982
Reactance to Fault
Voltage (V)
Va
Vb
Vc
Ia
Ib
Ic
XTF
8000
7000
White Plains 8W70 SEL - 5/21/2009 10:13:23.7138
7500
Reactance to Fault
5000
Va
2500
Voltage (V)
0
GE
0.4
0.2
0.07027 (k1=14.90)
1B
0.76
0.78
0.80
0.82
0.84
Time
GE RTF = 0.07 ohms
SEL RTF = 0.069 ohms
0.86
0.88
Current (A)
Reactance (O)
Vb
Vc
Ia
Ib
Ic
XTF
6000
5000
4000
6000
4000
0.90
0.92
2000
Reactance (O)
Current (A)
6000
0
0.4
0.3
SEL
0.2
0.1
1B
0.05
0.06934 (k1=14.90)
0.10
0.15
0.20
0.25
Time
21
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
Feeder Fault – GE & SEL - Reactance Calculation
White Plains 8W70 - 5/21/2009 10:13:22.9982
Reactance to Fault
Vc
Ia
Ib
Ic
XTF
Voltage (V)
Vb
8000
Current (A)
Va
7500
White Plains 8W70 SEL - 5/21/2009 10:13:23.7138
5000
Reactance to Fault
7000
6000
2500
Va
Voltage (V)
0.4
0.07027 (k1=14.90)
1B|Rs0=0.1284|Xs0=0.4207
40
45
50
55
Time (c)
K1 = 14.9
SEL RTF = 0.0703 ohms
GE RTF = 0.0693 ohms
PQNode RTF = 0.1898 ohms
Current (A)
0.2
35
Vc
Ia
Ib
Ic
XTF
5000
4000
60
6000
65
4000
2000
Actual Fault = 0.24 ohms
22
Vb
6000
Reactance (O)
Reactance (O)
0
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
0
0.4
0.3
0.2
0.06934 (k1=14.90)
1B|Rs0=0.1246|Xs0=0.4237
0.1
2
4
6
8
Time (c)
10
12
14
PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
CAP Bank Fault – GE F60
White Plains Cap_1 - 6/11/2008 05:23:44.6172
15000
Va
Vb
Vc
Ia
Ib
Ic
Ires
Voltage (V)
10000
5000
0
-5000
-10000
-15000
Current (A)
50000
0
-50000
0.66
23
0.68
0.70
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
0.72
Time (s)
0.74
0.76
0.78
PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
CAP Bank Fault – GE F60 Reactance Calculation
White Plains Cap_1 - 6/11/2008 05:23:44.6172
Reactance to Fault
Voltage (V)
40000
Reactance (O)
7500
Current (A)
Va
Vc
Ia
Ib
Ic
Ires
XTF
5000
2500
20000
0
1.0
0.5
1B 0.03507 (k1=1)
0.0
0.65
24
Vb
0.70
0.75
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
0.80
Time
0.85
0.90
PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
CAP Bank Fault – GE F60 - Relay Targets
White Plains Cap_1 - 6/11/2008 05:23:44.6172
Va
Vb
Vc
Ia
Ib
Ic
Ires
Relay Targets
5000
0
-5000
-10000
-15000
50000
Current (A)
Digital Channel
Osc Trig On
PHASE IOC1 OP A
PHASE IOC1 OP B
PHASE IOC1 OP C
PHASE TOC1 PKP A
PHASE TOC1 PKP B
PHASE TOC1 PKP C
Trip
On
TRIP
IOn
CB Status On
Voltage (V)
10000
0
-50000
PHASE IOC1 OP B On
0.68
25
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
0.70
PHASE IOC1 OP B Off
0.72
Time (s)
0.74
0.76
PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
CAP Bank Fault - Transformer 1 – GE T60 Relay Pickup – 3 Phases
WPlains Tr1 87-50 - 6/11/2008 05:23:44.7204
Ia
Ib
Ic
Ires
15000
10000
Digital Channel
Trig Osc On
XFMR PCNT DIFF 2ND A
XFMR PCNT DIFF 2ND B
XFMR PCNT DIFF 2ND C
Current (A)
5000
0
-5000
-10000
-15000
XFMR
XFMRPCNT
PCNT
XFMR
DIFF
DIFF2ND
PCNT
2NDAAOn
DIFF
Off 2ND AXFMR
Off PCNT DIFF 2ND A On
-20000
0.55
0.60
0.65
Time (s)
26
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
CAP Bank Fault - Transformer 1 – GE F60 Relay Pickup
Phase, Gnd TOC, Phase Undervoltage
WPlains Tr1_ 51V-51N - 6/11/2008 05:23:44.1219
Va
Vb
Vc
Ia
Ib
Ic
Ires
Voltage (V)
10000
Digital Channel
PHASE TOC1 PKP A
GROUND TOC1 PKP
Trig Osc On
PHASE UV1 OP A
PHASE UV1 OP B
PHASE UV1 OP C
5000
0
-5000
