Agenda

1
Agenda

• D-VAR
• DVC (Dynamic VAR Compensator)
• SuperVAR (Synchronous Condenser)

2
D-VAR

• What are D-VAR Devices?
• Dynamic VARs Fully integrated modular STATCOM
  with proprietary 3X overload
• Instantaneously injects precise amounts of
  reactive power into a network
• Can be seamlessly integrated with static shunt
  devices as part of a larger solution

3
Application of D-VAR
Transmission Problems That D-VAR Can Solve

• Voltage Stability / Voltage Collapse -
  Uncontrolled rapid decline
• in system voltage
• Steady State Voltage Regulation - Wind farms,
  radial lines, etc...
• Import/ Transfer Capability Restrictions -
  Limited ability to
• reliably import,
  export, or transfer power
• Mitigate voltage flicker/ power quality - Wind
  farms, industrial
• facilities

GE / AMSC performs full system analysis jointly
with the customer to determine the least cost,
best available solution
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Just the FACTS DVAR

High power, air cooled, inverters (STATCOM)

No environmental permits required

Lowest cost

Quickest installation

Easily located in
distribution substations

No need for operator
control

24 X 7 remote
monitoring by AMSC
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DVAR Basics.
Each D-VAR system has continuous reactive power
with temporary overload capability up to 3 times
its continuous rating. Each phase is individually
controlled.
Proprietary Power Electronics Technology
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Typical Inverter Module
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Stacked Inverter Array
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D-VAR Injection Capability
Proprietary technology provides combination of
continuous dynamic VARs with additional overload
boost
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American Superconductor field experience 34
Statcoms leads the industry.
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Field Operating Experience Summary

• Key Facts
• Over 530,000 Operating Hours gt 60 years
• Over 6200 stability/voltage sag responses
  recorded
• Number of inverters modules in the field 840 as
  of 1 Feb 05
• Six dedicated voltage regulating D-VARs averaging
  249 active regulating hours per month
• Proven high availability
• Last 36 months entire fleet 99.4
• Last 12 months entire fleet 99.7

American Superconductor D-VAR Systems have
unmatched experience and field performance
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D-VAR Annual Preventive Maintenance
Output Breaker Cabinet Annual connections
check/torque
Overall General Condition Check Annual - Lights,
exterior condition, air intake exhaust
passages, exhaust fans, fire extinguishers
MIU Annual General condition check, UPS Battery
check/test/replace,
Inverters Seasonal filter clean/replace, general
condition check, Winterize louvers, fans, check
heater operations.
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DVAR Application Examples

• Keyspan/LIPA Avoiding Voltage Collapse
• NE Utilities Increased Transfer Capability
• Caprock wind Wind Farm LVRT Regulation

13
East End of Long Island
Southold
Orient Point
Generating
Peconic
Areas of Voltage Collapse Concerns
Mattituck
Tuthill
Riverhead
Bridgehampton
Amagansett
Hero
East Hampton
Buell
Southampton
Tiana
Double Circuit 69kV fault
Installation Site
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CASE DISCRIPTION Load LI(2500MW) EE(133MW)
SF(92MW) No East End Generation
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Proposed Solution for the East End Voltage Issues
8 MVA D-VAR Installed at Bridgehampton
Easthampton
69 kV
To Bridgehampton
To Buell
13.8 kV
Load
Load
To East Hampton Diesels
13.8 kV
VT
Inputs to DVAR for Voltage Control
480-13800 V Padmount Transformers
VT
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Voltage Response with D-VAR Installed
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Northeast Utilities D-VAR Based Transmission
Solution for Transfer Capability Improvement
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Northeast Utilities Power Transfer
Increase Southwest Connecticut's Danbury Area
Southwest Connecticut

• 345 kV and 115 kV transmission system
• 13.8 kV distribution system
• Highly compensated with capacitors
• 235 MW Danbury Area
• 3600 MW SW Connecticut

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Northeast Utilities Danbury Area Loadflow Problem
Results

• For outage of the Long Mountain-Plumtree 345 kV
  line, imports into the area are almost 2,300 MW
  before area voltages collapse.
• Transfers into the area are curtailed when
  predicted contingency transmission voltages fall
  below 95.

Danbury Area 115 kV Substation Voltages
Per Unit Voltages
SW Connecticut Imports
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Northeast Utilities Danbury Area D-VAR Systems
Solution

• Install three D-VAR systems (rated at 8 MVAR
  each) at two existing distribution substations
  and D-VAR system controlled capacitor banks
• one 8 MVAR distribution
• two 37.8 MVAR transmission banks
• Reasons for purchase
• low profile, no substation site expansion was
  necessary
• low cost
• flexibility / relocatable
• installation time (lt6 months)
• summer 03 payback due to increased import
  capability

