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Review of Canadian Smart Grid Initiatives
Chad AbbeyCanmetENERGY, Natural Resources CanadaJuly 1, 2009
EPRI Power Quality Applications (PQA) and Advanced Distribution Automation (ADA)
2009 Conference and Exhibition
2Copyright © Her Majesty the Queen in Right of Canada, as represented by the Minister of Natural Resources, 2009. PQA/ADA Conference & Exhibition 2009
Overview
• Overview of industry activities
• Specific Smart Grid initiatives
• DER and the Smart Grid
• Testing facilities
• Perspective from regulators
• Summary
3Copyright © 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
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
4Copyright © Her Majesty the Queen in Right of Canada, as represented by the Minister of Natural Resources, 2009. PQA/ADA Conference & Exhibition 2009
New New TechnologyTechnology –– KinectsKinects Feeder Feeder CurrentCurrent Monitoring (FCM)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
5Copyright © 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 Leveraging Smart Meter Technology Milton Hydro ExampleMilton Hydro Example
Source: Leveraging Smart Meter Technology at Milton Hydro, R. Brajovic, presented at EDIST 2009 Conference, Markam, Ontario
6Copyright © 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 Comparing Smart Meter Customer Data and Distribution Transformer MeasurementsDistribution Transformer Measurements
Source: Leveraging Smart Meter Technology at Milton Hydro, R. Brajovic, presented at EDIST 2009 Conference, Markam, Ontario
7Copyright © 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 Transformer Monthly Loading using hourly interval data from each customerusing hourly interval data from each customer
Source: Leveraging Smart Meter Technology at Milton Hydro, R. Brajovic, presented at EDIST 2009 Conference, Markam, Ontario
8Copyright © 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) New Engineering Planning Tool (needs AMI) Energy Profile ManagerEnergy Profile Manager
• Metered load and generator profiles •Meter demand and network demand profiles
Source: Leveraging Smart Meter Data, CYME International, St-Bruno, Quebec.
9Copyright © 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 GroupCEATI 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
10Copyright © 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 ForumOntario 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
11Copyright © 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 Utilities Telecom Council (UTC) Canada request dedicated spectrumrequest 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
12Copyright © 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
13Copyright © 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
14Copyright © 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
15Copyright © 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 (2007)
Source: M.Dang, Hydro One, March 25, 2008
Orangeville
Goderich
16Copyright © Her Majesty the Queen in Right of Canada, as represented by the Minister of 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)
17Copyright © 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
18Copyright © 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
Low voltage test facility (CanmetENERGY):– Multiple inverters and interconnection testing
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
• 120-kVA, 3ph Grid simulator
• 5kW/15kW Solar Simulator• Adjustable RLC loads
19Copyright © 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
Substation125/25 kV
25/0.6 kV
DG1
VR
25/0.6 kV
X2
RL Load0 - 200 kW
Synchronous Generator0 - 200 kW
X1
2 3
1
20Copyright © Her Majesty the Queen in Right of Canada, as represented by the Minister of Natural Resources, 2009. 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
21Copyright © 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
22Copyright © 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.
23Copyright © 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
24Copyright © Her Majesty the Queen in Right of Canada, as represented by the Minister of Natural Resources, 2009. PQA/ADA Conference & Exhibition 2009
1615, Lionel-Boulet, Varennes, Québec, Canada
Smart Grid contact: David BeauvaisEmail: [email protected]
Tel. +1 450-652-5995Website: http://canmetenergy.nrcan.gc.ca
Questions?
Future of Fault Location and
Data Integration
Cristiana Dimitriu & George BaroudiCon EdisonJuly 1, 2009
EPRI Power Quality Applications (PQA) and Advanced Distribution Automation (ADA)
2009 Conference and Exhibition
2 Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved. PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
• Reactance-to-Fault Overview
• Relay Data Integration
• Other SCADA Data Integration
• Looking Forward
3 Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved. PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
27,13, 4 kV
13 kV
27, 4 kV
33,13, 4 kV
Con Edison Company of NYNYC and Westchester3.2 million electric customersSystem peak load 13,141 MW
4 Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved. PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
• 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 co- funded 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.
