Wind Utility Facts
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FACTS-based Schemes for Distribution Networks with Dispersed Renewable Wind Energy Professor Dr. Adel M Sharaf ECE Dept., UNB Fredericton, NB, Canada
Outline
Introduction Motivations Sample Study System Modelling Novel FACTS-based Schemes Controller Tuning Digital Simulation Conclusions and Recommendations
Introduction
Wind is a renewable Green Energy source
Load
kinetic Energy
Mechanical Energy
Electrical Energy
Introduction
Wind is also a clean Abundant Source No Emissions, No Pollutions carbon dioxide
sulfur dioxide particulates
Introduction
Wind energy is a promising green energy and becomes increasingly viable &popular. The cost of wind-generated electric energy has dropped substantially(6-7 per KWH). By 2005, the worldwide capacity had been increased to 58,982 MW-Cost is $ 20002500/KW World Wind Energy Association expects 120,000 MW to be installed globally by 2010.
Introduction Total installed wind power MW-capacity （ data from World Wind Energy Association) 20000 18000 16000 14000 12000 10000 8000
2004 (MW ) 2005 (MW )
6000 4000 2000 0
Germ any
USA
Denm ark CANADA
Introduction
Wind Energy Conversion System (WECS) Using Large Squirrel Cage/Slip ring Induction Generators
Stand alone-Village Electricity Electric Grid Connected WECS
Distributed/Dispersed/Farm Renewable Wind Energy Schemes
Located closer to Load Centers Low Reliability, Utilization, Security
Motivations
Energy crisis
Shortage of conventional fossil fuel based energy Escalating/rising cost of fossil fuels
Environmental/Pollution/GHG Issues
Greenhouse gas emission /Carbon Print Acid Rain/Smog/VOC-Micro-Particulates Water/Air/Soil Pollution &Health Hazards
Motivations
Large wind farm utilization is also emerging (50MW-250 MW) Sized Using Super Wind driven Turbines 1.6, 3.6, 5 MW Sizes Many new interface Regulations/Standards/PQ Requirements regarding full integration of large distributed/dispersed Wind Farms into Utility Grid.
Motivations
Challenges for Utility Grid–Wind Integration.
Stochastically-Highly Variable wind power injected into the Utility Grid. Increased Wind MW-Power penetration Level. Low SCR-Weak Distribution/Sub Transmission/Transmission Networks
- Mostly of a Radial Configuration - Large R/X ratio distribution Feeder with high Power Losses (4-10 %), Voltage Regulation Problems/Power Quality/Interference Issues. Required Reactive Power Compensation & Increased Burden brought by the induction generator
Sample Distribution Study System L.L.1
Infinite Bus
T1
L.L.2
T2
T3 L.L.3
WECS
I.M.
N.L.L
WECS-Decoupled Interface Scheme I.G.
Uncontrolled Rectifier
Lf Cf
Wind Turbine
DC Link Interface Cself
PWM Inverter
To Grid
System Description-wind turbine
Wind turbine model based on the steady-state power characteristics of the turbine 1 Pm = C p × S × ρ × V 3 2
S -- the Total BladeArea swept by the rotor blades (m^2) v -- the wind velocity (m/s) ρ--air density (kg/v^3)
System Description C1=0.5176, C2=116, C3=0.4, C4=5, C5=21 and C6=0.0068 c3 λi
C2 C p (λ , β ) = C1 − C3 β − C4 e + C6 λ λi 1 1 0.035 = − 3 λi λ + 0.08β β + 1
tip speed ratio λ is the quotient between the tangential speed of the rotor blade tips and the undisturbed wind velocity
System Description
– Wind speed
The dynamic wind speed model consists of four basic components:
Mean wind speed-14 m/s Wind speed ramp with a slope of ±5.6 Wind gust v = Ag [1− cos(2π (t / Dg − Tsg / Dg ))] Ag: the amplitude of the gust Tsg: the starting time of the gust Teg: the end time of the gust Dg = Teg - Tsg Turbulence components: a random Gaussian series
Wind Speed Dynamic Model 18 16
The eventual wind speed applied to the wind turbine is the summation of all four key components.
