Voltage Modulated DPC Strategy of DFIG Using Extended Power Theory under Unbalanced Grid Voltage Conditions

: This paper develops a voltage modulated direct power control (VM-DPC) strategy of a doubly fed induction generator (DFIG) using extended power theory under unbalanced grid voltage conditions. By introducing the modulated voltage of the active and reactive powers and the non-linear VM controller, the proposed VM-DPC strategy enables the generator dynamics to change from the time-varying di ﬀ erential equations into the time-invariant ones. Then, in order to deal with the voltage unbalance, three available power feedbacks, a combination of real active power and extended reactive power, a combination of extended active power and real reactive power, a combination of extended active power and extended reactive power, are developed. Together with a conventional controller (PI + R and feedforwards) and a non-linear VM controller, the power feedbacks are well controlled to track their references with the achievement of the constant active power, the constant reactive power and the balanced stator current. The main advantage of the VM-DPC strategy is the introduction of the modulated voltage and the non-linear VM controller making the generator dynamics time-invariant, which is easy for applying various control methods. Furthermore, the application of extended power can avoid the sequence extractions and the power compensations under unbalanced grid voltage. Finally, the simulation results demonstrate the e ﬀ ectiveness of the developed VM-DPC strategy.


Introduction
In recent years, wind power generation has been rapidly developing among different types of renewable power generation. The doubly fed induction generators (DFIGs) are widely employed in wind farms, due to the attractive merits of variable-speed operation, power decoupling control and lower converter rating [1,2]. However, since wind farms are usually in a rural area with long transmission lines, the voltage unbalance has become a common disturbance [3,4]. For dealing with this disturbance, various solutions have been designed on vector-oriented control (VOC) and direct power control (DPC).
One classical VOC is implemented in the positive and negative synchronous reference frame, where the unbalanced ac signals in the stationary reference frame are transferred to the DC signals in the positive and negative synchronous reference frame [5,6], respectively. Then, dual proportional-integral defined control targets. Then, the detailed implementation of the VM-DPC strategy is described. The simulation results are discussed in Section 4. Finally, Section 5 summarizes the conclusions.

Mathematic Model
In order to analyze the characteristic of DFIG under an unbalanced grid, the mathematical model is established in this section. Furthermore, the extended power theory is also introduced, and the relationship between real power and extended power is revealed in this Section to give a basis for the proposed control strategy in the next section.

Power Analysis
The grid condition in this study is assumed to be unbalanced without zero-sequence voltage and harmonics in a three-phase three-wire system. Accordingly, the voltages and currents contain both positive-and negative-sequence components, which can be expressed in the stationary reference frame as,        u sα = u sα+ + u sα− = U s+ cos ω g t + θ u+ + U s− cos −ω g t + θ u− u sβ = u sβ+ + u gβ− = U s+ sin ω g t + θ u+ + U s− sin −ω g t + θ u− (1) where u sαβ and i sαβ are the DFIG stator voltages and currents, subscripts +, − refer to the positiveand negative-sequence components, U s+ , U s− and I s+ , I s− are the amplitudes of positive-and negative-sequence voltages and currents, θ u+ , θ u− and θ i+ , θ i− are the initial phase angle of positiveand negative-sequence voltages and currents, ω g is the grid angular frequency, respectively. Based on the instantaneous power theory, the apparent powers of the DFIG stator can be calculated as, S s = 1.5U * sαβ I sαβ = P s − jQ s (3) where S s , P s and Q s are the apparent power, the active power and the reactive power, superscript * denotes the conjugate of the complex phasors, respectively. Then, under unbalanced grid voltage conditions, the classical active and reactive powers, containing both the average part and the oscillating part, are calculated as, where Re and Im refer to the real and imaginary parts of the apparent power, Energies 2020, 13, 6077 4 of 16 Based on the extended power theory, the extended active and reactive powers are calculated based on a lagged 90 • (1/4 fundamental period) voltage. Then, the 90 • lagged αand β-axis voltages are obtained as, where superscript refers to the delay signals by one quarter of the fundamental period.