Power Quality History
5 Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved. PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
PQView
PQTR #1 TR #2 TR #3 TR #4 TR #5
6 Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved. PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
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
PQ Monitors Coverage
7 Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved. PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
• In 2005, engineers from Distribution Engineering, Power Quality and R&D envisioned a further use of the stream of high- definition 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.
RTF History
8 Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved. PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
A-Ph
Va Bus Voltage Sags on faulted phase
In = 8kA
Total CurrentIn = 4x2 = 8kA
In = 2kATR Bus Current
In = 2kA
In = 2kA
In = 2kA
9 Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved. PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
Feeder trips
RTFmatches
reactance to feeder
model
PQNode captures
amps/voltsat S/S bus
PQView software
calculates reactance
Display asmap andtabulation
Display on VDIS
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
Present RTF Application
11 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)
12 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
PQTR #1 TR #2 TR #3 TR #4 TR #5
PQ PQ
• Expand substation monitoring capabilities
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
• 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.
14 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
15 Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved. PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
16 Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved. PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
1C
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0.50 0.52 0.54 0.56 0.58 0.60 0.62
Murray Hill 12M77 - 9/10/2008 08:07:15.6374
Vol
tage
(V)
Cur
rent
(A)
Time (s)
Va Vb Vc Ia Ib Ic Ires
Feeder Fault – GE F60 Relay Targets
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 Digital Relay Targets/Pick-up
C-Phase Fault
C-phase Instantaneous-Over-Current Op
18 Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved. PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
PHASE IOC1 OP C On PHASE IOC1 OP C Off
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Murray Hill 12M77 - 9/10/2008 08:07:15.6374
Q
Digital ChannelOsc Trig OnPHASE IOC1 OP CPHASE TOC1 PKP CGROUND TOC1 PKPTrip On
Vol
tage
(V)
Cur
rent
(A)
Time (s)
Va Vb Vc Ia Ib Ic Ires
Feeder Fault – GE F60 Relay Targets
19 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
1C 0.05351 (k1=3.800)
5000
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0
5000
10000
15000
0.0
0.5
1.0
0.50 0.52 0.54 0.56 0.58 0.60 0.62 0.64
Murray Hill 12M77 - 9/10/2008 08:07:15.6374Reactance to Fault
Vol
tage
(V)
Cur
rent
(A)
Rea
ctan
ce (O
)
Time
Va Vb Vc Vab Vbc Vca Ia
Ib Ic Iab Ibc Ica Ires XTF
C-Phase Fault
20 Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved. PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
Feeder Fault – SEL (Schweitzer) – Relay Targets & Reactance Calculation
1B|Rs0=0.1246|Xs0=0.42370.3906 (k1=1)
4000
6000
8000
0
2000
4000
6000
1
2
2 4 6 8 10 12 14
White Plains 8W70 SEL - 5/21/2009 10:13:23.7138Reactance to Fault
Vol
tage
(V)
Cur
rent
(A)
Rea
ctan
ce (O
)
Time (c)
Va Vb Vc Vab Vbc Vca Ia
Ib Ic Iab Ibc Ica XTF
OUT1 On50B1 On 50B1 Off50B On 50B Off51P On 51P Off51PR Off51N On 51N Off51NR Off 50P1 On 50P1 Off67P1 On 67P1 Off67P1T On 67P1T Off50QF On 50QF Off50QR On 50QR Off50GF On 50GF Off50GR On 50GR Off50L OffSV1 On SV1 OffFSB On FSB Off52A Off3PO OnTRIP On IN1 Off