14
Wind Speed (m/s)
12 10 8 6 4 2 0 0
0.1
0.2
0.3
0.4 Time(Second)
0.5
0.6
0.7
0.8
MPFC-FACTS Scheme 1
Complementary PWM pulses to ensure dynamic topology change between switched capacitor and tuned arm power filter Two IGBT solid state switches control the operation of the MPFC via a six-pulse diode bridge
Tri-loop Error Driven Controller Modulation Index Voltage Stabilization loop Current Dynamic Error Tracking loop
Current Harmonic Tracking Loop
DVR-FACTS Scheme 2
If S1 is high and S2 is low, both the series A combination of and shunt capacitors series capacitor are connected into the andcircuit, shuntwhile the resistor and inductor capacitor will be fully shorted compensation
Flexible If S1 isstructure low and S2 is high, the series modulated by capacitor a will be removed Tri-loop Error from the system, the resistor and Driven inductorController will be connected to the shunt capacitors as a tuned arm filter
HPFC-FACTS Scheme 3
Use of a 6-pulse VSC based APF to have faster controllability and enhanced dynamic performance Combination of tuned passive power filter and active power filter to reduce cost
Coupling capacitor Coupling transformer PWM converter DC Capacitor to provide the energizing voltage
Passive Filter tuned near 3rd harmonic frequency
Novel Scheme-3 Multi-loop Error Driven Controller
Novel Decoupled Multi-loop Error Driven Controller
Using decoupled direct and quad. (d , q) voltage components Using The Phase Locked Loop (PLL) to get the required synchronizing signal- phase angle of the synthesized VSC-Three Phase AC output voltages with Utility-Bus Using Proportional plus Integral (PI) controller to regulate any tracked errors Using Pulse Width Modulation-PWM with a variable modulation index -m
Novel Decoupled Multi-loop Error Driven Controller
Outer-Voltage Regulator: Tri-loop Dynamic Error-Driven controller
The voltage stabilization loop The current dynamic error tracking loop The dynamic power tracking loop
Inner-Voltage Regulator: Mainly to control the DC-Side capacitor charging and discharging voltage to ensure almost a near constant DC capacitor voltage
Controller Tuning
Control Parameter: Selection/optimization Using a guided Off-Line Trial-and-Error Method based on successive digital simulations
Minimize function-Jo 2 N the objective
J o = ∑ et ( k ) k =1
Where settling time count N =
Tsettling Tsample
Find optimal Gains: kp, ki and individual loop weightings (γ) to yield a near minimum Jo under different set-selections of the controller parameters
ASampleofJ0-Ki-Kp3-phase-portraitforControllerParameterSearching
1
0.8
Jo
0.6
0.4
0.2
0 15 10 5 Ki
0
0.5
1 Kp
1.5
2
Digital Simulation
Digital Study System Validation is done by using Matlab/Simulink/Sim-Power Software Environment under a sequence of excursions:
Load switching/Excusrions
At t = 0.2 second, the induction motor was removed from bus 5 for a duration of 0.1 seconds; At t = 0.4 second, linear load was removed from bus 4 for a duration of 0.1 seconds; At t = 0.5 second, the AC distribution system recovered to its initial state.
Wind-Speed Gusting changes modeled by dynamic wind speed-Software model
Digital Simulation
Digital Simulation Environment: MATLAB /Simulink/Sim-Power Using the discrete simulation mode with a sample time of 0.1 milliseconds The digital simulations were carried out without and with the novel FACTS-based devices located at Bus 5 for 0.8 seconds
System Dynamic Responses at Bus 2 without and with MPFC withcompensation without compensation
0.1
0.2
0.3
0.4 Current (rms)
0.5
0.6
0.7
0.8
5 3 1 0 0
0.1
0.2
0.3
0.4 Real Power
0.5
0.6
0.7
0.8
Per unit
2 1 0 -1 0
0.1
0.2
0.3
0.4 ReactivePower
0.5
0.6
0.7
0.8
1 0 -1 -2 0
0.1
0.2
0.3
0.4 PowerFactor
0.5
0.6
0.7
0.8
1.1 1 0.5 0 0
0.1
0.2
0.3
0.4 Time(Second)
0.5
0.6
0.7
0.8
Per unit
1.5 1 0.5 0 0
Per unit
Per unit
Voltage(L-Lrms)
System Dynamic Responses at Bus 3 without and with MPFC withcom pensation without com pensation