-10000
Current (A)
-15000
2000
1000
0
-1000
GROUND TOC1 PKP On
GROUND TOC1 PKP Off
1.16
27
1.18
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
1.20
1.22
Time (s)
1.24
1.26
PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
Feeder Fault – Bassler Relay
NO VOLTAGE Available at Station, No Reactance calculation
North Queens 1Q08 - 9/1/2008 23:23:09.5140
Ia
Ib
Ic
In
Ires
10000
8000
6000
Current (A)
4000
2000
0
-2000
-4000
-6000
-8000
-10000
-12000
0.04
28
0.05
0.06
0.07
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
0.08
Time (s)
0.09
0.10
0.11
0.12
PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
Feeder Fault – Bassler Relay - Relay Targets
North Queens 1Q08 - 9/1/2008 23:23:09.5140
Ia
Ib
Ic
In
Ires
10000
8000
6000
4000
Current (A)
Digital Channel
51NT
TRIP
150TPT
150TPPU
51PPU
VO12_LABEL
INPUT_1
50TPT
150TNT
50TPPU
150TNPU
51NPU
VO11_LABEL
2000
0
-2000
-4000
-6000
-8000
-10000
Relay Targets
50TPT On
-12000
0.04
0.06
50TPT Off
0.08
0.10
Time (s)
• Relay digital channels (targets, and pick-up) are named differently in SEL, GE F60, this may create
confusion.
• Relay digital channels (targets, pick-up) will display the type of relay that operated/picked-up but not the
faulted phase.
29
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
Bassler Relay - How to Identify Faulted Phase?
• Relay Target Phases are available in a log file (txt) generated by the Bassler Relay.
• The log (txt) file should be integrated in PQView to automatically identify the faulted
phase, and send a notification (Future Development).
30
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
Fault CIOA
Seaport#1 40M43 (43A) - 1/4/2009 12:00:58.1925
Va
Vb
Vc
Ia
Ib
Ic
1
0
-1
-2
10000
Current (A)
Digital Channel
PHASE IOC1 OP C
PHASE TOC1 PKP A
PHASE TOC1 PKP C
GROUND TOC1 PKP
Trip
On
TRIP
IOn
GROUND IOC1 PKP
GROUND IOC1 OP
PHASE IOC1 PKP C
PHASE IOC1 OP
PHASE TOC1 PKP
GROUND TOC1 DPO
PHASE IOC1 PKP
PHASE IOC1 DPO
GROUND IOC1 DPO
Trip
IOff
Voltage (V)
2
5000
0
-5000
-10000
-15000
PHASE TOC1 PKP On
0.18
Electrotek/EPRI
31
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
0.20
PHASE TOC1
PHASE
GROUND
PKP
TOC1
Trip
GROUND
A
TOC1
OnPKP
TRIP
Trip
PKP
DPO
PHASE
On
C
IOC1
On
On
OffPHASE
PKP
OP
DPO
IOff
PHASE
TOC1
IOn
PHASE
PHASE
PHASE
On
PHASE
Off
On
Off
PHASE
On
PHASE
PHASE
IOC1
PKP
PHASE
IOC1
IOC1
IOC1
IOC1
IOC1
A
PKP
IOC1
IOC1
IOC1
OP
Off
DPO
PKP
IOC1
OP
PKP
C
C
TRIP
OP
DPO
Trip
On
PKP
On
Off
On
OP
C
C Off
Off
On
Off IOn
IOff Off
On
0.22
Time (s)
0.24
0.26
PQView®
PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
Inrush (Feeder Restoration)
32
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
Subcycle Event Feeder 8W64 - GE F60 Relay
Subcycle
33
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
Relay RTF Website - Development
34
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
Relay data Æ RTF = 0.1747
35
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
Substation PQ Monitor data Æ RTF = 0.1661
36
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
37
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
38
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
Working Progress and Future Enhancements
• Enhance Web PQView to allow intranet viewing of DigitalRelay Targets
Channels.