-5000
-0
5000
-5000
0
5000
0 2 4 6 8 10 12 14
White Plains 8W70 SEL - 5/21/2009 10:13:23.7138Duration: 4.500c
Digital ChannelOUT150B150B51P51PR51N51NR50P167P167P1T50QF50QR50GF50GR50LSV1FSB52A3POTRIPIN1
Vol
tage
(V)
Cur
rent
(A)
Time (c)
Va Vb Vc Ia Ib Ic
Relay Targets
RTF Calculation
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
GE RTF = 0.07 ohms
SEL RTF = 0.069 ohms
1B 0.07027 (k1=14.90)
6000
7000
8000
0
2500
5000
7500
0.2
0.4
0.76 0.78 0.80 0.82 0.84 0.86 0.88 0.90 0.92
White Plains 8W70 - 5/21/2009 10:13:22.9982Reactance to Fault
Vol
tage
(V)
Cur
rent
(A)
Rea
ctan
ce (O
)
Time
Va Vb Vc Ia Ib Ic XTF
1B 0.06934 (k1=14.90)
4000
5000
6000
0
2000
4000
6000
0.1
0.2
0.3
0.4
0.05 0.10 0.15 0.20 0.25
White Plains 8W70 SEL - 5/21/2009 10:13:23.7138Reactance to Fault
Vol
tage
(V)
Cur
rent
(A)
Rea
ctan
ce (O
)
Time
Va Vb Vc Ia Ib Ic XTF
GE
SEL
22 Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved. PQA/ADA Conference & Exhibition 2009
1B|Rs0=0.1246|Xs0=0.42370.06934 (k1=14.90)
4000
5000
6000
0
2000
4000
6000
0.1
0.2
0.3
0.4
2 4 6 8 10 12 14
White Plains 8W70 SEL - 5/21/2009 10:13:23.7138Reactance to Fault
Vol
tage
(V)
Cur
rent
(A)
Rea
ctan
ce (O
)
Time (c)
Va Vb Vc Ia Ib Ic XTF
Future of Fault Location and Data Integration
Feeder Fault – GE & SEL - Reactance Calculation
K1 = 14.9
SEL RTF = 0.0703 ohms
GE RTF = 0.0693 ohms
PQNode RTF = 0.1898 ohms
Actual Fault = 0.24 ohms
1B|Rs0=0.1284|Xs0=0.42070.07027 (k1=14.90)
6000
7000
8000
0
2500
5000
7500
0.2
0.4
35 40 45 50 55 60 65
White Plains 8W70 - 5/21/2009 10:13:22.9982Reactance to Fault
Vol
tage
(V)
Cur
rent
(A)
Rea
ctan
ce (O
)
Time (c)
Va Vb Vc Ia Ib Ic XTF
23 Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved. PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
-15000
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0
5000
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0
50000
0.66 0.68 0.70 0.72 0.74 0.76 0.78
White Plains Cap_1 - 6/11/2008 05:23:44.6172
Vol
tage
(V)
Cur
rent
(A)
Time (s)
Va Vb Vc Ia Ib Ic Ires
CAP Bank Fault – GE F60
24 Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved. PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
1B 0.03507 (k1=1)
2500
5000
7500
0
20000
40000
0.0
0.5
1.0
0.65 0.70 0.75 0.80 0.85 0.90
White Plains Cap_1 - 6/11/2008 05:23:44.6172Reactance to Fault
Vol
tage
(V)
Cur
rent
(A)
Rea
ctan
ce (O
)
Time
Va Vb Vc Ia Ib Ic Ires XTF
CAP Bank Fault – GE F60 Reactance Calculation
25 Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved. PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
PHASE IOC1 OP B On PHASE IOC1 OP B Off
-15000
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0
5000
10000
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0
50000
0.68 0.70 0.72 0.74 0.76
White Plains Cap_1 - 6/11/2008 05:23:44.6172
Digital ChannelOsc Trig OnPHASE IOC1 OP APHASE IOC1 OP BPHASE IOC1 OP CPHASE TOC1 PKP APHASE TOC1 PKP BPHASE TOC1 PKP CTrip OnTRIP IOnCB Status On
Vol
tage
(V)
Cur
rent
(A)
Time (s)
Va Vb Vc Ia Ib Ic Ires
CAP Bank Fault – GE F60 - Relay Targets
Relay Targets
26 Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved. PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
XFMR PCNT DIFF 2ND A OnXFMR PCNT DIFF 2ND A Off XFMR PCNT DIFF 2ND A OnXFMR PCNT DIFF 2ND A Off-20000
-15000
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0
5000
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0.55 0.60 0.65
WPlains Tr1 87-50 - 6/11/2008 05:23:44.7204
Digital ChannelTrig Osc OnXFMR PCNT DIFF 2ND AXFMR PCNT DIFF 2ND BXFMR PCNT DIFF 2ND C C
