On Extending the Energy Balancing Limit of Multilevel Cascaded H-Bridge Converters for Largescale Photovoltaic Farms © 2013 IEEE Australasian Universities Power Engineering Conference (AUPEC), 29 Sept. – 3 Oct 2013, Hobart, Tasmania, On Extending the Energy Balancing Limit of Multilevel Cascaded H-Bridge Converters for Large-scale Photovoltaic Farms Yifan Yu Georgios Konstantinou Branislav Hredzak Vassilios G. Agelidis This material is posted here with permission of the IEEE. Such permission of the IEEE does not in any way imply IEEE endorsement of any of UNSW’s products or services. Internal or personal use of this material is permitted. However, permission to reprint/republish this material for advertising or promotional purposes or for creating new collective works for resale or redistribution must be obtained from the IEEE by writing to: pubs-permissions@ieee.org By choosing to view this document, you agree to all provisions of the copyright laws protecting it. Australasian Universities Power Engineering Conference, AUPEC 2013, Hobart, TAS, Australia, 29 September – 3 October 2013 1 On Extending the Energy Balancing Limit of Multilevel Cascaded H-Bridge Converters for Large-scale Photovoltaic Farms Yifan Yu Georgios Konstantinou Branislav Hredzak and Vassilios G. Agelidis Australian Energy Research Institute and School of Electrical Engineering and Telecommunications, The University of New South Wales, Sydney, NSW, 2052, Australia email: yifan.yu@student.unsw.edu.au g.konstantinou@unsw.edu.au b.hredzak@unsw.edu.au vassilios.agelidis@unsw.edu.au Abstract—When multilevel cascaded H-bridge converters are used to interface large-scale photovoltaic farms to the electricity grid, the stochastic variation of irradiance and other factors lead to unequal power generation among the phases, affecting the three-phase balanced system. Injections of fundamental frequency zero sequence to modulation references can deal with this problem. This paper proposes the third harmonic injection to extend the balancing limit of three-phase unbalanced power generation. The concepts and definitions of converter energy balancing limit are presented to assess its energy balancing capability. Numerical comparison results reveal that the proposed third harmonic injection method has greater energy balancing capability. Selected simulation results are provided to verify the performance of the proposed method. Index Terms—AC-DC power converters; Photovoltaic systems Lf Phase A ia H-Bridge A1 PV String Isolated DC-DC Converter Idc ib ic H-Bridge Ipv Vc Vpv H-Bridge A2 I. I NTRODUCTION In the next few decades, photovoltaic (PV) power generation is expected to gain much higher energy market share, due to the ever-decreasing costs of PV panels and their associated power conditioners [1], [2]. The majority of the contemporary commercially available PV converters are designed for small or medium-scale residential PV generators up to several hundred kilo-watts [3], [4]. Large-scale mega-watt (MW) PV farms, nevertheless, are more economically attractive due to their reduced cost per watt, higher conversion efficiency, reduced intermittency and ultimately to their control as a conventional power station. The PV industry is not alone in the pursuit of high power converters. The electric motor drives industry also suffered in the 1980s and then conquered this barrier through the widespread application of multilevel converters [5]–[7]. By synthesizing voltage waveforms with multiple levels, this technology allows converters to withstand higher voltage with low voltage rating devices. Furthermore, the multilevel waveform decreases the average switching frequency of the devices, and, hence, the converter switching losses. Duplicating the technical success of multilevel converters in the emerging renewable energy industry has been an interesting topic for researchers worldwide [8]–[12]. However, several barriers have to be conquered on its way to the ultimate industrial success, H-Bridge A3 Phase B Phase C n Fig. 1. Three-phase seven-level cascaded H-bridge converter. due to some unique requirements of the PV generators, such as Maximum Power Point Tracking (MPPT) and intermittency. Compared to other multilevel converter topologies such as the Neutral Point Clamped (NPC), Flying Capacitor (FC) and