• Define and understand the functions of all the Relay Targets
available especially for XFRs, and Bus Sections. Also standardize
the Relay Naming convention between the Bassler, SEL, and GE
F60.
• Integrate relay data (Analog, Digital Channels) into Visual
Distribution, and other applications (FMS).
• Extend RTF application to the overhead distribution system
• Integrate SCADA from unit substations
• Integrate data from AMI’s
39
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
Working Progress and Future Enhancements
Multiple-feeder Outage
40
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
Thank you!
Questions?
41
Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved.
PQA/ADA Conference & Exhibition 2009
Integrated Analysis of Power
System Disturbances
Fred Elmendorf, Theo Laughner
TVA
Mark McGranaghan, Chris Melhorn,
Zhiming Dai, Paul Myrda
EPRI
AKA - How to prepare for the impending
Data Tsunami
http://www.bionomicfuel.com/wp-content/uploads/2008/10/energy-produced-by-tidal-waves_2.jpg
© 2009 Electric Power Research Institute, Inc. All rights reserved.
2
Background – PQ Monitoring Systems
Traditional Uses
• Benchmarking
Potential Uses
• Health Assessments
• Standards Compliance
• Performance Analysis
• Consumer Issue
Resolution
• Fault Detection
Requirements
• Integrated Information
System
• Standalone
© 2009 Electric Power Research Institute, Inc. All rights reserved.
3
Outline
• Concept of an Integrated Power Monitoring System
• Applications
• Integration Requirements
• Important Concepts for System Events
• Examples of System Event Analysis
© 2009 Electric Power Research Institute, Inc. All rights reserved.
4
© 2009 Electric Power Research Institute, Inc. All rights reserved.
5
Wide range of applications that can take
advantage of integrated data
• Fault analysis - fault location, fault cause identification, trends of
fault conditions indicating problems.
• Incipient faults associated with arresters, cracked insulators,
cable splices, etc.
• Evaluation of breaker and relay performance – timing, pole
spans, coordination, evaluation of fault duties, maintenance
requirements.
• Capacitor application evaluations – identification of switching
problems, can failure identification, harmonic resonance
problems, restrikes, performance of synchronous closing control.
• Transformer assessments – loading evaluations, harmonic
duty, fault duty, identification of possible problems from
harmonics and unbalances.
• Tap changer and voltage regulator assessments –
identification of problems from disturbance waveforms (see
Figure 3), unbalanced conditions, voltage regulation
assessments.
• Distributed generation applications – evaluation of
performance with respect to interconnection requirements (e.g.
wind farms).
© 2009 Electric Power Research Institute, Inc. All rights reserved.
6
Applications that can help improve reliability
and security of the system
© 2009 Electric Power Research Institute, Inc. All rights reserved.
7
Smart Grid Monitoring System –
Grid Data Sources
Information
• Characterizing the grid in real time and for post event analysis
is dependant upon a network of sensors, meters and devices
providing data on regular basis.
Analytics
D
A
T
A
Data Integration
D
A
T
A
D
A
T
A
D
A
T
A
D
A
T
A
D
A
T
A
Automated
Substations
Security
Equipment
Monitoring
Digital Relays
Data
Communication
Grid
GridData
Data
Sources
Sources
IED’s, DFRs, SERs, PMU’s, Remote video, Line monitors,
smart sensors, Intelligent grid devices: switches, reclosers,
cap controllers, etc., Cable monitors, Weather data, BPL as
sensor, Meter as sensor
© 2009 Electric Power Research Institute, Inc. All rights reserved.
8
LAN
Sensors
Smart Grid Monitoring System –
Data Communication
Information
• Open Standards based Digital Communication Networks allow
devices to communicate securely with the Enterprise
•Extensive array of options available
•Public and private digital networks
Analytics
•Wired, wireless, and optical
Utility
Applications
Data Integration
D
A
T
A
Data
Data
Communication
Communication
D
A
T
A
Grid Data
Sources
D
A
T
A
D
A
T
A
D
A
T
A
D
A
T
A
Automated
Substations
Security
Equipment
Monitoring
© 2009 Electric Power Research Institute, Inc. All rights reserved.
