© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop
Australian Case Studies
Applications of D-VAR STATCOM
2015
© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop
• Renewable Applications
• Industrial Applications
• Utility Application
D-VAR® STATCOMs Case Studies
2
© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop
Collgar Wind Farm
© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop 4
Background• Collgar Wind Farm is the largest wind farm in the southern hemisphere and is owned by UBS
International Infrastructure Fund and the Retail Employees Superannuation Trust (Split 60/40)
• Its 206 MW comes from of 111 Vestas V90-2MW wind turbine generators
• It is located near Merredin in Western Australia and cost $750 million
• It is tied into Western Power’s Merredin-West Kalgorrlie 220 kV transmission system
• The wind farm must comply with the Western Power Technical Rules for the interconnection of
a large generating plants - these rules require the following:
a reactive capability that is greater than the wind turbines can provide alone
a minimum reactive capability that the wind farm as a whole is to supply (steady state)
a specific dynamic reactive performance of the that wind farm’s reactive capability (transient
response)
• Specifically, the reactive support be used to regulate the system voltage in a carefully defined
manner that ensures consistent, safe, and stable operation of the wind farm and the greater
power grid
• In order to meet these requirements, the installation of ancillary reactive support equipment
and controls was necessary
• The D-VAR® STATCOM system was split and installed on two 33 kV buses
Each 33 kV bus gets:
12 x 4 MVAR D-VAR STATCOMs
2 x 13 MVAR capacitor banks
© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop
Collgar WF D-VAR® Installation
5
33 kV
2 x 180MVA
275-220/33 kV
Transformer
2 x 13 MVAR
Cap BankD
-VA
R
D-V
AR
D-V
AR
D-V
AR
D-V
AR
D-V
AR
D-V
AR
D-V
AR
D-V
AR
D-V
AR
MCE
D-V
AR
D-V
AR
D-V
AR
D-V
AR
D-V
AR
D-V
AR
D-V
AR
D-V
AR
D-V
AR
D-V
AR
MCE
N.O.
PT
CT
PT PT
CT
220 kV
To Collgar
Terminal
MVAR Control
Monitoring
Master Control
Enclosure
2 x 13 MVAR
Cap Bank
Collgar WF Collgar WF
96 MVAR2 x 12 x 4 MVAR
D-VAR STATCOM
D-V
AR
D-V
AR
D-V
AR
D-V
AR
96 MVAR2 x 12 x 4 MVAR
33/0.48 kV Transformers
© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop 6
Analysis Approach• The members of AMSC’s Network Planning Group are some of the world’s
foremost interconnection standard experts and have an intimate knowledge
of Western Power’s Technical Rules for generation interconnection
• AMSC obtained detailed technical data on the Collgar Wind Farm and
developed computer models using the same power system simulation
software packages that Western Power uses
• AMSC’s Planning Group performed load-flow, dynamic stability, and,
harmonic analysis to develop a solution that would ensure compliance with
the Western Power Technical rules while also optimizing for performance,
efficiency, and cost
• AMSC then worked with both Vestas and Western Power to ensure
confidence in the solution by assisting the Western Power Transmission
Planning Team in simulating the wind farm with the reactive power solution
on their computers
• AMSC continued to support Vestas and Western Power to further optimize
the system control through the final design, construction and commissioning
of the project until commercial operation was achieved
© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop
Musselroe Wind Farm
© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop 8
Background• Musselroe Wind Farm is owned and operated by Hydro Tasmania
• Its generating capacity is composed of 56 Vestas V90 3 MW wind turbine generators
• It is located near Cape Portland Tasmania, Australia
• It ties into the transmission system via a 54 radial km 110 kV transmission line
• Much of the analysis work was conducted by consultants working for Hydro Tasmania using
AMSC’s D-VAR® PSS/E and other vendor’s models.
