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Modelling and Simulation inSmart Grid Demos
Roger C. DuganSr. Technical Executive
IEEE ISGT Europe 2011Manchester, UK7 December 2011
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2 2011 Electric Power Research Institute, Inc. All rights reserved.
What is the Smart Grid?
Smart Grid means different things to different people Communications and control
Not typically represented in distribution systemanalysis
Distributed resources
Generation, storage, demand response, microgrids
Some of these issues have been addressed
Monitoring (AMI, etc.)
Intelligent protection
Energy efficiency
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3 2011 Electric Power Research Institute, Inc. All rights reserved.
What Kind of Analysis Tools are Needed?
What can be done if more is known about the system?
What different approaches to DSA tools?
Expected:
Convergence of distribution monitoring anddistribution state estimation (DSE) into DMS
Selected relevant issues are discussed in thispresentation
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4 2011 Electric Power Research Institute, Inc. All rights reserved.
State of the Art
Most DSA tools can perform 3-phase analysis Some (e.g., EPRI OpenDSS) more than three phases
Most tools were originally designed for static power flow
A few can perform power flows over time
Tools and techniques designed for uniprocessors
Satisfactory for the time being future ??
Many (most?) exploit radial nature of feeders
For simulation efficiencies Harmonics analysis is optional
If available
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5 2011 Electric Power Research Institute, Inc. All rights reserved.
State of the Art, contd
Frequency-domain tools are preferred for DSA Time-domain tools do exist
Dynamics analysis (electromechanical transients) isuncommon
Planning and operational tools (DMS) are often separate
Secondary (LV) has been ignored
Changing!
Loads modeled by time-invariant ZIP models
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6 2011 Electric Power Research Institute, Inc. All rights reserved.
Needs Envisioned by EPRI
Sequential time simulation In various time steps
Meshed network solution capability
Better modeling of Smart Grid controllers
Advanced load and generation modeling
High phase order modeling ( >3 phases)
Stray voltage (NEV), crowded ROWs, etc.
Integrated harmonics NEV requires 1st and 3rd
User-defined (scriptable) behavior
Dynamics for DG evaluations
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7/327 2011 Electric Power Research Institute, Inc. All rights reserved.
EPRIs Vision
Distribution planning and distribution managementsystems (DMS) with access to real time loading andcontrol data will converge into a unified set of analysistools.
Real-time analysis and planninganalysis will merge into common tools.
Distribution system analysis tools will continue to play animportant role, although they might appear in a much
different form than today.
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Tackling Smart Grid Issues
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Modeling for Distributed Generation
Voltage rise and regulation, Voltage fluctuations,
Protective relaying and control functions,
Impact on short-circuit analysis,
Impact on fault location and clearing practices,
Interconnection transformer,
Transformer configuration,
Harmonics, Response to system imbalances
e.g. open-conductor faults due to failing splices.
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Example of an Expected DG Problem
Regulator taps upto compensate for
voltage drop
Voltage overshoots as
power output ramps up
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Root of Problem
Voltage Profile w/ DG
0.0 2.0 4.0 6.0
Distance from Substation (km)
0.90
0.95
1.00
1.05
1.10
p.u. Voltage
High Voltages Distribution
Systems designed
for voltage DROP,
not voltage RISE.
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Time Sequential Simulation
Electric vehicle charging (minutes, hours)
Solar and wind generation (seconds)
Dispatchable generation (minutes to hours)
Storage simulations (minutes to hours)
Energy efficiency (hours)
Distribution state estimation (seconds, minutes)
End use load models (minutes to hours) End use thermal models (minutes to hours)
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Modeling for Unbalances
Very important for North American systems Symmetrical component model and an unbalanced phase-
domain model can yield quite different results.
A symmetrical component model uses only the positive- and zero-sequence impedancesassumes balance
Asymmetries yield impedances that are not balanced betweenphases.
Many distribution system analysis tools can perform full 3-phaseanalysis;
A few programs can go beyond 3-phases.
Many circuits include multiple feeders sharing right-of-ways
We have analyzed circuits with 17 conductors on the samepole sharing a common neutral
(as well as several communications messengers).
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Example
FEEDER A FEEDER B
380.0 A
364.6 A
348.6 A
543.7 A
525.2 A
509.6 A
54.4 A
A
B
C
A
B
C
Shield
%I2/I1= 3.85% %I2/I1= 4.09%
I2 = Negative Sequence
I1 = Positive Sequence
A B C
515 A 519 A 518 A
Feeder A
IAVG=517 A
A B C
357 A 359 A 359 A
Feeder B
IAVG=358 A
Symmetrical Component ModelUnbalanced model
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Large Systems
A key capability 5000 10000 bus systems are routine today
Smart Grid requires solution of multiple feederssimultaneously
Goal:
100,000 to 1,000,000 nodes
Parallel computing could enable this
Requires new algorithms
HPC (High Performance Computing) ?
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Simulating with AMI Load Data
AMI verses Modeld (7/12/2010 to 7/17/2010)
0.96
0.97
0.98
0.99
1
1.01
1.02
1.03
1.04
20:00 8:00 20:00 8:00 20:00 8:00 20:00 8:00 20:00 8:00 20:00
Time
Voltage(PU)
Modeled
Measured
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Storage Element Model in OpenDSS
% Eff. Charge/DischargeIdle | Discharge | Charge
Idling Losses
kW, kvar
kWh
STORED
Other Key
Properties
% ReservekWhRated
kWhStored
%Stored
kWRated
etc.
