replacing the grid interface transformer in wind energy … · 2017. 9. 26. · ver the last...

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This article has been accepted for publication in a future issue of this journal, but has not been fully edited. Content may change prior to final publication. Citation information: DOI 10.1109/TPWRS.2016.2614692, IEEETransactions on Power Systems

1

Abstract— In wind energy conversion systems, the

fundamental frequency step-up transformer acts as a key

interface between the wind turbine and the grid. Recently, there

have been efforts to replace this transformer by an advanced

power electronics based solid-state transformer (SST). This

paper proposes a configuration that combines the doubly fed

induction generator (DFIG) based wind turbine and SST

operation. The main objective of the proposed configuration is to

interface the turbine with the grid while providing enhanced

operation and performance. In this work, SST controls the active

power to/from the rotor side converter (RSC), thus, eliminating

the grid side converter (GSC). The proposed system meets the

recent grid code requirements of wind turbine operation under

fault conditions. Additionally, it has the ability to supply reactive

power to the grid when the wind generation is not up to its rated

value. A detailed simulation study is conducted to validate the

performance of the proposed configuration.

Index Terms— Solid-state transformer, doubly fed induction

generator, power electronic transformer, fault ride through.

I. INTRODUCTION

ver the last decade, the penetration of renewable energy

sources has been increasing steadily in the power system.

In particular, wind energy installations have grown rapidly

with global installed capacity increasing from 47.6 GW in

2004 to 369.6 GW in 2014 [1]. Amongst the many

technologies that exist for wind energy conversion systems

(WECS), doubly fed induction generators (DFIG) have been

prevalent due to variable speed operation, high power density

and lower cost [2] [3].

DFIG based WECS consist of an induction generator whose

stator is directly connected to the grid while its rotor is

connected via back to back converters known as the rotor side

converter (RSC) and grid side converter (GSC), respectively

[3]. The generator is normally operated at a range of 500 V-

700 V and is connected to the transmission network (11-33

kV) through a transformer that acts as an integral part of the

WECS to interface the wind turbine and the grid.

Imran Syed and Vinod Khadkikar are with the Electrical Power Engineering

Program, Masdar Institute, Abu Dhabi, United Arab Emirates (emails:

[email protected], [email protected]). ogy.-mail: [email protected], [email protected]).

This research work was supported by Masdar Institute of Science and

Technology

ACAC

DCAC

Var

Compensator

SST

(Renewables

integration and

Var

Compensation)

Current

System

SST integrated

system

Wind

PV

PV

Wind

Fig. 1 Expected SST integrated grid.

Recently, there has been much interest in developing an

alternative to the traditional fundamental frequency

transformer using solid-state devices.

The solid-state transformer (SST) achieves voltage

conversion through a series of power electronics devices while

offering multiple advantages, such as, smaller size, improved

power quality and fault tolerant features [4]-[11].

Fig. 1 shows a power distribution system based on SST as

envisioned in [4]. Proposed in 1980 [5], advances in solid-

state technology have made SST more viable today leading to

increased research in its feasibility and physical realization.

A promising 10 kVA prototype has been developed and

presented in [6]. Further, the use of high voltage silicon

carbide (SiC) power devices for SST has been explored and

presented in [7]-[8]. As seen in Fig. 1, SST can act as an

interface between the grid and generation sources. However,

research showing detailed configurations for integrating

existing technologies is limited. In [9], work is reported on

using SST in a microgrid based on renewable sources. In [10],

SST is used to interface a wind park based on squirrel cage

induction generator (SCIG) with the grid. However, a detailed

analysis on fault ride through requirement and reactive power

support has not been conducted in [10].

In this paper, a new configuration is proposed that combines

the operation of DFIG based WECS and SST. This

configuration acts as an interface between the wind turbine

and grid while eliminating the GSC of DFIG. Moreover, it is

essential to have fault ride through (FRT) incorporated in

DFIG system to meet the grid code requirements [11]-[20]. In

the proposed work, the developed configuration allows DFIG

to ride through faults seamlessly, which is the aspect (FRT)

Replacing the Grid Interface Transformer in

Wind Energy Conversion System With Solid-

State Transformer Abdul Manna , S Imran Syed, Vinod Khadkikar, Senior Member, IEEE

tudent Member, IEEE, Vinod Khadkikar, Member, IEEE

Mannan Rauf, Student Member, IEEE, Vinod Khadkikar, Member, IEEE

O

mailto:[email protected]






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that has not been addressed in the earlier work on SST

interfaced WECS.