Per unit
0.1
0.2
0.3
0.4 Current (rm s)
0.5
0.6
0.7
0.8
Per uint
1.5 1 0.5 0 0
0.1
0.2
0.3
0.4 RealPower
0.5
0.6
0.7
0.8
1 0.5 0 0
0.1
0.2
0.3
0.4 ReactivePower
0.5
0.6
0.7
0.8
1 0.5 0 -0.5 0
0.1
0.2
0.3
0.4 PowerFactor
0.5
0.6
0.7
0.8
1 0.5 0 0
0.1
0.2
0.3
0.4 Tim e(Second)
0.5
0.6
0.7
0.8
Per unit
2 1.5 1 0.5 0 0
Per unit
Voltage(L-Lrm s)
System Dynamic Responses at Bus 5 without and with MPFC withcompensation without compensation
Per unit
0.1
0.2
0.3
0.4 Current (rms)
0.5
0.6
0.7
0.8
Per unit
1.5 1 0.5 0 0
0.1
0.2
0.3
0.4 Real Power
0.5
0.6
0.7
0.8
1 0.5 0 0
0.1
0.2
0.3
0.4 ReactivePower
0.5
0.6
0.7
0.8
1 0 -1 0
0.1
0.2
0.3
0.4 PowerFactor
0.5
0.6
0.7
0.8
1 0.5 0 0
0.1
0.2
0.3
0.4 Time(Second)
0.5
0.6
0.7
0.8
Per unit
1.5 1 0.5 0 0
Per unit
Voltage(L-Lrms)
The frequency variation at the WECS interface without and with MPFC 62 withcom pensation without com pensation 61
Frequency (Hz)
60
59
58
57
56 0
0.1
0.2
0.3
0.4 Tim e(Second)
0.5
0.6
0.7
0.8
System Dynamic Responses at Bus 2 without and with DVR withcompensation without compensation
0.2
0.3
0.4 Current (rms)
0.5
0.6
0.7
0.8
3 1 0 0
0.1
0.2
0.3
0.4 Real Power
0.5
0.6
0.7
0.8
2 1 0 -1 0
0.1
0.2
0.3
0.4 ReactivePower
0.5
0.6
0.7
0.8
1 0 -1 -2 0
0.1
0.2
0.3
0.4 PowerFactor
0.5
0.6
0.7
0.8
1 0.5 0 0
0.1
0.2
0.3
0.4 Time(Second)
0.5
0.6
0.7
0.8
Per unit
0.1
Per unit
1.5 1 0.5 0 0
Per unit
Per unit
Voltage(L-Lrms)
System Dynamic Responses at Bus 3 without and with DVR withcom pensation without com pensation
0.1
0.2
0.3
0.4 Current (rm s)
0.5
0.6
0.7
0.8
Per unit
1.5 1 0.5 0 0
0.1
0.2
0.3
0.4 RealPower
0.5
0.6
0.7
0.8
1 0.5 0 0
0.1
0.2
0.3
0.4 ReactivePower
0.5
0.6
0.7
0.8
2 1 0 -1 0
0.1
0.2
0.3
0.4 PowerFactor
0.5
0.6
0.7
0.8
1 0.5 0 0
0.1
0.2
0.3
0.4 Tim e(Second)
0.5
0.6
0.7
0.8
Per unit
Per unit
1.5 1 0.5 0 0
Per unit
Voltage(L-Lrm s)
System Dynamic Responses at Bus 5 without and with DVR withcompensation without compensation
0.1
0.2
0.3
0.4 Current (rms)
0.5
0.6
0.7
0.8
Per unit
1 0.5 0 0
0.1
0.2
0.3
0.4 Real Power
0.5
0.6
0.7
0.8
0.5 0 0
0.1
0.2
0.3 0.4 ReactivePower
0.5
0.6
0.7
0.8
1 0.5 0 -0.5 0
0.1
0.2
0.3
0.4 PowerFactor
0.5
0.6
0.7
0.8
1 0.5 0 0
0.1
0.2
0.3
0.4 Time(Second)
0.5
0.6
0.7
0.8
Per unit
Per unit
1.5 1 0.5 0 0
Per unit
Voltage(L-Lrms)
The frequency variation at the WECS interface without and with DVR 62 withcompensation without compensation 61
Frequency (Herz)
60
59
58
57
56
0
0.1
0.2
0.3
0.4 Time(Second)
0.5
0.6
0.7
0.8
System Dynamic Responses at Bus 2 without and with HPFC withcompensation without compensation
0.2
0.3
0.4 Current (rms)
0.5
0.6
0.7
0.8
3 1 0 0
0.1
0.2
0.3
0.4 Real Power
0.5
0.6
0.7
0.8
2 1 0 -1 0
0.1
0.2
0.3
0.4 ReactivePower
0.5
0.6
0.7
0.8
1 0 -1 0
0.1
0.2
0.3
0.4 Power Factor
0.5
0.6
0.7
0.8
1 0.5 0 0
0.1
0.2
0.3
0.4 Time(second)
0.5
0.6
0.7
0.8
Per unit
0.1
Per unit
1.5 1 0.5 0 0
Per unit
Per unit
Voltage(L-Lrms)
System Dynamic Responses at Bus 3 without and with HPFC withcompensation without compensation
0.1
0.2
0.3
0.4 Current (rms)
0.5
0.6
0.7
0.8
1 0.5 0 0
0.1
0.2
0.3
0.4 Real Power
0.5
0.6
0.7
0.8
Per unit
0.5 0 -0.2 0
0.1
0.2
0.3
0.4 ReactivePower
0.5
0.6
0.7
0.8
0.5 0 -0.5
0
0.1
0.2
0.3
0.4 Power Factor
0.5
0.6
0.7
0.8
1 0.5 0 0
0.1
0.2
0.3
0.4 Time(Second)
0.5
0.6
0.7
0.8
Per unit
1.5 1 0.5 0 0
Per unit
Per unit
Voltage(L-Lrms)
System Dynamic Responses at Bus 5 without and with HPFC withcompensation without compensation
0.1
0.2
0.3
0.4 Current (rms)
0.5
0.6
0.7
0.8
Per unit
1.5 1 0.5 0 0
0.1
0.2
0.3
0.4 Real Power
0.5
0.6
0.7
0.8
1 0.5 0 0
0.1
0.2
0.3
0.4 ReactivePower
0.5
0.6
0.7
0.8
1 0.5 0 -0.5 0
0.1
0.2
0.3
0.4 Power Factor
0.5
0.6
0.7
0.8
1 0.5 0 0
0.1
0.2
0.3
0.4 Time(Second)
0.5
0.6
0.7
0.8
Per unit
Per unit
1.5 1 0.5 0 0
Per unit
Voltage(L-Lrms)
The frequency variation at the WECS interface without and with HPFC 62 withcompensation without compensation 61
Frequency (Herz)
60
59
58
57
56
0
0.1
0.2
0.3
0.4 Time(Second)
0.5
0.6