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Basic Charge/Discharge Model for StorageModel
Example STORAGE Dispatch LoadShape
0
0.1
0.2
0.3
0.4
0.5
0.6
0.7
0.8
0.9
1
1250 1300 1350 1400
Time, hr
Mult
Mult
Discharge Zone > 0.92
Charge Zone < 0.40Charge on Time
These Days
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21 2011 Electric Power Research Institute, Inc. All rights reserved.
Follow Mode
Example Daily Dispatch Curve
-1.5
-1
-0.5
0
0.5
1
1.5
0 5 10 15 20 25
time, Hr
Multiplier
Mult
Charge Cycle
Discharge Cycle
Example Follow Mode Solution (2 Days)
-250
-200
-150
-100
-50
0
50
100
150
200
250
0 8 16 24 32 40 48
time, h
kW
-1
-0.8
-0.6
-0.4
-0.2
0
0.2
0.4
0.6
0.8
1
Power Discharged LoadShape kWh Stored
Charge/Discharge driven proportionately to apredefined curve
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22 2011 Electric Power Research Institute, Inc. All rights reserved.
StorageController Element in OpenDSS (CES Hub)
Discharge Mode
Charge Mode
kW Target
Discharge Time
Total Fleet kW CapacityTotal Fleet kWh
et. al.
Storage FleetSubstation
V, I
Comm Link
Time + Discharge rate
Peak Shaving
Load Following
Loadshape
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23 2011 Electric Power Research Institute, Inc. All rights reserved.
Hub Dispatch Modes Defined for AEP Demo
Time Turn ON at specific time
Peak Shave
Limit to a value
Follow
Time trigger and then shave
Loadshape
ScheduleCharge
Discharge
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24 2011 Electric Power Research Institute, Inc. All rights reserved.
Load Shapes With and Without Storage
Discharge Trigger @ Noon, 75 kWh Storage, 30% charge @ 2AM
0
1000
2000
3000
4000
5000
6000
7000
8000
9000
10000
0 100 200 300 400 500 600
Hours
kW
0
10
20
30
40
50
60
70
80
"kWh Normal"
"kWh"kWh Stored
75 kWh Does a pretty good
job of clipping the peaks
unless triggered too early
Early
Too early drains storage
About right
Late
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25 2011 Electric Power Research Institute, Inc. All rights reserved.
Load Shapes With and Without Storage
Discharge Trigger @ Noon, 25 kWh Storage, 30% charge @ 2AM
0
1000
2000
3000
4000
5000
6000
7000
8000
9000
10000
150 170 190 210 230 250 270 290
Hours
kW
0
5
10
15
20
25
30
"kWh Normal"
"kWh"
kWh Stored
Early
Not enough Oomph
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Co-Simulation of Power andCommunications Systems
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27 2011 Electric Power Research Institute, Inc. All rights reserved.
The Question
Can you dispatch the 84 CES units fast enough tocompensate for the sudden loss of PV generation on aCloud Transient ?
Why it might not work: Communications latency
CES not in right location or insufficient capacity
Calls for a Hybrid simulation
Communications network (NS2)
Distribution network (OpenDSS)
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28 2011 Electric Power Research Institute, Inc. All rights reserved.
Modeling Communications
Clusters of
Storage Units
Voltage regulator (Reg1)
PV Location (PV1)
Solar Ramp Function
0 100 200 300
Seconds
0.00
0.20
0.40
0.60
0.80
1.00
p.u.
10%/s 5%/s
(dropout @ 20%)
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
0.000 0.500 1.000 1.500 2.000
% Arrival vs time (S)
400mW
80mW
30mW
10mW
0 5 10 15 20 25 300.995
1.000
1.005
1.010
1.015
1.020
1.025
Time (seconds)
VoltageMagnitude(per
unit)
Base Phase a
Base Phase b
Base Phase c
Phase a
Phase b
Phase c
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29 2011 Electric Power Research Institute, Inc. All rights reserved.
How We Did It
OpenDSS
Extract
Time andCoordinates
NS2
DS Device
LoadProfile
Merge
Time andProfile
Wireless
Model
PowerCircuitModel
NS2 script toconfigure node
topology
Messagearrival times
Load profilesfor each DS
device
Loadprofiles
timed to DS
event arrival
OpenDSStopology for
DS devices
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30 2011 Electric Power Research Institute, Inc. All rights reserved.
OpenDSS Script (Snippet)
Set sec=20
Solve ! Init steady state at t=20
Sample
! Start the ramp down at 1 sec
Set sec=21
Generator.PV1.kW=(2500 250 -) ! Decrement 10%
Solve
Sample
Set sec=22
Generator.PV1.kW=(2500 500 -) ! Decrement another 10%
Solve
Sample
Set sec = 22.020834372 ! Unit 1 message arrives
storage.jo0235001304.state=discharging %discharge=11.9
Solve Sample
Set sec = 22.022028115 ! Unit 2 message arrives
storage.jo0235000257.state=discharging %discharge=11.9
Solve
Sample
Etc.
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31 2011 Electric Power Research Institute, Inc. All rights reserved.
Questions?
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TogetherShaping the Future of Electricity