Modular Multilevel Converter (MMC), the Cascaded H-Bridge (CHB) has been accepted as the most suitable candidate for the next generation PV farm converters [13], due to multiple separate low voltage DC links. These are considered a major drawback for industrial drives but are now a perfect match to PV systems. A three-phase seven-level CHB converter consists of nine H-bridges, each fed by multiple strings of PV panels via their own isolated DC-DC converters as shown in Fig. 1. In this way, the capacitor voltages are regulated by the grid via Hbridges, while each DC-DC converter does independent MPPT to maximize the captured PV power. The merits of separate DC links and the proven multi-string configuration are fully deployed to achieve better efficiency and higher power ratings. One problem that needs to be addressed with CHB is the Australasian Universities Power Engineering Conference, AUPEC 2013, Hobart, TAS, Australia, 29 September – 3 October 2013 unbalanced power generation by the PV panels connected to each H-Bridge, due to unequal radiation, temperature and panel parameters. It should be noted that balanced three-phase grid injection currents are required by the grid code [14]. As a consequence, control methods need to be modified in order to deliver balanced three-phase currents to the grid, even under unequal power generation from each phase. In [12], a continuous time domain energy balancing control algorithm was presented to solve inter-bridge unbalance for the singlephase seven-level CHB converter. However, due to the absence of interfacing DC-DC converters, the capacitor voltage of the individual H-bridge has to be variable to achieve local MPPT, resulting in undesirable harmonic spectrum. Moreover, the lack of galvanic isolation limits the operational DC voltage to 1000V due to safety considerations, thus making it less attractive for large-scale applications. A fundamental frequency zero sequence, which was firstly presented for capacitor voltage balancing of CHB based Static Synchronous Compensator (STATCOM) [15], was later deployed to redistribute the generated power among the three phases of the CHB PV converter [16]. Another zero sequence, the min-max sequence [17], was also proposed for the same purpose, which features very simple calculation but results in sub-optimal energy balancing control. Although it has been confirmed that these energy balancing control methods can achieve rebalancing with an extra zero sequence injection for some demonstrated cases, the energy balancing limit, i.e. the limit to which three-phase balanced currents are maintained despite of the different amount of power generated by each PV module, has not been addressed. The objective of this paper is firstly to investigate analytically the energy balancing limit of existing methods and secondly to report a more advanced zero sequence injection method aiming to increase such limit. The rest of the paper is organized as follows. In Section II, the fundamental frequency zero sequence injection to redistribute the power among the phases is calculated based on the phasor diagram. The fundamental concepts and definitions of energy balancing limit are presented in Section III. A third harmonic injection method that maximizes the converter energy balancing limit is proposed in Section IV, followed by the energy balancing limit comparison between the existing and proposed methods in Section V. Section VI provides computer simulations based on MATLAB/PLECS to verify the performance of the proposed approach. Finally, the conclusions are summarized in Section VII. II. P OWER R EDISTRIBUTION BY F UNDAMENTAL F REQUENCY Z ERO S EQUENCE I NJECTION In the balanced operation of a CHB converter, equal amount of power is generated by each phase and the respective threephase voltages and currents are displaced by 120 degrees having the same amplitude, as demonstrated in Fig. 2a. Vga , Vgb , Vgc and Iga , Igb , Igc represent the grid voltage and current vectors, respectively, and Vca , Vcb , Vcc are the jωLfIgc C Vgc Sector II Vcc Sector III 2 Sector I Igc Vca jωLfIga A α n Iga Vga Igb Sector VI Sector IV Vcb Vgb B jωLfIgb Sector V (a) C Vgc Vcc Sector II Sector I Sector III Igc Vca n' V0 θ ω Iga Vga A Igb Sector IV Vgb B Vcb Sector VI Sector V (b) Fig. 2. Phasor diagram of (a) balanced