Accordingly, the extended active and reactive powers are calculated as, where S s_ex , P s_ex and Q s_ex are the extended apparent power, the extended active power and the extended reactive power, respectively. During network unbalance, the extended active and reactive powers also contain both the average part and the oscillating part, which are calculated as, (11) As seen, the oscillating parts of the classical and extended active and reactive powers caused by the positive-sequence voltage and the negative-sequence current are equal to each other, while the oscillating parts of the classical and extended active and reactive powers caused by the negative-sequence voltage and the positive-sequence current are opposite. Meanwhile, since the average active and reactive powers produced by the negative-sequence voltages and currents are relatively small, they can be approximately regarded as null. This means that the average parts of both the classical and extended active/reactive powers are equal to each other. Consequently, based on the previous analysis, the following equation can be obtained as, (12) Energies 2020, 13, 6077 5 of 16

DFIG Model
Accordingly, based on Equations (1) and (7), the differential equations of the αand β-axis voltage, containing both the positive-and negative-sequence components, are obtained as For a complex vector expression, Equation (13) is rewritten as, where U sαβ is the voltage vector and given as, Then, based on Equation (3), the dynamics of the active and reactive powers of a DFIG are obtained as, (16) In order to give a more intuitive representation of DFIG model, the equivalent circuit of DFIG in the stationary frame is shown in Figure 1.

DFIG Model
Accordingly, based on Equations (1) and (7), the differential equations of the α-and β-axis voltage, containing both the positive-and negative-sequence components, are obtained as For a complex vector expression, Equation (13) is rewritten as, (14) where Usαβ is the voltage vector and given as, (15) Then, based on Equation (3), the dynamics of the active and reactive powers of a DFIG are obtained as, In order to give a more intuitive representation of DFIG model, the equivalent circuit of DFIG in the stationary frame is shown in Figure 1. As can be seen in Figure 1, the dynamics of the DFIG voltage and flux linkages are given as, As can be seen in Figure 1, the dynamics of the DFIG voltage and flux linkages are given as, where R s and R r are the stator and rotor resistances, ω r is the rotor angular frequency, L m is the mutual inductance, L ls and L lr are the stator and rotor leakage inductances, L s = L m + L ls and L r = L m + L lr are the stator and rotor self-inductances, respectively. According to Equation (18), the rotor flux linkage and current can be also expressed as, Energies 2020, 13, 6077 6 of 16 (20) where σ = 1 − L m 2 /(L s L r ) is the leakage factor.
Then, submitting Equations (19) and (20) into the dynamics of the DFIG rotor voltage in Equation (17), the dynamics of the DFIG stator current are obtained as, In practice, the actual grid angular frequency would vary around the nominal value in an allowed narrow range, such as ±0.5 Hz [24] and ±1.0 Hz [25]. For a simplified implementation, a nominal angular frequency ω 1 is used instead of the actual one ω g in Equation (21). Meanwhile, the rotor resistance R r and the stator resistance R s is far lower than the rotor and stator inductance, thus, the term R r /L r and R s /L s can be assumed to be null in Equation (21). Based on the analysis, the dynamics of the stator current is simplified as, where ω 1 = 100π rad/s is the nominal grid angular frequency. Then, submitting Equation (22) into Equation (16), the dynamics of the active and reactive powers of a DFIG are rewritten as, For clear statements and calculations, the scalar expression of Equation (23) is given as, It is noted in Equation (24) that the dynamics of the active and reactive powers of a DFIG have the ac voltage-related coefficients, which makes it a non-linear time-varying system. In order to change the time-varying system into the time-invariant one, the modulated voltages of the active and reactive powers are defined as, where u P and u q are the modulated voltages of the active and reactive powers, U sm is the amplitude of the stator voltage and calculated as Due to the introduction of the modulated voltages of the active and reactive powers, the differential equation of the active and reactive powers of a DFIG is simplified as, As seen from Equation (27), the time-varying differential equation of the active and reactive powers of a DFIG is converted into the time-invariant constant coefficient-related one, due to the introduction of the modulated voltage of the active and reactive powers. This merit enables various control methods to be easily applied here. Besides, all the aforementioned calculations are in the Energies 2020, 13, 6077 7 of 16 stationary reference frame, where the need for the PLL is completely avoided in the VM-DPC strategy for a simple implementation.