• One of the sites challenges is they have very low fault currents and because of this many
different types of studies using different softwares, including EMT, have been used
• The D-VAR® STATCOM system was split and installed on two 33 kV buses
Each 33 kV bus gets:
2 x 4 MVAR D-VAR STATCOMs
2 x 10 MVAR capacitor banks
and 1 synchronous condenser
• The D-VAR STATCOM system enables the wind farm:
to coordinate the reactive capabilities of the D-VAR STATCOM, the four capacitor banks,
and the Vestas wind turbine generators
to provide dynamic VARs from the D-VAR STATCOM to assist the transmission system’s
post fault voltage recovery
© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop
10 MVAR
4.1st
High Pass
Filter Bank(Note - First On
Last Off)
Musselroe WF D-VAR® Installation
10 MVAR
4.1st
High Pass
Filter Bank
10 MVAR
4.1st
Filter Bank8 MVAR
D-VAR
8 MVAR
D-VAR
MRWF 33 kV - Collector Bus
MVAR Control
D-VAR
MCE
PTWind Farm
33 kV Feeder
System
Circuit Breaker
Capacitor Switch
Disconnect Switch
4 x 4 MVAR D-VAR STATCOM (16 MVAR)
4 x 10 MVAR of Cap Banks (40 MVAR)
Synchronous
Condenser
MRWF 110 kV Bus – Regulation Bus
PT
Monitoring
PT
Synchronous
CondenserVestas
Wind Park Controller
AMSC/Vestas
Communication
D-VAR
110 kV
Transend Grid
Derby 110 Bus kV – POI and GPS Requirements Met
10 MVAR
4.1st
Filter Bank
54 km
CT
Master Control
Enclosure
D-VAR
9
© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop 10
Analysis Approach• Worked with consultants and Vestas by providing models and expert
advice as to how the D-VAR® STATCOM would operate in certain
circumstances
• Used harmonic analysis to ensure that the wind farm had no resonance
or voltage distortion issues by detuning the four 33 kV capacitor banks
© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop
Karara Mine
© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop 12
Background• Karara Mine in Western Australia is a joint venture between Gindalbie Metals Ltd and
AnSteel Group
• Because of Karara Mine’s size and location, it had to solve some unique voltage, power
factor, and motor starting challenges, as well as ensure that the mine met Western
Power’s interconnection requirements before operations could begin
• The D-VAR® STATCOM was installed at two locations:
Karara Mine site
Western Power’s (WP’S) Eneabba substation
• The D-VAR STATCOM system enables the mine:
to meet WP’s voltage requirements for loads < 50 MW
to meet WP’s PF requirements for loads > 50 MW
to mitigate voltage drops that can occur during the start-up of the mine’s largest
induction motors
to avoid harmonic voltage distortions and parallel resonances at the 330 kV and
33 kV voltage levels and to meet Western Power’s distortion limits
• AMSC’s D-VAR solution is also meeting Western Power’s VAR support requirements for
the Eneabba substation
© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop
Karara Mine D-VAR® Installation
5 x 4 MVA
33/0.48 kV
Transformer
20 MVAR
5 x 4 MVARMVAR Control
Two
330/33/11 kV LTC
150/180 MVA
Transformers
3 x 20 MVAR
PT
MCE
Voltage &
Current
Monitoring
N.C.
33 kV
330 kV
N.C.
8 x 6 MVAR Plant Load
PT
Plant Load
CT
Long
330 kV Line
Three
Springs
330 kV
CT
Eneabba
132 kV
Very Long
132 kV Line
CT
Time Frame Sources
Contingent Interim Ultimate
Power Factor POI
4 C-Filters
Detuned 5th
Q = 5.2
Rp = 200 Ohms
4 High Pass Filters
Detuned 6.7th
Q = 1.44
Rp = 40 Ohms
MMMMMMMMMM
Start Motors Via the
Motor Start Signal Line
D-VAR D-VAR D-VARD-VARD-VAR
13
© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop 14
Analysis Approach• Used loadflow analysis determined the overall number and step size
of the 33 kV capacitor banks so that the plant could meet its minimum
power factor (PF) requirements at the appropriate locations for the
three different timeframes
• Used loadflow and stability analysis to design the D-VAR® STATCOM’s
control system (Master control enclosure – MCE) so that it operated
appropriately in both voltage and PF modes and met Western Power’s
requirements
• Used loadflow and stability analysis to verify that the size of the D-VAR
STATCOM at the Karara Mine was sufficient in size to assist in starting
the plant’s largest induction motors
• Used harmonic analysis to ensure that the plant had no resonance or
voltage distortion issues by detuning the 33 kV PF correction capacitor
banks
© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop
Prominent Hill Mine
© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop 16
Background• The Prominent Mine is owned and operated by OZ Minerals and was opened in 2009
• The mine is located in South Australia and mines copper and gold
• The mine’s mining process uses electrically high powered crushing, grinding, and
flotation equipment.