0.7
0.8
Comparison of Voltage THD with Different Compensation Scheme Bus Without With number compensator MPFC 1 28.39% 4.90%
With With DVR HPFC 11.9% 4.99%
2
32.70%
4.60%
12.2% 4.88%
3
35.95%
4.29%
12.6% 4.69%
4
35.75%
3.51%
12.2% 4.51%
5
35.77%
3.32%
13.1% 3.90%
6
36.04%
3.57%
8.57% 4.57%
Comparison of Steady-state Bus Voltage with Different Compensation Scheme Bus Without With number compensator MPFC 1 0.97 1.02
With DVR 1.01
With HPFC 1.05
2
0.95
1.00
1.03
1.05
3
0.94
1.00
1.02
1.05
4
0.89
0.99
1.02
1.05
5
0.86
0.99
1.02
1.06
6
0.83
0.96
1.03
1.05
Conclusions
Three Novel FACTS-based Converter & Control schemes, namely the MPFC, the DVR, and the HPFC, have been Developed and validated for voltage stabilization, power factor correction and power quality improvement in the distribution network with dispersed wind energy integrated.
Recommendation
The Low-Cost MPFC-Scheme 1 is preferred for low to medium size wind energy integration schemes (from 600 to 5000 kW). The DVR-Scheme 2 is good for Strong AC subtransmission and distribution systems with large X/R ratio The HPFC-Scheme 2 Active Power Filter & Capacitor Compensator is most suitable for Larger Wind-Farms with MW-energy penetration level (100 MW or above).
Recommendation
The schemes validated in this research need to be fully tested in the distribution network with real dispersed wind energy systems. This research can be extended to the grid integration of other dispersed renewable energy. Other Artificial Intelligence based control strategies can be investigated in future work.
Conclusions
A Validation Study of a unified sample study system Using the ATLAB/Simulink A dynamic wind speed software model was developed to simulate the varying Random/Stochastic and temporal wind variations in the MATLAB/Simulink Three Novel FACTS based Stabilization Schemes were validated using digital simulations Novel Control strategies using dynamic Multi-Loop Decoupled Controllers were developed & Validated
Publications
[1] A. M. Sharaf and Weihua Wang, ‘A Low-cost Voltage Stabilization and Power Quality Enhancement Scheme for a Small Renewable Wind Energy Scheme’, 2006 IEEE International Symposium on Industrial Electronics, 2006, p.1949-53, Montreal, Canada [2] A. M. Sharaf and Weihua Wang, ‘A Novel Voltage Stabilization Scheme for Standalone Wind Energy Using A Dynamic Sliding Mode Controller’, Proceeding- the 2nd International Green Energy Conference, 2006, Vol. 2, p.205-301, Oshawa, Canada [3] A. M. Sharaf, Weihua Wang, and I. H. Altas, ‘Novel STATCOM Controller for Reactive Power Compensation in Distribution Networks with Dispersed Renewable Wind Energy’, 2007 Canadian Conference on Electrical and Computer Engineering, Vancouver, Canada, April, 2007 [4] A. M. Sharaf, Weihua Wang, and I. H. Altas, ‘A Novel Modulated Power Filter Compensator for Renewable Dispersed Wind Energy Interface’, the International Conference on Clean Electrical Power, 2007, Capri, Italy, May, 2007 [5] A. M. Sharaf, Weihua Wang, and I. H. Altas, ‘A Novel Modulated Power Filter Compensator for Distribution Networks with Distributed Wind Energy’ (Accepted by International Journal of Emerging Electric Power System)
Outline
Introduction Motivations Sample Study System Modelling Novel FACTS-based Schemes Controller Tuning Digital Simulation Conclusions and Recommendations
Introduction
Wind is a renewable Green Energy source
Load
kinetic Energy
Mechanical Energy
Electrical Energy
Introduction
Wind is also a clean Abundant Source No Emissions, No Pollutions carbon dioxide
sulfur dioxide particulates
Introduction
Wind energy is a promising green energy and becomes increasingly viable &popular. The cost of wind-generated electric energy has dropped substantially(6-7 per KWH). By 2005, the worldwide capacity had been increased to 58,982 MW-Cost is $ 20002500/KW World Wind Energy Association expects 120,000 MW to be installed globally by 2010.