Control System
Based on the power analysis and the mathematical model of DFIG, the relationship between the power ripple, harmonic currents, and the extended power is built in this section. Then, three different control targets under an unbalanced grid are elaborated. Furthermore, the system implementation of the control strategy is presented to give a more intuitive understanding of the developed VM-DPC strategy.

Control Targets
The voltage unbalance would produce the current unbalance/harmonics, the power pulsations and the torque ripples and then the DFIG operation tends to worsen. Thus, the VM-DPC with unbalanced control is necessitated for the sake of reinforcing the generator performance under unbalanced grid voltage conditions. From the generator operation point of view, three control targets are defined as, Target I: To remove the oscillating active power. Target II: To remove the oscillating reactive power and also the oscillating torque. Target III: To operate with balanced stator currents.
As with Target I, the oscillating parts of the active power are controlled to be zero, thus, the active power is constant with the fact that P s_i2 + P s_u2 = 0. Then, based on Equation (5), the amplitude and phase angle of the negative-sequence current are obtained as, Together with the negative-sequence current as indicated in Equation (28), the oscillating parts of the extended reactive power are calculated as, As seen, the oscillating parts of the extended reactive powers are opposite under such case. In other words, if Target I is active with constant classical active power, the extended reactive power is also controlled to be constant. It means that both the oscillating parts of the classical active power and the extended reactive power can be eliminated at the same time.
Notably, since the power reference has no pulsations, it is required that the power feedbacks are also non-oscillating. Meanwhile, for ensuring the average power delivery, the average parts of the power feedbacks are required to be equal to those of the classical active and reactive powers. Thus, based on the previous analysis, for achieving Target I, the power feedbacks are designed as, If the designed power feedbacks are well controlled to track their references, the oscillating parts of the classical active power and the extended reactive power are eliminated simultaneously under unbalanced grid voltage conditions.
As for Target II, the oscillating reactive power is required to be removed, thus, the reactive power is controlled to be constant with no reactive power pulsations, i.e., Q s_i2 + Q s_u2 = 0. As indicated in [21], the oscillating part of the electromagnetic torque is proportional to that of the reactive power only with the unbalanced voltage. Consequently, with Target II enabled, both the oscillating parts of the reactive power and the electromagnetic torque can be eliminated simultaneously. For achieving the fact that Q s_i2 + Q s_u2 = 0, based on (6), the amplitude and phase angle of the negative-sequence current are obtained as, According to Equation (31), the oscillating part of the extended active power is expressed as, As seen, when Target II is enabled, the constant extended active power is obtained, because the sum of the oscillating parts of the extended active powers is zero. It means that both the constant extended active power and the constant classical reactive power can be simultaneously obtained. As a result, for removing the oscillating reactive powers, the power feedbacks can be set as, Notably, based on Equation (12), the average values of the extended and classical powers are equal to each other. Although the extended active power replaces the classical active power as the power feedback, the average power can be well regulated. If the negative-sequence current is properly injected as required by Equation (31), the oscillating parts of the extended active power and classical reactive power can be controlled to be constant.
For Target III, since the stator current is controlled to be balanced, the negative-sequence current is eliminated. Accordingly, the oscillating parts of the classical active and reactive powers caused by the negative-sequence current and positive-sequence voltage is zero, i.e., P s_i2 = Q s_i2 = 0. However, the oscillating parts caused by the negative-sequence voltage and the positive-sequence current still exist, i.e., P s_u2 0 and Q s_u2 0.