urre
nt (A
)
Time (s)
Ia Ib Ic Ires
CAP Bank Fault - Transformer 1 – GE T60 Relay Pickup – 3 Phases
27 Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved. PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
GROUND TOC1 PKP OnGROUND TOC1 PKP Off
-15000
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0
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0
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2000
1.16 1.18 1.20 1.22 1.24 1.26
WPlains Tr1_ 51V-51N - 6/11/2008 05:23:44.1219
Digital ChannelPHASE TOC1 PKP AGROUND TOC1 PKPTrig Osc OnPHASE UV1 OP APHASE UV1 OP BPHASE UV1 OP C
Vol
tage
(V)
Cur
rent
(A)
Time (s)
Va Vb Vc Ia Ib Ic Ires
CAP Bank Fault - Transformer 1 – GE F60 Relay Pickup
Phase, Gnd TOC, Phase Undervoltage
28 Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved. PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
-12000
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0.04 0.05 0.06 0.07 0.08 0.09 0.10 0.11 0.12
North Queens 1Q08 - 9/1/2008 23:23:09.5140
Cur
rent
(A)
Time (s)
Ia Ib Ic In Ires
Feeder Fault – Bassler Relay NO VOLTAGE Available at Station, No Reactance calculation
29 Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved. PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
Feeder Fault – Bassler Relay - Relay Targets
• 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.
50TPT On 50TPT Off-12000
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0.04 0.06 0.08 0.10
North Queens 1Q08 - 9/1/2008 23:23:09.5140
Digital Channel51NTTRIP150TPT150TPPU51PPUVO12_LABELINPUT_150TPT150TNT50TPPU150TNPU51NPUVO11_LABEL
Cur
rent
(A)
Time (s)
Ia Ib Ic In Ires
Relay Targets
30 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).
31 Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved. PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
Fault CIOA
PHASE IOC1 OP C OnPHASE IOC1 OP C OffPHASE TOC1 PKP A On PHASE TOC1 PKP A OffPHASE TOC1 PKP C OnGROUND TOC1 PKP OnTrip On OnTRIP IOn On TRIP IOn OffGROUND IOC1 PKP OnGROUND IOC1 OP OnPHASE IOC1 PKP C OnPHASE IOC1 PKP C OffPHASE IOC1 OP OnPHASE IOC1 OP OffPHASE TOC1 PKP On GROUND TOC1 DPO Off PHASE IOC1 PKP OnPHASE IOC1 PKP OffPHASE IOC1 DPO OffPHASE IOC1 DPO OnGROUND IOC1 DPO OffTrip IOff Off Trip IOff On
-2
-1
0
1
2
-15000
-10000
-5000
0
5000
10000
0.18 0.20 0.22 0.24 0.26
Seaport#1 40M43 (43A) - 1/4/2009 12:00:58.1925
Electrotek/EPRI PQView®
Digital ChannelPHASE IOC1 OP CPHASE TOC1 PKP APHASE TOC1 PKP CGROUND TOC1 PKPTrip OnTRIP IOnGROUND IOC1 PKPGROUND IOC1 OPPHASE IOC1 PKP CPHASE IOC1 OPPHASE TOC1 PKPGROUND TOC1 DPOPHASE IOC1 PKPPHASE IOC1 DPOGROUND IOC1 DPOTrip IOff
Vol
tage
(V)
Cur
rent
(A)
Time (s)
Va Vb Vc Ia Ib Ic
32 Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved. PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
Inrush (Feeder Restoration)
33 Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved. PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
Subcycle
Subcycle Event Feeder 8W64 - GE F60 Relay
34 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
35 Copyright © 2009 Electric Power Research Institute, Inc. All rights reserved. PQA/ADA Conference & Exhibition 2009
Future of Fault Location and Data Integration
Relay data RTF = 0.1747
36 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 RTF = 0.1661
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
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
• Enhance Web PQView to allow intranet viewing of Digital 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
Relay Targets
40 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
41 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?