Introduction Total installed wind power MW-capacity （ data from World Wind Energy Association) 20000 18000 16000 14000 12000 10000 8000
2004 (MW ) 2005 (MW )
6000 4000 2000 0
Germ any
USA
Denm ark CANADA
Introduction
Wind Energy Conversion System (WECS) Using Large Squirrel Cage/Slip ring Induction Generators
Stand alone-Village Electricity Electric Grid Connected WECS
Distributed/Dispersed/Farm Renewable Wind Energy Schemes
Located closer to Load Centers Low Reliability, Utilization, Security
Motivations
Energy crisis
Shortage of conventional fossil fuel based energy Escalating/rising cost of fossil fuels
Environmental/Pollution/GHG Issues
Greenhouse gas emission /Carbon Print Acid Rain/Smog/VOC-Micro-Particulates Water/Air/Soil Pollution &Health Hazards
Motivations
Large wind farm utilization is also emerging (50MW-250 MW) Sized Using Super Wind driven Turbines 1.6, 3.6, 5 MW Sizes Many new interface Regulations/Standards/PQ Requirements regarding full integration of large distributed/dispersed Wind Farms into Utility Grid.
Motivations
Challenges for Utility Grid–Wind Integration.
Stochastically-Highly Variable wind power injected into the Utility Grid. Increased Wind MW-Power penetration Level. Low SCR-Weak Distribution/Sub Transmission/Transmission Networks
- Mostly of a Radial Configuration - Large R/X ratio distribution Feeder with high Power Losses (4-10 %), Voltage Regulation Problems/Power Quality/Interference Issues. Required Reactive Power Compensation & Increased Burden brought by the induction generator
Sample Distribution Study System L.L.1
Infinite Bus
T1
L.L.2
T2
T3 L.L.3
WECS
I.M.
N.L.L
WECS-Decoupled Interface Scheme I.G.
Uncontrolled Rectifier
Lf Cf
Wind Turbine
DC Link Interface Cself
PWM Inverter
To Grid
System Description-wind turbine
Wind turbine model based on the steady-state power characteristics of the turbine 1 Pm = C p × S × ρ × V 3 2
S -- the Total BladeArea swept by the rotor blades (m^2) v -- the wind velocity (m/s) ρ--air density (kg/v^3)
System Description C1=0.5176, C2=116, C3=0.4, C4=5, C5=21 and C6=0.0068 c3 λi
C2 C p (λ , β ) = C1 − C3 β − C4 e + C6 λ λi 1 1 0.035 = − 3 λi λ + 0.08β β + 1
tip speed ratio λ is the quotient between the tangential speed of the rotor blade tips and the undisturbed wind velocity
System Description
– Wind speed
The dynamic wind speed model consists of four basic components:
Mean wind speed-14 m/s Wind speed ramp with a slope of ±5.6 Wind gust v = Ag [1− cos(2π (t / Dg − Tsg / Dg ))] Ag: the amplitude of the gust Tsg: the starting time of the gust Teg: the end time of the gust Dg = Teg - Tsg Turbulence components: a random Gaussian series
Wind Speed Dynamic Model 18 16
The eventual wind speed applied to the wind turbine is the summation of all four key components.