DVAR Dynamic Range -55 to 130 MVAR
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Northeast Utilities Danbury Area Comparison of
Loadflow Results
Solution
Per Unit Voltages
Problem
SW Connecticut Imports
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Caprock Wind Farm D-VAR Based Transmission
Solution for steady-state voltage regulation
and transient voltage support
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Area One-Line Diagram
Utility Substations
Wind Farm Site
Transmission Lines
Utility Interconnection Point
60 Miles
Xcel Transmission New Mexico
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D-VAR Solutions Dynamic Voltage Support
Provides a total of -48 MVAR/84 MVAR
T1 60/90 MVA with LTC
Utility Interconnection Point
115 kV
34.5 kV
600V
26 MW
9 X 3.6 MVAR
VTs
97 Lagging PF
26 units
The dynamic MVARs are sized to prevent the wind
farm from tripping off-line for the faults that
the utility specified.
34.5 kV UDG collector system
600V
Joslyn VBM Switch
28 MW
97 Lagging PF
8/24 MVAR D-VAR
28 units
4x2500 KVA 34500-480V padmount transformers
D-VARs .
Dynamic 2 x 8 x 3 48 MVAR
8/24 MVAR D-VAR
1200 Amp Breaker
600V
26 MW
Dynamic Capacitor Banks 2 x 18 MVAR 36 MVAR
Joslyn VBU Switch
97 Lagging PF
26 units
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Summary of large DVAR Applications
DVAR Application
DVAR system output range

• Rayburn Coop -36 to 86 MVAR
• NE Utilities -55 to 130 MVAR
• Caprock wind farm -48 to 84 MVAR
• NW Semiconductor -168 to 168 MVAR

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American Superconductor Dynamic Var
Compensator DVCTM
AMSCs large single site solution is called a
Dynamic VAR Compensator or DVCTM.
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DVCTM Solution Advantages

• Hybrid Statcom / SVC
• Exceeds performance of conventional SVC
  technology
• Builds off of widely successful D-VARTM statcom
  platform and proven compenents
• Modular components - easily expandable
• 20 - 30 less cost than equivalent SVC solutions

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SVC basic building blocks

• TCR - Thyristor Controlled Reactor
• Provides infinite control of reactor VARs from
  0-100
• On all the time but VAR output changing per
  system needs
• Sized to provide max lagging VARs (Reactor-filter
  caps max)

• TSC - Thyristor Switched Capacitors
• On only as needed to provide leading VARs
• Fast switching in 1-2 cycles with Thyristor
  switch
• 25-100 MVAR -same or different sizes to allow
  smaller VAR steps

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Example DVC Solution
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DVC Operation
1) STATCOM responds to any voltage deviation
outside preset levels (use overload ratings as
needed) 2) Primary Capacitors quickly switch in
response to large voltage deviations 3) Secondary
Capacitors switch to bring STACOM output within
continuous rated output (below overload levels)
as needed.
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Capacitor and reactor switching using Joslyn VBU
modified to include AMSC control board
Close Timing From solenoid energization to
contact touch 20 - 28 ms max. Trip Timing From
solenoid energization to contact part 17 ms
max. From contact part to full open 7 ms
max. Low Maintenance 10,000 operation between
inspections Proven Performance Over 500 three
phase units installed during past 40 years
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SaskPowerDVC solution providessteady-state
voltage regulation and transient voltage
stability support
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Saskatchewan Powers Rush Lake Wind Farm One-Line
Diagram
Critical Outage
Critical Bus for Post Fault Voltage Requirement
230 kV Transmission Bus
Point of Common Coupling
Substation Transformer 100 MVA Base, 10 Z 10 LTC
34.5kV Main Collection Bus

• Rush Lake Solution Requirements
• Regulate voltage at 230 kV transmission bus PCC
• Install sufficient reactive capability to meet
  95 lagging to 90 leading PF at PCC
• Prevent tripping of wind farm turbines for worst
  fault
• Prevent 138 kV bus from dropping below 0.70 pu
  voltage for worst fault (MAPP Criteria)

Collection Feeders To 150 MW of Wind turbines
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Saskatchewan Powers Rush Lake Wind Farm DVCTM
Dynamic Reactive Compensation Solution
Critical Outage
Critical Bus for Post Fault Voltage Requirement
230 kV Transmission Bus
Point of Common Coupling
Substation Transformer 100 MVA Base, 10 Z 10 LTC
34.5kV Main Collection Bus
D-VAR
Collection Feeders To 150 MW of Wind turbines
D-VAR
2X25 MVAR Cap Bank (Transient Use Only)
8 X 13.2 MVAR Cap Banks (Steady State Regulation)
16/48 MVAR DVAR Statcom
DVC System Total Short-term Dynamic VAR
Capability -48 to 98 MVAR
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Critical Transmission Bus Voltage With Solution
Cap 1 Out
Cap 2 Out
Cap 2 In
Cap 1 In
0.70 p.u. Minimum Voltage Target
Critical Transmission Bus Voltage Without
Solution
With DVC solution, critical transmission voltage
remains above target
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DVC Solution Advantages

• Hybrid STATCOM / SVC
• Exceeds performance of conventional SVC
  technology
• Builds off of widely successful D-VAR STATCOM
  platform
• Modular components - easily expandable
• 20 - 30 less cost than equivalent SVC solutions