As analyzed previously, the oscillating classical and extended active/reactive powers are always opposite regardless of the negative-sequence current. Then, by adding the classical and extended powers, the constant power feedbacks are obtained. However, the average parts of the sums are twice the constant power references. Thus, for guaranteeing the average power delivery, an additional coefficient (0.5) needs to be inserted and then the power feedbacks are calculated as,

System Implementation
Based on the previous analysis, the power feedback contains both the average part and the oscillating part with twice the grid frequency under unbalanced grid voltage conditions. In other words, for effectively tracking the constant power references with zero steady-state errors, the power controller is required to regulate both DC signals and ac signals at twice the grid frequency. Consequently, the widely-used ac controller, i.e., PI+R controller tuned at twice the grid frequency, is employed in this VM-DPC strategy to regulate the power feedbacks to track their corresponding references.
It is noted that there is an allowed frequency deviation in a narrow range around the nominal frequency [24,25]. In order to reduce the sensitivity of frequency deviations and guarantee the stable operation over frequency deviations around the nominal frequency, in practical applications, a cutoff frequency ω c = 5-20 rad/s is inserted as a damping factor. Thus, the complete expression of the employed power controller is given as, where k p , k i and k r are the proportional, integral and resonant parameters, ω c is the cutoff frequency and set as 10 rad/s, respectively. According to Equation (27), the modulated voltages of the active and reactive powers are obtained by, where v P and v Q are the outputs of the power controllers, where P sref and Q sref are the active and reactive power references, P sfb and Q sfb are the active and reactive power feedbacks given in Equation (30), (33) and (34), respectively. Accordingly, together with the PI+R controller and the feedforwards in Equation (36), the modulated voltages of the active and reactive powers are gotten. For obtaining the rotor voltage from the modulated voltage of the active and reactive powers, based on the generator model, the non-linear VM controller is designed as, As seen, the rotor voltage can be easily obtained with a simple calculation. Then, the rotor voltage is transferred from the stator stationary reference frame to the rotor stationary one with Park Transformation based on the rotor position angle as, where u rα_r and u rβ_r are the required rotor voltages in the rotor stationary reference frame, θ r is the rotor position angle, respectively. Figure 2 gives the block diagram of the developed VM-DPC strategy. Since the delay unit for obtaining the one-quarter-of-fundamental-period delayed stator voltage is not in the scope of this paper, a simple T/4-delay method is employed in the control system, where T = 20 ms is the fundamental period. As seen, the VM-DPC consists of three parts: (1) the power feedback generation that provides the available power feedback for achieving the defined control targets; (2) the power tracking control that guarantees the power feedback to track its reference with the conventional PI+R controller and feedforwards; (3) the VM controller that generates the rotor voltage from the modulated voltage of the active and reactive powers.
In the VM-DPC strategy, the extended active and reactive powers are calculated in Equation (9) based on the delayed voltage and the measured currents. Together with the classical active and reactive powers in Equation (4), three power feedbacks are designed as shown in Equation (30), (33) and (34) for the achievement of the constant active power, the constant reactive power and the balanced stator current under unbalanced grid voltage conditions. Together with the conventional PI+R controller and feedforwards, the power feedbacks are well controlled to track their references with the proper modulated voltages. Then, the non-linear VM controller is employed to obtain the rotor voltage from the modulated voltage. Finally, based on the rotor voltages, the SVM technique is introduced to generate the switching voltage vectors with their respective duration times.
In the VM-DPC strategy, the extended active and reactive powers are calculated in Equation (9) based on the delayed voltage and the measured currents. Together with the classical active and reactive powers in Equation (4), three power feedbacks are designed as shown in Equation (30), (33) and (34) for the achievement of the constant active power, the constant reactive power and the balanced stator current under unbalanced grid voltage conditions. Together with the conventional PI+R controller and feedforwards, the power feedbacks are well controlled to track their references with the proper modulated voltages. Then, the non-linear VM controller is employed to obtain the rotor voltage from the modulated voltage. Finally, based on the rotor voltages, the SVM technique is introduced to generate the switching voltage vectors with their respective duration times.