Integrated Analysis of Power System Disturbances
Fred Elmendorf, Theo Laughner TVA
Mark McGranaghan, Chris Melhorn, Zhiming Dai, Paul MyrdaEPRI
2© 2009 Electric Power Research Institute, Inc. All rights reserved.
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
3© 2009 Electric Power Research Institute, Inc. All rights reserved.
Background – PQ Monitoring Systems
Traditional Uses• Benchmarking
• Standards Compliance
• Consumer Issue Resolution
• Standalone
Potential Uses• Health Assessments
• Performance Analysis
• Fault Detection
• Integrated Information System
Requirements
4© 2009 Electric Power Research Institute, Inc. All rights reserved.
Outline
• Concept of an Integrated Power Monitoring System• Applications• Integration Requirements• Important Concepts for System Events• Examples of System Event Analysis
5© 2009 Electric Power Research Institute, Inc. All rights reserved.
6© 2009 Electric Power Research Institute, Inc. All rights reserved.
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).
7© 2009 Electric Power Research Institute, Inc. All rights reserved.
Applications that can help improve reliability and security of the system
8© 2009 Electric Power Research Institute, Inc. All rights reserved.
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
Grid Data Sources
Grid Data Sources
Data Communication
Data Integration
Analytics
Information
Smart Grid Monitoring System – Grid Data Sources
• 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.
LAN
SensorsDigital Relays
Automated Substations
Security
Equipment Monitoring
D A T A
D A T A
D A T A
D A T A
D A T A
D A T A
9© 2009 Electric Power Research Institute, Inc. All rights reserved.
Smart Grid Monitoring System – Data Communication
• Open Standards based Digital Communication Networks allow devices to communicate securely with the Enterprise
Grid Data Sources
Data Communication
Data Communication
Data Integration
Analytics
Information
LAN
SensorsDigital Relays
Automated Substations
Security
Equipment Monitoring
D A T A
D A T A
D A T A
D A T A
D A T A
D A T A
Utility Applications
D A T A
•Extensive array of options available •Public and private digital networks•Wired, wireless, and optical
10© 2009 Electric Power Research Institute, Inc. All rights reserved.
Pub/SubMiddleware
External Applications
CIM Based Analytics Data Warehouse
P
P
P
1
1
PP
P
P
P
P
Business UnitsBusiness Unit ID
Transmission LinesTransmission Line ID
SubstationsSubstation ID
Business Unit ID (FK)Central Station ID (FK)
Substation to Transmission LinesSubstation ID (FK)Transmission Line ID (FK)Segment ID (FK)
Central StationsCentral Station ID
Power TransformersPower Transformer ID
Substation ID (FK)
Hydran UnitsHydran Unit ID
Power Transformer ID (FK)
IEDsIED ID
Substation ID (FK)IED Type (FK)
Circuit BreakersCircuit Breaker ID
SensorsSensor ID
Sensor Type (FK)Substation ID (FK)IED ID (FK)Hydran Unit ID (FK)Weather Station ID (FK)
Sensor TypesSensor Type
Sensor Type DescriptionUOM (FK)
Weather StationsWeather Station ID
Substation ID (FK)
Sensor ReadingsSensor ID (FK)Timestamp
Sensor Reading Value
Units of UOM
Transmission Line SegmentTransmission Line ID (FK)Segment ID
IED TypesIED Type
IEDs to Circuit BreakersIED ID (FK)Circuit Breaker ID (FK)
Results in• Enterprise wide
information model• Assets defined one
time in the Network• Connect all types of
meta data with asset• No information silos
Smart Grid Monitoring System – Data Integration
• Utility Common Information Model (CIM) Analytics data warehouse• Integration Middleware allows data flow to Analytics Data Warehouse
Grid Data Sources
Data Communication
Data IntegrationData Integration
Analytics
Information
LAN
SensorsDigital Relays
Automated Substations
Security
Equipment Monitoring
Utility Applications
11© 2009 Electric Power Research Institute, Inc. All rights reserved.