37
STATCOM Vs SVC Performance At Reduced Voltages
STATCOM is a Current Controlling Device
Q IV Reactive
Power is linearly dependent on Voltage SVC is a
Impedance Controlling Device Q V2/X
Reactive Power is dependent on the square
of the Voltage
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80/200 MVAR STATCOM Capacitive Output Vs. Bus
Voltage As Compared to 200 MVAR SVC
200 MVAR _at_ 1.00 p.u.
1.00 p.u.
D-VAR Peak Output Capability
SVC Peak Output Capability
.80 p.u.
160 MVAR _at_ .80 p.u.
128 MVAR _at_ .80 p.u.
.60 p.u.
120 MVAR _at_ .60 p.u.
72 MVAR _at_ .60 p.u.
69kV Bus Voltage
.40 p.u.
80 MVAR _at_ .40 p.u.
32 MVAR _at_ .40 p.u.
.20 p.u.
40 MVAR _at_ .20 p.u.
8 MVAR _at_ .20 p.u.
50 MVAR
150 MVAR
200 MVAR
100 MVAR
D-VAR Capacitive Output
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Performance Comparison DVC vs. SVC
Alternate DVC Solution
SVC Solution
DVC outperforms conventional SVC technology!!
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• SuperVARTM Dynamic Synchronous Condenser

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SuperVarTM

• SuperVAR rotating machines platform
• Worlds first commercial product based on HTS
  technology
• TVA launch customer ordered first five
  production units
• Successfully tested on the Ohio power grid
• Delivered advanced prototype to TVA in August
  2004 for final grid testing
• Supplements D-VAR Solutions

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8 MVAR SuperVARTM Condenser Cut Away
Refrigeration Systems
Auxiliary Drive Motor 480V Service
Exciter
Stator and HTS Rotor
25 feet
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SuperVARTM Condenser Performance Features

• Fast reacting dynamic voltage and stability
  support (leading and lagging VARs) at a multiple
  of the machine rating
• /-12 MVAR Continuous
• Up to 2x continuous rating for 2 minutes
• Fast exciter
• Increases local fault power by 80 MVA due to low
  sub-synchronous reactance
• Very low maintenance and operating costs
• Connects direct to MV bus at 1.5 -13.8 kV
• Simplified installation using compact container

44
Power Quality Problems - Motor Starting
Existing Utility and Customer System
Customer Substation
69-12.5 kV Substation
4160V
1200 HP Dredge Motor
12.5 kV
Vista
1000 HP Booster 1 Motor
4.5 MVA
N.O.
Other customer loads
Riley
600 HP Backwash Motor
4160V
12.5 kV
69 kV
1000 HP Booster2 Motor
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Voltage Sags on 12.47 kV Bus due to
MotorStarting on Existing System
13
Motor starting is causing very noticeable and
objectionable voltage sags
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Power Quality Problems - Motor Starting
Add SuperVARTM Solution
Customer Substation
69-12.5 kV Substation
4160V
1200 HP Dredge Motor
12.5 kV
Vista
1000 HP Booster 1 Motor
4.5 MVA
N.O.
Other customer loads
Riley
600 HP Backwash Motor
4160V
12.5 kV
69 kV
1000 HP Booster2 Motor
12 MVA SuperVAR Device
SuperVARTM Condenser solution is even better
without a 13.8-12.5 kV transformer
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SuperVARTM Condenser Applied to Motor Starting
Problem
Motor 2
Motor 3
Motor 1
Motor 4
Bus Voltage in kV
Bus Voltage Without SuperVARTM Condenser
Time (Seconds)
Bus Voltage With SuperVARTM Condenser
Bus Voltage in kV
Time (Seconds)
SuperVARTM MVAR Output
Output in MVAR
Time (Seconds)
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Summary of benefits of SuperVARTM Solutions

• Eliminates voltage sags from large motor starting
  events
• Increases local fault MVA and adds inertia to
  system
• Mitigates transient voltage problems including
  voltage flicker
• Solves steady state voltage regulation problems

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Detailed Load Modeling
Proper Load Modeling for Voltage Studies
56
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Typical Loadflow Base Case
Sub C
Sub B
Load represented on the transmission bus,
typically as constant MVA.
138 kV
Sub A
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51
Necessary Detail That Need to be Added to the
Loadflow Base Case
Sub C
Detailed Loadflow
Sub B
Sub-Transmission System
Sub 1
138 kV
Sub B
Sub A
115 kV
46 kV
Sub 2
The transmission flows and voltages between the
loadflows should not change.
Sub 3
Dist. Transformer and Dist. Line Z
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Detailed Load Modeling
Why go through all of this work to model the load?
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You Cant Determine Your Risk Without It!
These are voltage responses using ZIP load
models, for 138 kV and 12 kV buses after a fault.
Voltage In Per Unit
Time In Seconds
57
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Compare ZIP Models and Detailed Models!
Compare the results using detailed load models
with those for ZIP loads models.
Comparison of ZIP loads
Voltage In Per Unit
Time In Seconds
58
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Questions?