D
A
T
A
9
Digital Relays
LAN
Sensors
Smart Grid Monitoring System –
Data Integration
Information
• Utility Common Information Model (CIM) Analytics data warehouse
• Integration Middleware allows data flow to Analytics Data Warehouse
Analytics
External
Applications
CIM Based Analytics
Data Warehouse
Substation to Transmission Lines
Transmission Line Segment
Substation ID (FK)
Transmission Line ID (FK)
Segment ID (FK)
Transmission Line ID (FK)
Segment ID
P
P
Data
DataIntegration
Integration
P
Transmission Line ID
IED Type
Business Units
P
Business Unit ID
Substations
IEDs
Substation ID
IED ID
Business Unit ID (FK)
Central Station ID (FK)
Utility
Applications
P
1
Central Stations
P
Central Station ID
Substation ID (FK)
IED Type (FK)
Weather Stations
P
Weather Station ID
IEDs to Circuit Breakers
Substation ID (FK)
Pub/Sub
Middleware
IED ID (FK)
Circuit Breaker ID (FK)
Power Transformers
Power Transformer ID
Substation ID (FK)
P
Sensors
P
Sensor ID
1
Sensor Type (FK)
Substation ID (FK)
IED ID (FK)
Hydran Unit ID (FK)
Weather Station ID (FK)
Hydran Units
Hydran Unit ID
Power Transformer ID (FK)
Circuit Breakers
Circuit Breaker ID
Sensor Types
Data
Communication
Grid Data
Sources
Transmission Lines
IED Types
Sensor Readings
Sensor Type
Sensor ID (FK)
Timestamp
Results in
• Enterprise wide
information model
• Assets defined one
time in the Network
• Connect all types of
meta data with asset
• No information silos
Units of
UOM
Sensor Type Description
UOM (FK)
Sensor Reading Value
Automated
Substations
Security
Equipment
Monitoring
© 2009 Electric Power Research Institute, Inc. All rights reserved.
10
Digital Relays
LAN
Sensors
Smart Grid Monitoring System –
Analytics
Information
• Analytics are dependant upon access to data
• Higher levels of analytics require more access to data
Analytics Levels of Complexity
Analytics Engine
Analytics
Analytics
Data Integration
External
Applications
CIM Based Analytics
Data Warehouse
Substation to Transmission Lines
Data
Communication
Transmission Line Segment
Substation ID (FK)
Transmission Line ID (FK)
Segment ID (FK)
Transmission Line ID (FK)
Segment ID
P
P
P
Transmission Lines
IED Types
Transmission Line ID
IED Type
Business Units
P
Business Unit ID
Substations
IEDs
Substation ID
IED ID
Business Unit ID (FK)
Central Station ID (FK)
Utility
Applications
P
1
Central Stations
P
Central Station ID
Substation ID (FK)
IED Type (FK)
Weather Stations
P
Weather Station ID
Pub/Sub
Middleware
IEDs to Circuit Breakers
Substation ID (FK)
IED ID (FK)
Circuit Breaker ID (FK)
Power Transformers
Power Transformer ID
Substation ID (FK)
P
Sensors
P
Sensor ID
1
Sensor Type (FK)
Substation ID (FK)
IED ID (FK)
Hydran Unit ID (FK)
Weather Station ID (FK)
Hydran Units
Hydran Unit ID
Power Transformer ID (FK)
Circuit Breakers
Circuit Breaker ID
Sensor Types
Sensor Readings
Sensor Type
Sensor ID (FK)
Timestamp
1. Real time alarms, thresholds screen display, message, pager
2. Calculated metrics, trends tailored notifications
3. Analysis of data, events
diagnostics, both real time and
post event, data mining
4. Advanced optimizations,
modeling, planning, decision
support
Units of Measure
UOM
Sensor Type Description
UOM (FK)
Sensor Reading Value
Grid Data
Sources
Automated
Substations
Security
Equipment
Monitoring
© 2009 Electric Power Research Institute, Inc. All rights reserved.
Digital Relays
11
LAN
Sensors
Smart Grid Monitoring System –
Information
Information
Information
• Analytics generate actionable information
• Analytics depend greatly upon observable level of
information and integration with other applications
Portal/Dashboards
Analytics
Data Integration
Informed
Decision
Making
Information
Analytics support
management of:
© 2009 Electric Power Research Institute, Inc. All rights reserved.
12
Revenue
Risks
Costs
Grid Data
Sources
– Asset Lifecycle
– Operations
– Workforce
– Planning
– Customer
Reliability
Data
Communication
Operations
Maintenance
Finance
Planning
Engineering
Customers
Business Intelligence…Presented on
Dashboards
© 2009 Electric Power Research Institute, Inc. All rights reserved.