Delay unit
Power feedbacks Equ. By these means, the generator is adequately controlled to achieve the predefined control targets with enhanced behavior. As seen from Figure 2, all the calculations and implementations are carried out in the stationary reference frame with no PLL. The introduction of the modulated voltage of the active and reactive power and the non-linear VM controller causes the power dynamics to be the time-invariant ones, which enables the easy application of various control methods. Meanwhile, compared to the existing solutions in [19][20][21], the sequence extractions and the power compensations are not essential here, thereby resulting in a simpler implementation.

Simulation Studies
To validate the effectiveness of the proposed VM-DPC strategy, simulation studies were conducted using Matlab/Simulink, and Figure 3 shows the schematic diagram of the simulated system. The generator was rated at 2.0 MW with its parameters given in Table 1. The nominal DClink voltage was fixed at 1100 V. The grid-side converter was used to maintain the constant DC-link voltage and was controlled by a conventional method of PWM rectifiers, which is not included in this paper. During the simulations, a switching frequency of 3.0 kHz was used in the developed VM-DPC strategy. The rotor speed was initially set at 1.2 p.u. (super-synchronous), because the mechanical time constant is much larger than the electromagnetic one. Besides, an additional three-phase programmable voltage source was used to provide the unbalanced grid with a larger voltage unbalance being 10%. In the following tests, four different operating modes were adopted and compared.
(1) Mode I: the classical active and reactive powers in Equation (4) are set as the feedback powers. By these means, the generator is adequately controlled to achieve the predefined control targets with enhanced behavior. As seen from Figure 2, all the calculations and implementations are carried out in the stationary reference frame with no PLL. The introduction of the modulated voltage of the active and reactive power and the non-linear VM controller causes the power dynamics to be the time-invariant ones, which enables the easy application of various control methods. Meanwhile, compared to the existing solutions in [19][20][21], the sequence extractions and the power compensations are not essential here, thereby resulting in a simpler implementation.

Simulation Studies
To validate the effectiveness of the proposed VM-DPC strategy, simulation studies were conducted using Matlab/Simulink, and Figure 3 shows the schematic diagram of the simulated system. The generator was rated at 2.0 MW with its parameters given in Table 1. The nominal DC-link voltage was fixed at 1100 V. The grid-side converter was used to maintain the constant DC-link voltage and was controlled by a conventional method of PWM rectifiers, which is not included in this paper. During the simulations, a switching frequency of 3.0 kHz was used in the developed VM-DPC strategy. The rotor speed was initially set at 1.2 p.u. (super-synchronous), because the mechanical time constant is much larger than the electromagnetic one. Besides, an additional three-phase programmable voltage source was used to provide the unbalanced grid with a larger voltage unbalance being 10%. In the following tests, four different operating modes were adopted and compared.     Figure 4 gives the simulation results of the tested DFIG during active and reactive power steps. Since the positive direction of the stator current is into the generator, the negative active power refers to the power delivered from the generator to the grid. Meanwhile, the negative reactive power refers to the capacitive reactive power. In this test, the stator active and reactive powers were initially set at −0.5 p.u. and 0.0 p.u., respectively. The active power reference was changed to −0.8 p.u. at 0.1 s and then back to −0.5p.u. at 0.5 s. The reactive power reference was changed to −0.2 p.u. at 0.2 s and then back to 0 p.u. at 0.4 s. Since there was no voltage unbalance, both the classical and extended powers were constant with no oscillating parts and they were equal to each other. Thus, in this test, the classical active and reactive powers were set as the power feedbacks with Mode I enabled. As seen, during the active and reactive power steps, the stator active and reactive powers can effectively track their references with zero steady-state errors. The active and reactive powers can also achieve a decoupling regulation. During the power steps, the stator and rotor current remained highly sinusoidal with their total harmonic distortions (THDs) being 2.3% and 2.2%, respectively. Therefore, the VM-DPC strategy