• The starting of the mine’s four 6 MW ball and SAG mill motors:
draws 130% rated full load current
takes up to 20 seconds to start
drops the 11 kV bus voltage to 84%
causes other loads to trip on under voltage
impacts the 132 kV transmission voltage
• The mine’s 8 MVAR D-VAR® STATCOM was installed on its main 11 kV bus
• The D-VAR STATCOM provides the mine the ability:
to limit the motor startup step change in voltage to a maximum of 5%
to maintain the 132 kV PF at unity
to dynamically regulate the mine’s 11 kV distribution bus
© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop
Prominent Hill D-VAR® Installation
MMMM
2 x 4 MVA
11/0.48 kV
Transformer
8 MVAR
2 x 4 MVARD-VAR
MVAR Control
Voltage & Current
Monitoring
132 kV
PT
Rest of
Mine Load
CT
To
Olympic
Dam
(~180km)
D-VAR
2 x 45 MVA
132/11 kV
12.5% Z
11 kV
Start Motors Via the
Motor Start Signal Line
MCE
Motors
2 x 6 MW Ball Mill
2 x 6 MW SAG Mill
21 MVAR
7 x 3 MVAR
17
© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop 18
Analysis Approach
• Used loadflow and stability analysis to show the step voltage
drop impacts of four mill motor starts on the uncompensated
system
• Used loadflow and stability analysis to size the D-VAR® STATCOM
system and its parameters to reduce the motor starting voltage
dips to < 5%
• Used loadflow analysis to develop the D-VAR’s PF regulation and
capacitor bank control parameters to insure that the mine
consumes nor provides any VARs to the 132 kV grid (operates at
a unity PF)
• Utilizes “Line Drop Compensation” to control remote end power
factor at the PCC.
© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop
Ergon St. George Substation
© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop 20
Background
• The St. George substation is located near St. George
Queensland, Australia and is owned by Ergon Energy
• The project was to replace an aging SVC which provided day to
day voltage regulation as well as for fast acting voltage support
for the loss of certain lines or generators during heavy load
periods
• The site had significant harmonic voltage distortion already and
any installed equipment should not be adversely impacted by
the this voltage harmonics nor amplify it to unacceptable levels
• The substations SVC was replaced with an 8 MVAR D-VAR®
STATCOM derated to 6.4 MVAR and three 5 MVAR 33 kV
capacitor banks (Today’s D-VAR STATCOM would not require to
be derated)
© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop
N.C.
Switch
Ergon St. George D-VAR® Installation
33 kV
66/33 kVTransformer
MVAR Control
Voltage
Monitoring
3 x 5 MVAR
Capacitor Banks
Detuned 2.8th
Substation 66 kV Bus
AMSC D-VAR System
Scope of Supply
PT
MCE
D-VAR D-VAR
PTPT
2 x 4 MVA
33/0.48 kV
Transformer
6.4 MVAR
2 x 3.2 MVAR
21
© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop 22
Comparison of Solutions• AMSC considered proposing SVCs and D-VAR® STATCOMs to replace Ergon’s
aging St. George SVC, but chose only the D-VAR STATCOM
• Field testing and analysis of data has shown that the D-VAR STATCOM injects
very low levels of harmonics currents and is a much more robust solution
when installed in a high harmonic environment when compared with most
SVC designs
• An SVC solution would likely have:
a standalone harmonic filter to ensure that the SVC would operate
properly and not impact other utility facilities and add cost to the solution
be subject to a single point of failure in the harmonic filter in the SVC and
the harmonic filter
• The D-VAR STATCOM has several performance characteristics that are superior
to SVCs that are beneficial to this application such as:
faster response times
short term overload capability
more robust low voltage performance
© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop
Essential Energy’s
Nyngan Substation Installation
© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop
• The potential voltage stability problem that the Nyngan area can
experience can be traced back to the high impedance and long
distance of the 66 kV circuits that are radially supplied by Nyngan
substation
• A voltage stability event can be triggered by a trip of the Nyngan PV
solar plant