operation (b) unbalanced operation with fundamental frequency zero sequence injection. fundamental frequency vectors of the converter output phase voltage. When the power generated by the PV modules connected to different phases is unequal, due to partial shading or other reasons, the situation becomes complicated. The three-phase grid currents will be asymmetrical if the converter phase legs are still modulated with the same reference waveform. Injection of a fundamental frequency zero sequence is one way to solve this problem [16]. As depicted in Fig. 2b, the injected zero sequence does not alter the line-to-line voltages seen by the grid, which makes it possible to deliver threephase balanced currents to the grid even under unbalanced power generation. Additionally, it generates different amount of power with the grid current of each phase, but zero net power when considering the three phases as a whole. Therefore, the zero sequence redistributes the power among three Australasian Universities Power Engineering Conference, AUPEC 2013, Hobart, TAS, Australia, 29 September – 3 October 2013 phases as required to provide three-phase balanced currents. With the introduction of this fundamental frequency zero sequence, the three-phase voltage references can be rewritten as follows: √ √ Vca = 2Vcp cos(ωt + α) + 2V0 cos(ωt + θ), (1) Vcb = Vcc = √ 2Vcp cos(ωt + α − 120◦ ) + √ ◦ 2Vcp cos(ωt + α + 120 ) + √ P(A,B,C) , Ppeak /3 (4) where Ppeak refers to the rated peak power of all PV modules connected to the converter. The location of zero sequence based on the three-phase power generation is summarized in Table I. The case of zero sequence vector located in Sector I is analyzed in detail before a more generalized relationship is developed. According to the phasor diagram depicted in Fig. 2b, the power redistribution caused by the injected zero sequence for each phase can be expressed as: ! λA + λB + λC Ppeak V0 Ig cos θ = λA − , (5) 3 3 ! λA + λB + λC Ppeak V0 Ig cos(θ + 2π/3) = λB − , (6) 3 3 ! λA + λB + λC Ppeak V0 Ig cos(θ − 2π/3) = λC − , (7) 3 3 √ Three-phase Power Ratio 2V0 cos(ωt + θ), (3) where Vcp and α are the rms value and phase angle of the positive sequence of Phase A, and V0 and θ represent the rms value and phase angle of the injected zero sequence vector. As illustrated in the phasor diagram of Fig. 2b, the addition of the fundamental frequency zero sequence vector only shifts the fictitious neutral point with the line-to-line voltage seen from the grid unchanged. The location of the zero sequence generation depends on the actual power generation of each phase and can be located in and of the six sectors (I-VI). Here, λA , λB , λC are defined as the power generation ratios, which are computed by comparing the actual power of each phase to its rated peak power: λ(A,B,C) = TABLE I L OCATION OF Z ERO S EQUENCE V ECTOR BASED ON T HREE - PHASE P OWER G ENERATION 2V0 cos(ωt + θ), (2) √ λA + λB + λC 3Vg Ig = Ppeak , (8) 3 where Vg and Ig stand for the rms value of grid voltage and current. The amplitude of the zero sequence vector and its phase displacement can then be calculated as: √ 6∆ V0 = Vg , (9) 3(λA + λB + λC ) ! √ 6(λC − λB ) θ = arcsin , (10) 2∆ 3 Sector λB < λ C < λ A I λB < λ A < λ C II λA < λ B < λ C III λA < λ C < λ B IV λC < λ A < λ B V λC < λ B < λ A VI where:q 2 2 2 ∆ = (λA − λB ) + (λB − λC ) + (λA − λC ) . (11) After performing similar analysis in other sectors, it is found that the representations of the amplitude of zero sequence vector are identical, while the representations of phase displacement differ in each sector and can be summarized as: • for Sectors I and VI: ! √ 6 (λB − λA ) −1 , (12) θ = sin 2∆ • • for Sectors II and III: 2π θ= + sin−1 3 √ for Sectors IV and V: 4π + sin−1 θ= 3 √ ! 6 (λC − λB ) , 2∆ ! 6 (λA − λC ) . 