14
Wind Speed (m/s)
12 10 8 6 4 2 0 0
0.1
0.2
0.3
0.4 Time(Second)
0.5
0.6
0.7
0.8
MPFC-FACTS Scheme 1
Complementary PWM pulses to ensure dynamic topology change between switched capacitor and tuned arm power filter Two IGBT solid state switches control the operation of the MPFC via a six-pulse diode bridge
Tri-loop Error Driven Controller Modulation Index Voltage Stabilization loop Current Dynamic Error Tracking loop
Current Harmonic Tracking Loop
DVR-FACTS Scheme 2
If S1 is high and S2 is low, both the series A combination of and shunt capacitors series capacitor are connected into the andcircuit, shuntwhile the resistor and inductor capacitor will be fully shorted compensation
Flexible If S1 isstructure low and S2 is high, the series modulated by capacitor a will be removed Tri-loop Error from the system, the resistor and Driven inductorController will be connected to the shunt capacitors as a tuned arm filter
HPFC-FACTS Scheme 3
Use of a 6-pulse VSC based APF to have faster controllability and enhanced dynamic performance Combination of tuned passive power filter and active power filter to reduce cost
Coupling capacitor Coupling transformer PWM converter DC Capacitor to provide the energizing voltage
Passive Filter tuned near 3rd harmonic frequency
Novel Scheme-3 Multi-loop Error Driven Controller
Novel Decoupled Multi-loop Error Driven Controller
Using decoupled direct and quad. (d , q) voltage components Using The Phase Locked Loop (PLL) to get the required synchronizing signal- phase angle of the synthesized VSC-Three Phase AC output voltages with Utility-Bus Using Proportional plus Integral (PI) controller to regulate any tracked errors Using Pulse Width Modulation-PWM with a variable modulation index -m
Novel Decoupled Multi-loop Error Driven Controller
Outer-Voltage Regulator: Tri-loop Dynamic Error-Driven controller
The voltage stabilization loop The current dynamic error tracking loop The dynamic power tracking loop
Inner-Voltage Regulator: Mainly to control the DC-Side capacitor charging and discharging voltage to ensure almost a near constant DC capacitor voltage
Controller Tuning
Control Parameter: Selection/optimization Using a guided Off-Line Trial-and-Error Method based on successive digital simulations
Minimize function-Jo 2 N the objective
J o = ∑ et ( k ) k =1
Where settling time count N =
Tsettling Tsample
Find optimal Gains: kp, ki and individual loop weightings (γ) to yield a near minimum Jo under different set-selections of the controller parameters
ASampleofJ0-Ki-Kp3-phase-portraitforControllerParameterSearching
1
0.8
Jo
0.6
0.4
0.2
0 15 10 5 Ki
0
0.5
1 Kp
1.5
2
Digital Simulation
Digital Study System Validation is done by using Matlab/Simulink/Sim-Power Software Environment under a sequence of excursions:
Load switching/Excusrions
At t = 0.2 second, the induction motor was removed from bus 5 for a duration of 0.1 seconds; At t = 0.4 second, linear load was removed from bus 4 for a duration of 0.1 seconds; At t = 0.5 second, the AC distribution system recovered to its initial state.
Wind-Speed Gusting changes modeled by dynamic wind speed-Software model
Digital Simulation
Digital Simulation Environment: MATLAB /Simulink/Sim-Power Using the discrete simulation mode with a sample time of 0.1 milliseconds The digital simulations were carried out without and with the novel FACTS-based devices located at Bus 5 for 0.8 seconds
System Dynamic Responses at Bus 2 without and with MPFC withcompensation without compensation
0.1
0.2
0.3
0.4 Current (rms)
0.5
0.6
0.7
0.8
5 3 1 0 0
0.1
0.2
0.3
0.4 Real Power
0.5
0.6
0.7
0.8
Per unit
2 1 0 -1 0
0.1
0.2
0.3
0.4 ReactivePower
0.5
0.6
0.7
0.8
1 0 -1 -2 0
0.1
0.2
0.3