• A D-VAR® STATCOM is installed at the Nyngan substation’s 22 kV bus
• Its capability is ±4 MVAR continuous and ±12 MVAR dynamic
• Its two fold purpose is
- to regulate Nyngan 66 kV bus voltage
- to provide dynamic VARs to assist the transmission system’s voltage
recovery for a trip of the Nyngan PV solar plant
24
Background
© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop 25
Nyngan Substation Installation
22 kV
MVAR
Control
D-VAR
66 kV
PT
Monitoring
Voltages &
Currents
Master Control
Enclosure
PT
CTPT
132 kV
132/66 kV Transformer
66/22 kV Transformer
To Dubbo Substation
22/0.48 kV
Transformer
Local Line
Local Lines
4 MVAR
D-VAR
MCE
CT
2 x 4.8 MVAR
Capacitor Banks
© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop 26
Analysis Approach
• Loadflow analysis was conducted at peak and light load conditions
• No problems arise when Nyngan area is lightly loaded or when the
load supplied by the Nyngan substation is treated as lumped load
• QV analysis at peak load and using a proper load profile in the Nyngan
area showed that a trip of the Nyngan PV solar plant could cause a
voltage collapse problem
• QV analysis helped determine the size of the D-VAR STATCOM so that
there would be enough dynamic reactive capability to prevent voltage
collapse from occurring for the tripping of the Nyngan PV solar plant
© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop
Essential Energy’s
Nyngan Area D-VAR System
Installations
© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop
• Essential Energy’s Nyngan substation is served from two long 132 kV
transmission lines from the Dubbo substation
• Outage of one of the two 132 kV transmission lines can cause low
voltage problems in the Nyngan area – possibly a voltage stability issue
• Multiple D-VAR® STATCOM systems are installed at the Nyngan area to
support the grid
• Each D-VAR is capable of ±4 MVAR continuous and ±12 MVAR dynamic
• The D-VAR systems two fold purpose are
- to regulate the Nyngan area voltages
- to provide dynamic VARs to assist the transmission system’s post
fault voltage recovery
28
Background
© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop 29
Essential Energy’s Nyngan AreaLocation of D-VAR Installations
Bourke 66 kV
Giralambone/Tritton
Nyngan 132/66 kV
Dubbo 132 & 66 kV
Wellington 330/132 kV
Nevertire
Dubbo 132/66 kV
Narromine
Elura
CSA
Peak
Mt BoppyCobar Town66/12 kV
120 km
180 km
50 km
© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop 30
Essential Energy’s D-VAR® Installations
From
Dubbo 132 kV
Nyngan
Elura
CSA
Peak
Bourke 66 kV
Giralambone/Tritton
Mt BoppyCobar Town
66/12 kV
Nyngan
Solar Plant
© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop 31
Analysis Approach• Used loadflow analysis to design the D-VAR systems’ voltage regulation controls so
that when the measured voltage changes relative to the Vref the D-VAR will respond
quickly with reactive output to mitigate the sudden voltage change
• For example, a brief MW decrease, caused by a cloud passing over the Nyngan Solar
Plant, dips the voltage for a period of say ten seconds then it returns to the long-term
average - the VAR output of the D-VAR STATCOM would rise for this short period of
time and then slowly fall back to zero
• Used stability analysis to design the D-VAR® systems’ control system so that it
operated appropriately for faults and voltage transients on the transmission system
• A sensitivity analysis with respect to motor modeling was conducted to determine its
impact on Nyngan area post fault voltage recoveries
• For example, a fault on one of the two Dubbo-Wellington 132 kV lines causes a
transient voltage dip and a slow voltage recovery - the VAR output of the D-VAR
systems would rise to their transient capacitive output (12 MVAR for each 4 MVAR
STATCOM) for this short period of time and then continue at their continuous
capacitive output level and if necessary switch in the capacitor banks under their
control
© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop© 2013 AMSC. Voltage Stability & Transmission Technologies Workshop
Session and Workshop
Q & A
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