2∆ (13) (14) Note that, for the case when λA = λB = λC , it is impossible to obtain the amplitude of the injected zero sequence based on (9) since both the numerator and denominator become zero. However, it is meaningless to analyze this situation since no actual power is generated. Furthermore, for λA = λB = λC > 0, all the numerators and denominators in (12)–(14) also become zero, but this case represents a balanced power generation and hence no zero sequence injection is needed. III. C ONCEPTS OF C ONVERTER E NERGY BALANCING L IMIT In order to redistribute the power among the three phases, the actual phase voltages should be the combination of the positive sequence and fundamental frequency zero sequence (Fig. 2). Therefore, to keep the three-phase balanced currents injected into the grid with the converter modulated in the linear region, these phase voltages should not exceed three times the designed capacitor voltage for a seven-level CHB. Hence, the energy balancing limit with fundamental frequency zero sequence injection can be obtained by confining the maximum phase voltage to three times the capacitor voltage Vc : √ q 2 Vx2 + Vy2 ≤ 3Vc , (15) Australasian Universities Power Engineering Conference, AUPEC 2013, Hobart, TAS, Australia, 29 September – 3 October 2013 where: • for 0 ≤ θ ≤ π/3 + α or 5π/3 + α ≤ θ ≤ 2π: • • 4 TABLE II PARAMETERS OF THE T HREE - PHASE S EVEN - LEVEL CHB C ONVERTER Vx = V0 cos θ + Vcp cos α, (16) Vy = V0 sin θ + Vcp sin α, (17) Peak Power of Single Panel Values PV Parameters (W) 64.98 Module Number in a Single String 311 String Number in Parallel 55 for π/3 + α ≤ θ ≤ π + α: Vx = V0 cos θ + Vcp cos (α + 2π/3) , (18) Vy = V0 sin θ + Vcp sin (α + 2π/3) , (19) for π + α ≤ θ ≤ 5π/3 + α: Converter Parameters Values Grid Voltage, Vg (kV) 6.6 Rated Power, Ppeak (MW) 10 Capacitor Voltage, Vc (V) 2500 IGBT Voltage Rating (V) 3300 1500 Vx = V0 cos θ + Vcp cos (α + 4π/3) , (20) IGBT Current Rating (A) Vy = V0 sin θ + Vcp sin (α + 4π/3) . (21) Filtering Inductor, Lf (mH) 5 Carrier Frequency, f (Hz) 1200 In real applications, all three-phase generation ratios are variable according to environmental factors and module parameters. Therefore, all points (λA , λB , λC ) satisfying the above requirements define a space where the zero sequence injection can rebalance the currents injected to the grid. This space is defined as the Energy Balanceable Space (EBS). Operation points lying outside this space are impossible to maintain three-phase balanced grid currents without forcing the converter into the over-modulation region. This EBS space can be numerically obtained by calculating two surfaces, an upper surface formed by the maximum balanceable λC max for each given (λA , λB ) and a lower one formed by the minimum balanceable λC min . Hence, the EBS of the converter of Table II is plotted in Fig. 3. Field experience indicates that, in most cases, the maximum deviation of the power generation ratio in one phase from the three-phase average value usually falls within 20%. That is to say scenarios with extremely unbalanced power generation are quite rare. However, extending the achievable EBS is still of great significance, since, for the same balanceable space, it can facilitate operation with lower capacitor voltage and thus reduction of losses in the DC voltage boosting stage. IV. E XTENDING THE E NERGY BALANCING L IMIT BY T HIRD H ARMONIC Z ERO S EQUENCE I NJECTION Third Harmonic Injection (THI) has been used to improve the DC voltage utilization of three-phase voltage source inverter. For balanced operation, the conclusion has been drawn that the injection level of one sixth of the fundamental component achieves highest AC output without being into the over-modulation region. In this section, a third harmonic injection for unbalanced three-phase system is proposed to extend the range of achievable AC output voltage and, hence, the converters EBS. To provide an indicator of the energy balancing limit of the converter, the Balance Factor (BF) is defined as the volume of the EBS: ZZ BF = (λC max − λC min ) dλA dλB . (22) 0≤λA ,λB ≤1 Fig. 3. Energy Balanceable Space with fundamental frequency zero sequence injection. Having noted that each modulation reference derived in Section II consists of fundamental frequency positive sequence and fundamental frequency zero sequence, a straightforward way to find the optimum injection level is by combining the optimum injection for the positive sequence with that for the zero sequence together. Consequently, the modulation reference for Phase A under this Double 1/6 Third Harmonic Injection (DTHI) method can be rewritten in the following form: √ √ 2Vcp Vca = 2Vcp cos (ωt + α) − cos (3ωt + 3α) | {z } | 6 {z } I √ II √ 2V0 + 2V0 cos (ωt + θ) − cos (3ωt + 3θ), (23) | {z } | 6 {z } III IV where Term I stands