0.4 PowerFactor
0.5
0.6
0.7
0.8
1.1 1 0.5 0 0
0.1
0.2
0.3
0.4 Time(Second)
0.5
0.6
0.7
0.8
Per unit
1.5 1 0.5 0 0
Per unit
Per unit
Voltage(L-Lrms)
System Dynamic Responses at Bus 3 without and with MPFC withcom pensation without com pensation
Per unit
0.1
0.2
0.3
0.4 Current (rm s)
0.5
0.6
0.7
0.8
Per uint
1.5 1 0.5 0 0
0.1
0.2
0.3
0.4 RealPower
0.5
0.6
0.7
0.8
1 0.5 0 0
0.1
0.2
0.3
0.4 ReactivePower
0.5
0.6
0.7
0.8
1 0.5 0 -0.5 0
0.1
0.2
0.3
0.4 PowerFactor
0.5
0.6
0.7
0.8
1 0.5 0 0
0.1
0.2
0.3
0.4 Tim e(Second)
0.5
0.6
0.7
0.8
Per unit
2 1.5 1 0.5 0 0
Per unit
Voltage(L-Lrm s)
System Dynamic Responses at Bus 5 without and with MPFC withcompensation without compensation
Per unit
0.1
0.2
0.3
0.4 Current (rms)
0.5
0.6
0.7
0.8
Per unit
1.5 1 0.5 0 0
0.1
0.2
0.3
0.4 Real Power
0.5
0.6
0.7
0.8
1 0.5 0 0
0.1
0.2
0.3
0.4 ReactivePower
0.5
0.6
0.7
0.8
1 0 -1 0
0.1
0.2
0.3
0.4 PowerFactor
0.5
0.6
0.7
0.8
1 0.5 0 0
0.1
0.2
0.3
0.4 Time(Second)
0.5
0.6
0.7
0.8
Per unit
1.5 1 0.5 0 0
Per unit
Voltage(L-Lrms)
The frequency variation at the WECS interface without and with MPFC 62 withcom pensation without com pensation 61
Frequency (Hz)
60
59
58
57
56 0
0.1
0.2
0.3
0.4 Tim e(Second)
0.5
0.6
0.7
0.8
System Dynamic Responses at Bus 2 without and with DVR withcompensation without compensation
0.2
0.3
0.4 Current (rms)
0.5
0.6
0.7
0.8
3 1 0 0
0.1
0.2
0.3
0.4 Real Power
0.5
0.6
0.7
0.8
2 1 0 -1 0
0.1
0.2
0.3
0.4 ReactivePower
0.5
0.6
0.7
0.8
1 0 -1 -2 0
0.1
0.2
0.3
0.4 PowerFactor
0.5
0.6
0.7
0.8
1 0.5 0 0
0.1
0.2
0.3
0.4 Time(Second)
0.5
0.6
0.7
0.8
Per unit
0.1
Per unit
1.5 1 0.5 0 0
Per unit
Per unit
Voltage(L-Lrms)
System Dynamic Responses at Bus 3 without and with DVR withcom pensation without com pensation
0.1
0.2
0.3
0.4 Current (rm s)
0.5
0.6
0.7
0.8
Per unit
1.5 1 0.5 0 0
0.1
0.2
0.3
0.4 RealPower
0.5
0.6
0.7
0.8
1 0.5 0 0
0.1
0.2
0.3
0.4 ReactivePower
0.5
0.6
0.7
0.8
2 1 0 -1 0
0.1
0.2
0.3
0.4 PowerFactor
0.5
0.6
0.7
0.8
1 0.5 0 0
0.1
0.2
0.3
0.4 Tim e(Second)
0.5
0.6
0.7
0.8
Per unit
Per unit
1.5 1 0.5 0 0
Per unit
Voltage(L-Lrm s)
System Dynamic Responses at Bus 5 without and with DVR withcompensation without compensation
0.1
0.2
0.3
0.4 Current (rms)
0.5
0.6
0.7
0.8
Per unit
1 0.5 0 0
0.1
0.2
0.3
0.4 Real Power
0.5
0.6
0.7
0.8
0.5 0 0
0.1
0.2
0.3 0.4 ReactivePower
0.5
0.6
0.7
0.8
1 0.5 0 -0.5 0
0.1
0.2
0.3
0.4 PowerFactor
0.5
0.6
0.7
0.8
1 0.5 0 0
0.1
0.2
0.3
0.4 Time(Second)
0.5
0.6
0.7
0.8
Per unit
Per unit
1.5 1 0.5 0 0
Per unit
Voltage(L-Lrms)
The frequency variation at the WECS interface without and with DVR 62 withcompensation without compensation 61
Frequency (Herz)
60
59
58
57
56
0
0.1
0.2
0.3
0.4 Time(Second)
0.5
0.6
0.7
0.8
System Dynamic Responses at Bus 2 without and with HPFC withcompensation without compensation
0.2
0.3
0.4 Current (rms)
0.5
0.6
0.7
0.8
3 1 0 0
0.1
0.2
0.3
0.4 Real Power
0.5
0.6
0.7
0.8
2 1 0 -1 0
0.1
0.2
0.3
0.4 ReactivePower
0.5
0.6
0.7
0.8
1 0 -1 0
0.1
0.2
0.3
0.4 Power Factor
0.5
0.6
0.7
0.8
1 0.5 0 0
0.1
0.2
0.3
0.4 Time(second)
0.5
0.6
0.7
0.8
Per unit
0.1
Per unit
1.5 1 0.5 0 0
Per unit
Per unit
Voltage(L-Lrms)
System Dynamic Responses at Bus 3 without and with HPFC withcompensation without compensation
0.1
0.2
0.3
0.4 Current (rms)
0.5
0.6
0.7
0.8
1 0.5 0 0
0.1
0.2
0.3
0.4 Real Power
0.5
0.6
0.7
0.8
Per unit
0.5 0 -0.2 0
0.1
0.2
0.3
0.4 ReactivePower
0.5
0.6
0.7
0.8
0.5 0 -0.5
0
0.1
0.2
0.3
0.4 Power Factor
0.5
0.6
0.7
0.8
1 0.5 0 0
0.1
0.2
0.3
0.4 Time(Second)
0.5
0.6
0.7
0.8
Per unit
1.5 1 0.5 0 0
Per unit
Per unit
Voltage(L-Lrms)
System Dynamic Responses at Bus 5 without and with HPFC withcompensation without compensation
0.1
0.2
0.3
0.4 Current (rms)
0.5
0.6
0.7
0.8
Per unit
1.5 1 0.5 0 0