can guarantee good tracking during power changes and the decoupling regulation between the active and reactive powers. Figure 5 gives the simulation results during a 10% transient voltage unbalance, where the stator active and reactive powers are set at −1.0 p.u. and 0.0 p.u., respectively. In this test, the developed VM-DPC strategy applied the classical active and reactive powers to be the feedbacks. As seen, in this mode, the stator active and reactive powers are controlled to be constant with no oscillating parts. However, the stator current was highly distorted with obvious third harmonic components of 150 Hz being 9.8%. Since the rotor rotates at 60 Hz in the positive direction, the third stator current introduces 90 Hz rotor harmonic current in the rotor winding, which is around 9.9%. The THDs of the stator and rotor currents were as much as 10.2% and 10.3%, respectively. Meanwhile, the electromagnetic torque oscillated badly and contained an oscillating part equivalent to 19.5%. As seen, the developed VM-   Figure 4 gives the simulation results of the tested DFIG during active and reactive power steps. Since the positive direction of the stator current is into the generator, the negative active power refers to the power delivered from the generator to the grid. Meanwhile, the negative reactive power refers to the capacitive reactive power. In this test, the stator active and reactive powers were initially set at −0.5 p.u. and 0.0 p.u., respectively. The active power reference was changed to −0.8 p.u. at 0.1 s and then back to −0.5p.u. at 0.5 s. The reactive power reference was changed to −0.2 p.u. at 0.2 s and then back to 0 p.u. at 0.4 s. Since there was no voltage unbalance, both the classical and extended powers were constant with no oscillating parts and they were equal to each other. Thus, in this test, the classical active and reactive powers were set as the power feedbacks with Mode I enabled. As seen, during the active and reactive power steps, the stator active and reactive powers can effectively track their references with zero steady-state errors. The active and reactive powers can also achieve a decoupling regulation. During the power steps, the stator and rotor current remained highly sinusoidal with their total harmonic distortions (THDs) being 2.3% and 2.2%, respectively. Therefore, the VM-DPC strategy can guarantee good tracking during power changes and the decoupling regulation between the active and reactive powers. Figure 5 gives the simulation results during a 10% transient voltage unbalance, where the stator active and reactive powers are set at −1.0 p.u. and 0.0 p.u., respectively. In this test, the developed VM-DPC strategy applied the classical active and reactive powers to be the feedbacks. As seen, in this mode, the stator active and reactive powers are controlled to be constant with no oscillating parts. However, the stator current was highly distorted with obvious third harmonic components of 150 Hz being 9.8%. Since the rotor rotates at 60 Hz in the positive direction, the third stator current introduces 90 Hz rotor harmonic current in the rotor winding, which is around 9.9%. The THDs of the stator and rotor currents were as much as 10.2% and 10.3%, respectively. Meanwhile, the electromagnetic torque oscillated badly and contained an oscillating part equivalent to 19.5%. As seen, the developed VM-DPC with the classical powers of the power feedbacks cannot guarantee satisfactory behaviors under unbalanced grid voltage conditions.        Figure 6 gives the simulation results during a 10% steady-state voltage unbalance, where the following four different operating modes are compared. As seen from Figure 6, under Mode I, the stator active and reactive powers are controlled to be non-oscillating, but the stator currents are highly distorted, as analyzed previously. When the feedback powers are switched to (30) under Mode II at 0.2 s, Energies 2020, 13, 6077 13 of 16 the harmonic components of the stator currents are immediately eliminated. The stator currents are highly sinusoidal with the THD being 1.8%. The current unbalance factor (CUF) of the stator current, referring to the radio of the amplitude of the negative-sequence current to that of the positive-sequence current, is around 10.8%. The stator active power remains constant, while the reactive power contains an oscillating part equal to 19.8%. Consequently, Target I of removing the oscillating active power was achieved. At 0.4 s, the control system was switched to Mode III with Target II enabled. Under such a case, the oscillating part of the reactive power is removed as expected. Notably, since the oscillating part of the electromagnetic torque is proportional to that of the