for the positive sequence and II for its 1/6 third harmonic injection, while Term III and IV represent the fundamental frequency zero sequence and its 1/6 third harmonic injection. The EBS is then obtained using a similar method to the previous section: max (| vca |max , | vcb |max , | vcc |max ) ≤ 3Vc . (24) Australasian Universities Power Engineering Conference, AUPEC 2013, Hobart, TAS, Australia, 29 September – 3 October 2013 5 Current(kA) 2 ia ib ic 0 −2 0 0.01 0.02 0.03 Time(s) 0.04 0.05 0.06 Voltage(kV) (a) 10 Vca Vcb Vcc 0 −10 0 0.01 0.02 Fig. 4. Energy Balanceable Space with DTHI. 0.03 Time(s) 0.04 0.05 0.06 (b) Fig. 6. Balanced operation of CHB converter (a) three-phase grid currents (b) three-phase seven-level converter output voltages. 0.5 0.4 Current(kA) 2 BF 0.3 0.2 Fundamental frequency Zero Sequence Injection 0.1 ia ib ic 0 −2 0 0.01 0.02 DTHI 0.03 Time(s) 0.04 0.05 0.06 0 2 4 6 Peak Power (MW) 8 10 Fig. 5. Balance Factor comparison. The EBS with DTHI for the same converter parameters as in Table II is plotted in Fig. 4. V. BALANCE FACTOR C OMPARISON This section compares the BFs of the two aforementioned methods numerically. The comparison is shown in Fig. 5 for the actual peak operating power increasing from 2MW to 10MW, for the 10MW converter designed in Table II. It can be observed that, for the same method, the BF declines with the increasing operating power, which means that if required it is possible to extend the energy balancing limit by oversizing the converter. Furthermore, the DTHI method increases the BF on average by 55%, as compared with the fundamental frequency zero sequence injection. VI. S IMULATION V ERIFICATION The two methods of zero sequence injection are investigated through simulations of the converter with the specifications given in Table II. Under balanced operation the converter injects symmetrical currents (Fig. 6a) and generates symmetrical voltages (Fig. 6b). Then the solar radiation decreases from 1 kW/m2 to 600 kW/m2 on the PV modules of Phase A, corresponding to 58.62% of the rated value for the module adopted in this paper, while the other two phases are not affected. If no additional Voltage(kV) (a) 0 10 Vca Vcb Vcc 0 −10 0 0.01 0.02 0.03 Time(s) 0.04 0.05 0.06 (b) Fig. 7. Unbalanced operation of CHB converter without energy balancing control (a) three-phase grid currents (b) three-phase seven-level converter output voltages (λA = 0.5862, λB = λC =1). balancing control methods are applied, the three-phase grid currents will be unbalanced, as depicted in Fig. 7a. Therefore, fundamental frequency zero sequence needs to be injected according to (9) (10). It can be observed in Fig. 8 that, by distorting the converter output phase voltages, the zero sequence can successfully redistribute the power among the three phases as required and maintain the three-phase balanced grid currents. However, due to the zero sequence injection, the level of each converter output phase voltage might be different, which, as a consequence, makes it complicated to analyze the harmonic spectra. Similarly, the simulation results employing the presented DTHI are provided in Fig. 9. It can be observed that by using DTHI the maximum modulation index becomes lower, which indicates a larger EBS compared to the fundamental frequency zero sequence injection. VII. C ONCLUSION The multilevel cascaded H-bridge converters face the problem of unbalanced power generation as a result of unequal radiation, temperature and panel parameters, for large-scale Australasian Universities Power Engineering Conference, AUPEC 2013, Hobart, TAS, Australia, 29 September – 3 October 2013 2 ia ib ic 0 −2 0 Current(kA) Current(kA) 2 0.01 0.02 0.03 Time(s) 0.04 0.05 −2 0 0.06 ia ib ic 0 0.01 0.02 10 Vca Vcb Vcc 0 0.01 0.02 0.03 Time(s) 0.04 0.05 0.06 0.03 Time(s) 0.06 Vca Vcb Vcc 0 −10 0 0.01 0.02 0.03 Time(s) 0.04 0.04 0.05 0.06 1 Reference Reference 0 0.02 0.05 0.05 0.06 (b) Ref A Ref B Ref C Zero seq. 0.01 0.04 10 (b) 1 −1 0 0.03 Time(s) (a) Voltage(kV) Voltage(kV) (a) −10 0 6 Ref A Ref B Ref C Zero seq. 0 −1 0 0.01 0.02 0.03 Time(s) 0.04 0.05 0.06 (c) (c) Fig. 8. Unbalanced operation of CHB converter with fundamental frequency zero sequence injection (a) three-phase grid currents (b) threephase seven-level converter output voltages (c) three-phase voltage