Smart Grid Monitoring System – Analytics
Grid Data Sources
Data Communication
Data Integration
AnalyticsAnalytics
Information
• Analytics are dependant upon access to data• Higher levels of analytics require more access to data
Analytics Levels of Complexity1. Real time alarms, thresholds -
screen display, message, pager 2. Calculated metrics, trends -
tailored notifications3. Analysis of data, events
diagnostics, both real time and post event, data mining
4. Advanced optimizations, modeling, planning, decision supportPub/Sub
Middleware
External Applications
External Applications
CIM Based Analytics Data Warehouse
P
P
P
1
1
PP
P
P
P
P
Business UnitsBusiness Unit ID
Transmission LinesTransmission Line ID
SubstationsSubstation ID
Business Unit ID (FK)Central Station ID (FK)
Substation to Transmission LinesSubstation ID (FK)Transmission Line ID (FK)Segment ID (FK)
Central StationsCentral Station ID
Power TransformersPower Transformer ID
Substation ID (FK)
Hydran UnitsHydran Unit ID
Power Transformer ID (FK)
IEDsIED ID
Substation ID (FK)IED Type (FK)
Circuit BreakersCircuit Breaker ID
SensorsSensor ID
Sensor Type (FK)Substation ID (FK)IED ID (FK)Hydran Unit ID (FK)Weather Station ID (FK)
Sensor TypesSensor Type
Sensor Type DescriptionUOM (FK)
Weather StationsWeather Station ID
Substation ID (FK)
Sensor ReadingsSensor ID (FK)Timestamp
Sensor Reading Value
Units of MeasureUOM
Transmission Line SegmentTransmission Line ID (FK)Segment ID
IED TypesIED Type
IEDs to Circuit BreakersIED ID (FK)Circuit Breaker ID (FK)
CIM Based Analytics Data Warehouse
P
P
P
1
1
PP
P
P
P
P
Business UnitsBusiness Unit ID
Transmission LinesTransmission Line ID
SubstationsSubstation ID
Business Unit ID (FK)Central Station ID (FK)
Substation to Transmission LinesSubstation ID (FK)Transmission Line ID (FK)Segment ID (FK)
Central StationsCentral Station ID
Power TransformersPower Transformer ID
Substation ID (FK)
Hydran UnitsHydran Unit ID
Power Transformer ID (FK)
IEDsIED ID
Substation ID (FK)IED Type (FK)
Circuit BreakersCircuit Breaker ID
SensorsSensor ID
Sensor Type (FK)Substation ID (FK)IED ID (FK)Hydran Unit ID (FK)Weather Station ID (FK)
Sensor TypesSensor Type
Sensor Type DescriptionUOM (FK)
Weather StationsWeather Station ID
Substation ID (FK)
Sensor ReadingsSensor ID (FK)Timestamp
Sensor Reading Value
Units of MeasureUOM
Transmission Line SegmentTransmission Line ID (FK)Segment ID
IED TypesIED Type
IEDs to Circuit BreakersIED ID (FK)Circuit Breaker ID (FK)
LAN
SensorsDigital Relays
Automated Substations
Security
Equipment Monitoring
LAN
SensorsDigital Relays
Automated Substations LAN
SensorsDigital Relays
Automated Substations
SecuritySecurity
Equipment MonitoringEquipment Monitoring
Utility Applications
Utility Applications
Analytics Engine
12© 2009 Electric Power Research Institute, Inc. All rights reserved.
Information
Smart Grid Monitoring System – Information
• Analytics generate actionable information • Analytics depend greatly upon observable level of
information and integration with other applications
Analytics support management of:
–Asset Lifecycle–Operations–Workforce–Planning –Customer
Cos
ts
Rel
iabi
lity
Ris
ks
Rev
enue
Grid Data Sources
Data Communication
Data Integration
Analytics
InformationInformation
Portal/Dashboards
OperationsMaintenanceFinancePlanningEngineering Customers
Informed Decision Making
13© 2009 Electric Power Research Institute, Inc. All rights reserved.