13
System Event Concepts
• Requirements for coordinating system events
– Information sources (coordinated data collection)
– Time synchronization requirements
– Data management requirements (common information model,
terminology)
• Other integration requirements for analysis of system events
– Models (e.g. for fault location)
– Model synchronization
– SCADA/EMS/DMS – system operations, conditions
– Asset databases
– Customer Information Systems, Outage Management System
– Other information systems (lightning, weather, traffic, etc.)
© 2009 Electric Power Research Institute, Inc. All rights reserved.
14
Examples of System Event Data and Analysis
Total Bank Covington, from 05/01/2005 to 02/01/2009
Voltage Magnitude (pu)
2.0
Event Count: 20
Event Count ITIC Lower Curve: 9
Time Stamp
1.5
ITIC – VL‐GND Only
1.0
0.5
70%
0.0
10 -3
10 -2
10 -1
10 0
Duration (s)
EPRI/Electrotek
10 1
10 2
10 3
PQView®
The 26‐month study looks at 20 events with 9 events creating voltage sags below 70% of nominal (VL‐GND). More importantly, there were 9 events where the VLL went below 70% of nominal at the 161‐kV bus. These events (maybe all) likely caused ASDs (AC and/or DC) to shut down at industrial locations. Customers likely called to complain. 10/17/2005 08:29:12.345
BC
0.884
B
0.778
0.075
4.5
11/15/2005 14:49:05.949
AB
0.687
B
0.725
0.075
4.5
11/15/2005 15:36:55.644
AB
0.828
A
0.780
0.042
2.5
12/31/2005 12:30:22.075
AB
0.655
B
0.763
0.158
9.5
02/21/2006 22:14:50.812
CA
0.744
C
0.651
0.050
3.0
03/13/2006 08:06:41.983
BC
0.847
B
0.797
0.033
2.0
04/02/2006 19:04:25.703
CA
0.693
A
0.773
0.042
2.5
04/02/2006 19:25:10.958
CA
0.683
C
0.646
0.058
3.5
04/02/2006 19:53:36.781
AB
0.696
A
0.744
0.042
2.5
04/02/2006 20:09:18.270
BC
0.648
B
0.715
0.042
2.5
04/07/2006 23:22:20.287
AB
0.814
B
0.780
0.042
2.5
04/12/2006 05:46:07.110
CA
0.791
C
0.562
0.067
4.0
04/15/2006 13:00:56.328
CA
0.832
C
0.639
0.083
5.0
05/21/2006 06:08:59.822
AB
0.676
A
0.511
0.092
5.5
08/20/2006 20:57:38.316
AB
0.787
A
0.559
0.075
4.5
10/01/2006 16:27:11.156
BC
0.663
B
0.697
0.083
5.0
07/09/2008 23:30:25.620
CA
0.812
C
0.582
0.058
3.5
08/15/2008 14:46:54.137
BC
0.619
B
0.709
0.092
5.5
10/07/2008 04:52:32.886
AB
0.707
B
0.599
0.042
2.5
11/06/2008 18:04:57.871
BC
0.816
C
0.770
0.042
2.5
Yellow – VL‐Gnd <70%, VLL > 70% of Nominal, Red – VLL < 70% of Nominal
15
© 2009 Electric Power Research Institute, Inc. All rights reserved.
Worse
VLL
Worse
VLN
VLL Magnitude VLN Magnitude Duration Duration
Phase
(pu)
Phase
(pu)
(s)
(cyc)
15
Outside TVA
in Yellow
From
West –
Northern
Route
From
West –
Southern
Route
© 2009 Electric Power Research Institute, Inc. All rights reserved.
From North East – Northern Route
From North East –
Southern Route
500-kV
From
SE
System
16
Worse
VLL
VLL Magnitude Duration Duration
Phase
(pu)
(s)
(cyc)
Time Stamp
11/15/2005 14:49:06.000
0.687
0.075
4.5
82%
100
g
150
50
0
-50
-100
Actual DFR Shot
68.7%
100
% of Nominal Voltage
Percent of Nominal VAB
AB
y
150
and
50
PQ Monitor Shot
0
-50
-100
-150
100
150
200
Time (ms)
250
-150
0.00
0.05
0.10
0.15
Time ( s)
Simulated Fault
DFR
Currents
© 2009 Electric Power Research Institute, Inc. All rights reserved.
17
150
100
100
PERCENT OF NOMINAL VAB
PERCENT OF NOMINAL VAB
150
50
0
-50
65.5% ‐ Min.
-100
-150
0.00
0.05
0.10
50
-50
25% ‐ Min.