references (λA = 0.5862, λB = λC =1). Fig. 9. Unbalanced operation of CHB converter with DTHI (a) three-phase grid currents (b) three-phase seven-level converter output voltages (c) threephase voltage references (λA = 0.5862, λB = λC = 1). photovoltaic farm applications. A third harmonic injection method for unbalanced three-phase systems, named Double 1/6 Third Harmonic Injection, has been presented in this paper to extend the converters energy balancing limit. Consequently, the three-phase balanced currents can be injected into the grid for more unbalanced power generation. The effectiveness of the presented method in extending the Energy Balanceable Space and Balance Factor is verified through computer simulation results. R EFERENCES [1] F. Blaabjerg, Z. Chen, and S. B. Kjaer, “Power electronics as efficient interface in despersed power generation systems,” IEEE Trans. Power Electron., vol. 19, no. 5, pp. 1184-1194, Sept. 2004. [2] J. M. Carrasco, L. G. Franquelo, J. T. Bialasiewicz, E. Galvan, R. C. P. Guisado, M. Prats, J. I. Leon, and N. M. Alfonso, Power-electronic systems for the grid integration of renewable energy sources: a survey, IEEE Trans. Ind. Electron., vol. 53, no. 4, pp. 1002-1016, Jun. 2006. [3] Y. Huang, M. Shen, F. Z. Peng, and J. Wang, “Z-Source converter for residential photovoltaic systems,” IEEE Trans. Power Electron., vol. 21, no. 6, pp. 1776-1782, Nov. 2006. [4] Y. Yu, Q. Zhang, X. Liu, and S. Cui, “DC-link voltage ripple analysis and impedance network design of single-phase Z-Source converter,” in the Proc. of EPE 2011, pp. 1-10. [5] J. Rodriguez, J. Lai, and F. Z. Peng, “Multilevel converters: a survey of topologies, controls, and applications,” IEEE Trans. Ind. Electron., vol. 49, no. 4, pp. 724-738, Aug. 2002. [6] J. Rodriguez, L. G. Franquelo, S. Kouro, J. I. Leon, R. C. Portillo, M. A. M. Prats, and M. A. Perez, Multilevel converters: an enabling technology for high-power applications, Proceedings of the IEEE, vol. 97, no. 11, pp. 1786-1817, Nov. 2009. [7] J. Rodriguez, S. Bernet, B. Wu, J. Pontt, and S. Kouro, “Multilevel voltage-source-converter topologies for industrial medium-voltage drives, IEEE Trans. Ind. Electron., vol. 54, no. 6, pp. 2930-2945, Dec. 2007. [8] M. C. Cavalcanti, A. M. Farias, K. C. Oliveira, F. A. S. Neves, and J. L. Afonso, “Eliminating leakage currents in neutral point clamped converters for photovoltaic systems,” IEEE Trans. Ind. Electron., vol. 59, no. 1, pp. 435-443, Jan. 2012. [9] S. Kouro, K. Asfaw, R. Goldman, R. Snow, B. Wu, and J. Rodriguez, “NPC multilevel multistring topology for large scale grid connected photovoltaic systems,” in the Proc. of IEEE PEDG 2010, pp. 400-405. [10] W. Zhao, H. Choi, G. Konstantinou, M. Ciobotaru, and V. G. Agelidis, “Cascaded H-bridge multilevel converter for large-scale PV gridintegration with isolated DC-DC stage,” in the Proc. of IEEE PEDG 2012, pp. 849-856. [11] J. Chavarria, D. Biel, F. Guinjoan, C. Meza, and J. J. Negroni, “Energybalance control of PV cascaded multilevel grid-connected inverters under level-shifted and phase-shifted PWMs,” IEEE Trans. Ind. Electron., vol. 60, no. 1, pp. 98-111, Jan. 2013. [12] E. Villanueva, P. Correa, J. Rodriguez, and M. Pacas, “Control of a single-phase cascaded H-bridge multilevel converter for grid-connected photovoltaic systems,” IEEE Trans. Ind. Electron., vol. 56, no. 11, pp. 4399-4406, Nov. 2009. [13] X. Yaosuo, K. C. Divya, G. Griepentrog, M. Liviu, S. Suresh, and M. Manjrekar, “Towards next generation photovoltaic converters,” in the Proc. of IEEE ECCE 2011, pp. 2467-2474. [14] “IEEE Standard for Interconnecting Distributed Resources With Electric Power Systems,” IEEE Std 1547-2003, 2003. [15] T. J. Summers, R. E. Betz, and G. Mirzaeva, “Phase leg voltage balancing of a cascaded H-bridge converter based STATCOM using zero sequence injection,” in the Proc. of EPE 2009, 2008, pp. 1-10. [16] C. D. Townsend, T. J. Summers, and R. E. Betz, “Control and modulation scheme for a cascaded H-bridge multi-level converter in large scale photovoltaic systems,” in the Proc. of IEEE ECCE 2012, pp. 3707-3714. [17] S. Rivera, B. Wu, S. Kouro, W. Hong, and Z. Donglai, “Cascaded Hbridge multilevel converter topology and three-phase balance control for large scale photovoltaic systems,” in the Proc. of IEEE PEDG 2012, pp. 690-697.