stator reactive power only with the positive-and negative-sequence current injection [21], under Mode III, the oscillating parts of the electromagnetic torque can also be eliminated. The oscillating part of the stator active power was increased to around 19.2%. Under this mode, the CUF of the stator current was 9.1%, while its THD was about 1.8%. When Mode IV was enabled at 0.6 s, the CUF of the stator current immediately decreased to 0.1%, where Target III of guaranteeing the balanced stator current was achieved. The THDs of the stator and rotor currents were 1.7% and 2.1%, respectively. The active and reactive powers contained the oscillating parts of 9.3% and 9.6%, respectively. Besides, the amplitude of the torque ripples was around 11.4%. Thus, by the means of applying different power feedbacks, the predefined control targets were achieved with enhanced behaviors, which can provide the enhanced behaviors under unbalanced grid voltage conditions. Notably, since the oscillating part of the electromagnetic torque is proportional to that of the stator reactive power only with the positive-and negative-sequence current injection [21], under Mode III, the oscillating parts of the electromagnetic torque can also be eliminated. The oscillating part of the stator active power was increased to around 19.2%. Under this mode, the CUF of the stator current was 9.1%, while its THD was about 1.8%. When Mode IV was enabled at 0.6 s, the CUF of the stator current immediately decreased to 0.1%, where Target III of guaranteeing the balanced stator current was achieved. The THDs of the stator and rotor currents were 1.7% and 2.1%, respectively. The active and reactive powers contained the oscillating parts of 9.3% and 9.6%, respectively. Besides, the amplitude of the torque ripples was around 11.4%. Thus, by the means of applying different power feedbacks, the predefined control targets were achieved with enhanced behaviors, which can provide the enhanced behaviors under unbalanced grid voltage conditions. For clear comparisons, Table 2 summarizes the THD of the stator current, the CUF of the stator current, and the oscillating amplitude of the active power, the reactive power, and the electromagnetic torque among different operating modes. It is evident that the developed VM-DPC, with the available power feedbacks, can greatly enhance and improve the generator performance under unbalanced grid voltage conditions. For clear comparisons, Table 2 summarizes the THD of the stator current, the CUF of the stator current, and the oscillating amplitude of the active power, the reactive power, and the electromagnetic torque among different operating modes. It is evident that the developed VM-DPC, with the available power feedbacks, can greatly enhance and improve the generator performance under unbalanced grid voltage conditions.  Figure 7 gives further simulation results with Mode II enabled during a 10% transient voltage unbalance. In this test, the generator was controlled to remove the oscillating part of the stator active power. The active and reactive powers of the DFIG were fixed at −1.0 p.u. and 0.0 p.u, which is the same as those of Figures 5 and 6. As seen, at 0.2 s, when a 10% transient voltage unbalance arises, the feedback powers can rapidly track the commanded values in around 20 ms. Meanwhile, the oscillating parts of the stator active power are eliminated with highly sinusoidal current provisions. Consequently, the developed VM-DPC strategy can provide fast dynamic responses during a transient unbalance.   Figure 7 gives further simulation results with Mode II enabled during a 10% transient voltage unbalance. In this test, the generator was controlled to remove the oscillating part of the stator active power. The active and reactive powers of the DFIG were fixed at −1.0 p.u. and 0.0 p.u, which is the same as those of Figures 5 and 6. As seen, at 0.2 s, when a 10% transient voltage unbalance arises, the feedback powers can rapidly track the commanded values in around 20 ms. Meanwhile, the oscillating parts of the stator active power are eliminated with highly sinusoidal current provisions. Consequently, the developed VM-DPC strategy can provide fast dynamic responses during a transient unbalance. As a result, based on the aforementioned simulation results, it is confirmed that the proposed VM-DPC with different power feedbacks can achieve the predefined control targets and provide both satisfactory steady-state performance and suitable dynamic behaviors under unbalanced grid voltage conditions. As a result, based on the aforementioned simulation results, it is confirmed that the proposed VM-DPC with different power feedbacks can achieve the predefined control targets and provide