The example described in this section illustrates application of Simscape™ Power Systems™ software to study the steady-state and dynamic performance of a 9 MW wind farm connected to a distribution system.
The wind farm consists of six 1.5 MW wind turbines connected to a 25 kV distribution system exporting power to a 120 kV grid through a 30 km 25 kV feeder. A 2300V, 2 MVA plant consisting of a motor load (1.68 MW induction motor at 0.93 PF) and of a 200 kW resistive load is connected on the same feeder at bus B25. A 500 kW load is also connected on the 575 V bus of the wind farm. The single-line diagram of this system is illustrated in Single-Line Diagram of the Wind Farm Connected to a Distribution System.
Single-Line Diagram of the Wind Farm Connected to a Distribution System
Both the wind turbine and the motor load have a protection system monitoring voltage, current and machine speed. The DC link voltage of the DFIG is also monitored. Wind turbines use a doubly-fed induction generator (DFIG) consisting of a wound rotor induction generator and an AC/DC/AC IGBT-based PWM converter. The stator winding is connected directly to the 60 Hz grid while the rotor is fed at variable frequency through the AC/DC/AC converter. The DFIG technology allows extracting maximum energy from the wind for low wind speeds by optimizing the turbine speed, while minimizing mechanical stresses on the turbine during gusts of wind. The optimum turbine speed producing maximum mechanical energy for a given wind speed is proportional to the wind speed (see Wind Turbine Doubly-Fed Induction Generator (Phasor Type) block of the relib/Wind Generation library for more details). Another advantage of the DFIG technology is the ability for power electronic converters to generate or Turbine Power Characteristics absorb reactive power, thus eliminating the need for installing capacitor banks as in the case of squirrel-cage induction generators.
This system is available in the
power_wind_dfig model. Load this model and
save it in your working directory as
case3to allow further modifications to
the original system. In this case study, the rotor is running at subsynchronous speed for wind
speeds lower than 10 m/s and it is running at a super-synchronous speed for higher wind speeds.
The turbine mechanical power as function of turbine speed is displayed in for wind speeds
ranging from 5 m/s to 16.2 m/s. These characteristics are obtained with the specified parameters
Turbine data (Turbine Power Characteristics).
Turbine Power Characteristics
The DFIG is controlled to follow the ABCD curve in Turbine Power Characteristics. Turbine speed optimization is obtained between point B and point C on this curve.
The wind turbine model is a phasor model that allows transient stability type studies with long simulation times. In this case study, the system is observed during 50 s. The 6-wind-turbine farm is simulated by a single wind-turbine block by multiplying the following three parameters by six, as follows:
The nominal wind turbine mechanical output power:
6*1.5e6 watts, specified in the
Turbine data menu
The generator rated power: 6*1.5/0.9 MVA (6*1.5 MW
at 0.9 PF), specified in the
Generator data menu
The nominal DC bus capacitor: 6*10000 microfarads,
specified in the
Converters data menu
The mode of operation is set to
Voltage regulation in
the Control Parameters dialog box.
The terminal voltage will be controlled to a value imposed by the
reference voltage (Vref=1 pu) and the voltage droop (Xs=0.02 pu).
Observe the turbine response to a change in wind speed. Initially,
wind speed is set at 8 m/s, and then at t=5s, wind speed increases
suddenly at 14 m/s. Waveforms for a Gust of Wind (Wind Farm in Voltage Regulation Mode) illustrates
the waveforms associated with this simulation. At t=5 s, the generated
active power starts increasing smoothly (together with the turbine
speed) to reach its rated value of 9MW in approximately 15s. Over
that time frame the turbine speed increases from 0.8 pu to 1.21 pu.
Initially, the pitch angle of the turbine blades is zero degree and
the turbine operating point follows the red curve of the turbine power
characteristics up to point D. Then the pitch angle is increased from
0 deg to 0.76 deg to limit the mechanical power. Observe also the
voltage and the generated reactive power. The reactive power is controlled
to maintain a 1 pu voltage. At nominal power, the wind turbine absorbs
0.68 Mvar (generated Q=-0.68 Mvar) to control voltage at 1pu. If you
change the mode of operation to
Var regulation with
the Generated reactive power Qref set
to zero, you will observe that the voltage increases to 1.021 pu when
the wind turbine generates its nominal power at unity power factor
(Waveforms for a Gust of Wind (Wind Farm in Var Regulation Mode)).
Waveforms for a Gust of Wind (Wind Farm in Voltage Regulation Mode)
Waveforms for a Gust of Wind (Wind Farm in Var Regulation Mode)
Now observe the impact of a voltage sag resulting from a remote
fault on the 120 kV system. In this simulation the mode of operation
Var regulation with Qref=0 and the
wind speed is constant at 8 m/s. A 0.15 pu voltage drop lasting 0.5
s is programmed, in the 120 kV voltage source menu, to occur at t=5
s. The simulation results are illustrated in Voltage Sag on the 120 kV System (Wind Farm in Var Regulation Mode).
Observe the plant voltage and current as well as the motor speed.
Note that the wind farm produces 1.87 MW. At t=5 s, the voltage falls
below 0.9 pu and at t=5.22 s, the protection system trips the plant
because an undervoltage lasting more than 0.2 s has been detected
(exceeding protection settings for the Plant subsystem). The plant
current falls to zero and motor speed decreases gradually, while the
wind farm continues generating at a power level of 1.87 MW. After
the plant has tripped, 1.25 MW of power (P_B25 measured at bus B25)
is exported to the grid.
Voltage Sag on the 120 kV System (Wind Farm in Var Regulation Mode)
Now, the wind turbine control mode is changed to
regulation and the simulation is repeated. You will notice
that the plant does not trip anymore. This is because the voltage
support provided by the 5 Mvar reactive power generated by the wind
turbines during the voltage sag keeps the plant voltage above the
0.9 pu protection threshold. The plant voltage during the voltage
sag is now 0.93 pu (Voltage Sag on the 120 kV System (Wind Farm in Voltage Regulation Mode)).
Voltage Sag on the 120 kV System (Wind Farm in Voltage Regulation Mode)
Finally, now observe the impact of a single phase-to-ground
fault occurring on the 25 kV line. At t=5 s a 9 cycle (0.15 s) phase-to-ground
fault is applied on phase A at B25 bus. When the wind turbine is in
regulation mode, the positive sequence voltage at wind turbine
terminals (V1_B575) drops to 0.8 pu during the fault, which is above
the undervoltage protection threshold (0.75 pu for a t>0.1 s).
The wind farm therefore stays in service (Wind Farm Waveforms During Fault at Bus B25 (Wind Farm in Voltage Regulation Mode)).
However, if the
Var regulation mode is used with
Qref=0, the voltage drops under 0.7 pu and the undervoltage protection
trips the wind farm. We can now observe that the turbine speed increases.
At t=40 s the pitch angle starts to increase to limit the speed (Wind Farm Waveforms During Fault at Bus B25 (Wind Farm in Var Regulation Mode)).
Wind Farm Waveforms During Fault at Bus B25 (Wind Farm in Voltage Regulation Mode)
Wind Farm Waveforms During Fault at Bus B25 (Wind Farm in Var Regulation Mode)