Business Intelligence…Presented on Dashboards
14© 2009 Electric Power Research Institute, Inc. All rights reserved.
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.)
15© 2009 Electric Power Research Institute, Inc. All rights reserved.
15
Event Count: 20Event Count ITIC Lower Curve: 9
0.0
0.5
1.0
1.5
2.0
10 -3 10 -2 10 -1 10 0 10 1 10 2 10 3
Total Bank Covington, from 05/01/2005 to 02/01/2009
EPRI/Electrotek PQView®
Vol
tage
Mag
nitu
de (p
u)
Duration (s)
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.
Time Stamp
Worse VLL
Phase
VLL Magnitude
(pu)
Worse VLN
Phase
VLN Magnitude
(pu)Duration
(s)Duration
(cyc)10/17/2005 08:29:12.345 BC 0.884 B 0.778 0.075 4.511/15/2005 14:49:05.949 AB 0.687 B 0.725 0.075 4.511/15/2005 15:36:55.644 AB 0.828 A 0.780 0.042 2.512/31/2005 12:30:22.075 AB 0.655 B 0.763 0.158 9.502/21/2006 22:14:50.812 CA 0.744 C 0.651 0.050 3.003/13/2006 08:06:41.983 BC 0.847 B 0.797 0.033 2.004/02/2006 19:04:25.703 CA 0.693 A 0.773 0.042 2.504/02/2006 19:25:10.958 CA 0.683 C 0.646 0.058 3.504/02/2006 19:53:36.781 AB 0.696 A 0.744 0.042 2.504/02/2006 20:09:18.270 BC 0.648 B 0.715 0.042 2.504/07/2006 23:22:20.287 AB 0.814 B 0.780 0.042 2.504/12/2006 05:46:07.110 CA 0.791 C 0.562 0.067 4.004/15/2006 13:00:56.328 CA 0.832 C 0.639 0.083 5.005/21/2006 06:08:59.822 AB 0.676 A 0.511 0.092 5.508/20/2006 20:57:38.316 AB 0.787 A 0.559 0.075 4.510/01/2006 16:27:11.156 BC 0.663 B 0.697 0.083 5.007/09/2008 23:30:25.620 CA 0.812 C 0.582 0.058 3.508/15/2008 14:46:54.137 BC 0.619 B 0.709 0.092 5.510/07/2008 04:52:32.886 AB 0.707 B 0.599 0.042 2.511/06/2008 18:04:57.871 BC 0.816 C 0.770 0.042 2.5
Examples of System Event Data and Analysis
70%
Yellow – VL‐Gnd
<70%, VLL > 70% of
Nominal, Red – VLL < 70% of Nominal
ITIC – VL‐GND Only
16© 2009 Electric Power Research Institute, Inc. All rights reserved.
From SE
Outside TVA in Yellow
From West –
Northern Route
From West –
Southern Route
From North East – Northern Route
From North East – Southern Route
500-kV
System
17© 2009 Electric Power Research Institute, Inc. All rights reserved.
-150
-100
-50
0
50
100
150
0.00 0.05 0.10 0.15
g
% o
f N
om
inal V
oltage
Time ( s)
-150
-100
-50
0
50
100
150
100 150 200 250
y
Perc
ent
of
Nom
inal V
AB
Time (ms)
82% 68.7%
Time Stamp
Worse VLL
Phase
VLL Magnitude
(pu)Duration
(s)Duration
(cyc)
11/15/2005 14:49:06.000 AB 0.687 0.075 4.5
Simulated Fault
Actual DFR Shot
and
PQ Monitor Shot
DFR
Currents
18© 2009 Electric Power Research Institute, Inc. All rights reserved.
18
-150
-100
-50
0
50
100
150
0.00 0.05 0.10 0.15 0.20 0.25
PE
RC
EN
T O
F N
OM
INA
L V
AB
TIME (MS)
65.5% ‐
Min.