-100
0.15
0.20
0.25
-150
200
250
300
150
S
350
400
450
Time (ms)
TIME (MS)
V
All Data Actual DFR and
PQ VAB Waveforms From
Event
0
6
500‐kV Network
150
VAB JOHNSONVILLE DFR (FAULT LOCATION)
100
PERCENT OF NOMINAL VAB
0
-50
65% ‐ Min.
-100
-150
100
50
Ph‐Ph
0
Arcing Fault
-50
5% ‐ Min.
-100
200
-150
250
300
Time (ms)
300
350
400
450
500
400
450
500
Time (ms)
150
150
PERCENT OF NOMINAL VAB
100
100
150
50
100
PERCENT OF NOMINAL VAB
PERCENT OF NOMINAL VAB
PERCENT OF NOMINAL VAB
100
In Blue
50
0
-50
68% ‐ Min.
-100
-150
100
150
200
250
300
Time (ms)
350
50
-50
-150
250
-50
-100
250
300
350
18
18
35% ‐ Min.
300
350
Time (ms)
50% ‐ Min.
Time (ms)
© 2009 Electric Power Research Institute, Inc. All rights reserved.
0
-100
0
-150
200
50
400
450
High Winds/Tornado
Impact 500‐kV
System in Arkansas
Time Stamp
04/02/2006 19:04:25.703
19
Worse VLL Phase
CA
Fault on 500-kV
System –
VLL Magnitude (pu)
Duration (s)
Duration (cyc)
Arkansas
0.693
0.042
2.5
150
Case #6 ‐ Fault at 19:04 on April 2, 2006
Occurred Off TVA System ‐ Probably on 500‐kV System in Yellow Block Area Located in Arkansas
50
0
-50
-100
-150
0.00
0.02
0.04
69.3%
0.06
Time ( s)
0.08
0.10
0.12
150
100
Percent of Nominal VCA
PERCENT OF NOMINAL VCA
100
50
0
-50
-100
-150
100
© 2009 Electric Power Research Institute, Inc. All rights reserved.
150
67.7%
200
Time (ms)
250
300
20
500‐kV Ph‐Ph‐Gnd Fault on Weakley Lagoon Creek 500‐kV Line
Towers Down and Line Locked Open ‐ Both 500‐kV Paths From Johnsonville 500 to Memphis Area Out of Service
150
PERCENT OF NOMINAL VBC
100
50
0
-50
-100
-150
0.00
64.8%
0.02
0.04
0.06
Time ( s)
0.08
0.10
0.12
Tornado Path
150
PERCENT OF NOMINAL VBC
100
50
0
VBC
-50
-100
-150
100
21
150
62.0%
200
Time (ms)
250
20.6%
300
© 2009 Electric Power Research Institute, Inc. All rights reserved.
21
© 2009 Electric Power Research Institute, Inc. All rights reserved.
22
DFR:
Fault Occurred: 19:28:42.876 CDT
Duration: 23 cycles
Bus Voltage: Dipped to 60% of Nominal
© 2009 Electric Power Research Institute, Inc. All rights reserved.
23
PMU
500 kV Bus Voltages
Took about 7 seconds for the voltage to recover back to nominal value
70% Nominal
© 2009 Electric Power Research Institute, Inc. All rights reserved.
24
Three Phase Fault
30% of Nom. For 3 Cycles
LSC Sites Sagging Below 70% of Nominal Voltage
Ground Switch
Event
25
© 2009 Electric Power Research Institute, Inc. All rights reserved.
25
4
Web-Based Application Integration
© 2009 Electric Power Research Institute, Inc. All rights reserved.
26
Line L5934 Substation A
Substation B
Fault Location
Str 14
© 2009 Electric Power Research Institute, Inc. All rights reserved.
27
In Summary…What is Key about this Project?
• Taking advantage of sensors throughout the system
• Many applications can use advanced monitoring
information (PQ, waveforms)
• Integration is required for the functionality of these
applications
• System event concept requires synchronization of data
and common terminology
• Effective utilization of Industry Standards
– IEC 61850 in substations
– Common Information Model for Enterprise Integration
• Web-Based Services to make applications available to
wide range of users with simple interfaces
© 2009 Electric Power Research Institute, Inc. All rights reserved.
28
© 2009 Electric Power Research Institute, Inc. All rights reserved.
29
…wax your digital surf board
and get ready for a wild ride!
www.savvyminds.com/SamplesSubpages/Tsunami.htm
© 2009 Electric Power Research Institute, Inc. All rights reserved.
30
Questions?
© 2009 Electric Power Research Institute, Inc. All rights reserved.
31