0.1
0.2
0.3
0.4 Real Power
0.5
0.6
0.7
0.8
1 0.5 0 0
0.1
0.2
0.3
0.4 ReactivePower
0.5
0.6
0.7
0.8
1 0.5 0 -0.5 0
0.1
0.2
0.3
0.4 Power Factor
0.5
0.6
0.7
0.8
1 0.5 0 0
0.1
0.2
0.3
0.4 Time(Second)
0.5
0.6
0.7
0.8
Per unit
Per unit
1.5 1 0.5 0 0
Per unit
Voltage(L-Lrms)
The frequency variation at the WECS interface without and with HPFC 62 withcompensation without compensation 61
Frequency (Herz)
60
59
58
57
56
0
0.1
0.2
0.3
0.4 Time(Second)
0.5
0.6
0.7
0.8
Comparison of Voltage THD with Different Compensation Scheme Bus Without With number compensator MPFC 1 28.39% 4.90%
With With DVR HPFC 11.9% 4.99%
2
32.70%
4.60%
12.2% 4.88%
3
35.95%
4.29%
12.6% 4.69%
4
35.75%
3.51%
12.2% 4.51%
5
35.77%
3.32%
13.1% 3.90%
6
36.04%
3.57%
8.57% 4.57%
Comparison of Steady-state Bus Voltage with Different Compensation Scheme Bus Without With number compensator MPFC 1 0.97 1.02
With DVR 1.01
With HPFC 1.05
2
0.95
1.00
1.03
1.05
3
0.94
1.00
1.02
1.05
4
0.89
0.99
1.02
1.05
5
0.86
0.99
1.02
1.06
6
0.83
0.96
1.03
1.05
Conclusions
Three Novel FACTS-based Converter & Control schemes, namely the MPFC, the DVR, and the HPFC, have been Developed and validated for voltage stabilization, power factor correction and power quality improvement in the distribution network with dispersed wind energy integrated.
Recommendation
The Low-Cost MPFC-Scheme 1 is preferred for low to medium size wind energy integration schemes (from 600 to 5000 kW). The DVR-Scheme 2 is good for Strong AC subtransmission and distribution systems with large X/R ratio The HPFC-Scheme 2 Active Power Filter & Capacitor Compensator is most suitable for Larger Wind-Farms with MW-energy penetration level (100 MW or above).
Recommendation
The schemes validated in this research need to be fully tested in the distribution network with real dispersed wind energy systems. This research can be extended to the grid integration of other dispersed renewable energy. Other Artificial Intelligence based control strategies can be investigated in future work.
Conclusions
A Validation Study of a unified sample study system Using the ATLAB/Simulink A dynamic wind speed software model was developed to simulate the varying Random/Stochastic and temporal wind variations in the MATLAB/Simulink Three Novel FACTS based Stabilization Schemes were validated using digital simulations Novel Control strategies using dynamic Multi-Loop Decoupled Controllers were developed & Validated
Publications
[1] A. M. Sharaf and Weihua Wang, ‘A Low-cost Voltage Stabilization and Power Quality Enhancement Scheme for a Small Renewable Wind Energy Scheme’, 2006 IEEE International Symposium on Industrial Electronics, 2006, p.1949-53, Montreal, Canada [2] A. M. Sharaf and Weihua Wang, ‘A Novel Voltage Stabilization Scheme for Standalone Wind Energy Using A Dynamic Sliding Mode Controller’, Proceeding- the 2nd International Green Energy Conference, 2006, Vol. 2, p.205-301, Oshawa, Canada [3] A. M. Sharaf, Weihua Wang, and I. H. Altas, ‘Novel STATCOM Controller for Reactive Power Compensation in Distribution Networks with Dispersed Renewable Wind Energy’, 2007 Canadian Conference on Electrical and Computer Engineering, Vancouver, Canada, April, 2007 [4] A. M. Sharaf, Weihua Wang, and I. H. Altas, ‘A Novel Modulated Power Filter Compensator for Renewable Dispersed Wind Energy Interface’, the International Conference on Clean Electrical Power, 2007, Capri, Italy, May, 2007 [5] A. M. Sharaf, Weihua Wang, and I. H. Altas, ‘A Novel Modulated Power Filter Compensator for Distribution Networks with Distributed Wind Energy’ (Accepted by International Journal of Emerging Electric Power System)
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