-150
-100
-50
0
50
100
150
250 300 350 400 450 500
VAB JOHNSONVILLE DFR (FAULT LOCATION)
PE
RC
EN
T O
F N
OM
INA
L V
AB
Time (ms)
5% ‐
Min.
-150
-100
-50
0
50
100
150
250 300 350 400 450 500
PE
RC
EN
T O
F N
OM
INA
L V
AB
Time (ms)
35% ‐
Min.
-150
-100
-50
0
50
100
150
100 200 300
V S 6
PE
RC
EN
T O
F N
OM
INA
L V
AB
Time (ms)
65% ‐
Min.
-150
-100
-50
0
50
100
150
200 250 300 350 400 450
PE
RC
EN
T O
F N
OM
INA
L V
AB
Time (ms)
25% ‐
Min.
-150
-100
-50
0
50
100
150
200 250 300 350 400 450
PE
RC
EN
T O
F N
OM
INA
L V
AB
Time (ms)
50% ‐
Min.
Ph‐Ph
Arcing Fault
-150
-100
-50
0
50
100
150
100 150 200 250 300 350
PE
RC
EN
T O
F N
OM
INA
L V
AB
Time (ms)
68% ‐
Min.
500‐kV Network
In Blue
All Data Actual DFR and PQ VAB Waveforms From Event
19
Fault on 500-kV System – ArkansasTime Stamp Worse VLL Phase VLL Magnitude (pu) Duration (s) Duration (cyc)
04/02/2006 19:04:25.703 CA 0.693 0.042 2.5
High Winds/Tornado
Impact 500‐kV
System in Arkansas
20© 2009 Electric Power Research Institute, Inc. All rights reserved.
-150
-100
-50
0
50
100
150
100 150 200 250 300
Per
cent
of N
omin
al V
CA
Time (ms)
67.7%
-150
-100
-50
0
50
100
150
0.00 0.02 0.04 0.06 0.08 0.10 0.12
PE
RC
EN
T O
F N
OM
INA
L V
CA
Time ( s)
69.3%
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
21© 2009 Electric Power Research Institute, Inc. All rights reserved.
21
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
20.6%
Tornado Path
-150
-100
-50
0
50
100
150
0.00 0.02 0.04 0.06 0.08 0.10 0.12
PE
RC
EN
T O
F N
OM
INA
L V
BC
Time ( s)
VBC
-150
-100
-50
0
50
100
150
100 150 200 250 300
PE
RC
EN
T O
F N
OM
INA
L V
BC
Time (ms)
64.8%
62.0%
22© 2009 Electric Power Research Institute, Inc. All rights reserved.
23© 2009 Electric Power Research Institute, Inc. All rights reserved.
DFR:
Fault Occurred: 19:28:42.876 CDT
Duration: 23 cycles
Bus Voltage: Dipped to 60% of Nominal
24© 2009 Electric Power Research Institute, Inc. All rights reserved.
PMU
500 kV Bus Voltages
70% Nominal
Took about 7 seconds for the
voltage to recover back to
nominal value
25© 2009 Electric Power Research Institute, Inc. All rights reserved.
25
LSC Sites Sagging Below
70% of Nominal Voltage
Ground
Switch
Event
Three Phase Fault
30% of Nom. For 3
Cycles
4
26© 2009 Electric Power Research Institute, Inc. All rights reserved.
Web-Based Application Integration
27© 2009 Electric Power Research Institute, Inc. All rights reserved.
Substation A
Substation B
Fault Location
Str
14
Line L5934
28© 2009 Electric Power Research Institute, Inc. All rights reserved.
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
29© 2009 Electric Power Research Institute, Inc. All rights reserved.
30© 2009 Electric Power Research Institute, Inc. All rights reserved.
…wax your digital surf board and get ready for a wild ride!
www.savvyminds.com/SamplesSubpages/Tsunami.htm
31© 2009 Electric Power Research Institute, Inc. All rights reserved.
Questions?