II. PROPOSED SYSTEM CONFIGURATION AND

MODELING

A. Motivation for DFIG

In [21], it has been reported that a DFIG based wind turbine

is the lightest amongst the current wind systems which also

explains its wide commercial use. Moreover, in the proposed

configuration, the GSC present in traditional DFIG systems is

removed making the machine setup further lighter. On the

other hand, SST being used in an AC/AC system is expected

to be 25% smaller in volume than traditional low frequency

transformer [22]. Thus, the use of SST to interface a DFIG

based wind system can be expected to provide further

reduction in weight and volume when compared to other wind

systems with the fundamental frequency transformer.

B. Background

The widely used DFIG based WECS configuration is shown

in Fig. 2 (a). The stator terminals of the machine are connected

directly to the grid while the rotor terminals are connected via

back to back converters. The RSC allows for variable speed

operation of the machine by injecting or drawing active power

from the rotor. The GSC maintains the DC link by transferring

the active power from the rotor to the grid or vice versa. The

step up transformer T1, is the interface between the DFIG

system and grid.

Three stage SST configuration is shown in Fig. 2 (b), where

it connects the grid to a distribution load. Conv-1 is a fully

controlled three-phase converter connected to the high voltage

grid (11-33 kV). It draws real power from the grid and

maintains the high voltage DC bus ( . This high voltage

DC is converted to high frequency AC voltage by a half bridge

converter (HB-1) which is then stepped down using a smaller

sized high frequency transformer. This transformer provides

the galvanic isolation between the grid and load. A second half

bridge converter (HB-2) converts the low voltage AC to low

voltage DC voltage ( . This DC bus supports conv-2

which maintains the three-phase/single phase supply voltage

to the load by producing a controlled three phase voltage. The

configuration thus performs the function of a regular

transformer allowing for bi-directional power flow using a

series of power electronics devices [5-10].

As mentioned earlier, the use of SST in WECS has been

explored by Xu et al. in [10]. SST was used in an SCIG based

WECS replacing the step-up transformer between the turbine

and grid. It was shown that SST can improve the voltage

profile at the terminals of the SCIG. While the focus of [10]

was on SCIG, possible configuration for DFIG systems was

also showcased that is represented in Fig. 2 (c). The step-up

transformer T1 in Fig. 2 (a) is directly replaced by the SST in

Fig. 2 (c).

RSC GSC

Vsabc

575V/25KVωmech

DFIG

Line

filter

RSC GSC

Vsabc

ωmech

DFIG

Line

filter

SST

575 V

25 KV

(a)

(b)

Grid

Grid

Conv-2

vldc vhdc

HB-2 HB-1 Conv-1

Grid

LoadMVLV

(c)

T1

Vldc1

Fig. 2 (a) Regular DFIG configuration, (b) SST structure and (c)

configuration suggested in [10].

C. Proposed System Description

The general DFIG based WECS representation is shown in

Fig. 3 (a) whereas the proposed system configuration is shown

in Fig. 3 (b). In the proposed configuration, the fundamental

frequency transformer is replaced by the SST. The proper

control of SST converter that is close to the stator of DFIG,

addressed as machine interfacing converter (MIC), can aid the

machine in its operation. Thus, it is proposed to eliminate the

GSC in the DFIG system configuration by incorporating its

role in SST. Note that this new arrangement modifies the

overall operation and control of standard GSC-RSC based

DFIG system. In principle, the machine terminal voltages can

be maintained constant in spite of any voltage variations in the

grid using MIC.

The direction of power flow in the proposed configuration

occurs from the low voltage machine terminals to the grid.

The MIC is responsible for: (i) maintaining the required

voltages at the stator terminals and (ii) transferring the real

power from the stator terminals ( to the low voltage DC

bus ( . This low voltage DC bus is regulated by the high

frequency stage converters (HB1 and HB2) and not by the

DFIG. In other words, MIC acts as a stiff grid at the stator

terminals. Interestingly, the low voltage DC bus (magnitude)

is very close to the one controlled by GSC in the regular DFIG

configuration [ in Fig. 2 (a)]. This allows the RSC in the

proposed configuration to be connected directly to of

SST. The has two functions, namely, (i) to transfer active

power from the stator terminals to the grid and (ii) to transfer

active power ( to/from the RSC during sub-synchronous or

super-synchronous operation.



3

DFIG

ωmech

RSC

vsabc

MIC High

frequency

stage

1:50

GIC

vldc vhdc

SOLID STATE

TRANSFORMER

DC

chopper (S1)

25 kV Ps

Pr

+-Ps Pr

Grid0.575 kV/25 kV

25 kV 0.575 kV

DFIG Wind

farm

0.575 kV

25 kV/120 kV

30 km

PCC

(a)

(b)

Fig. 3. (a) Regular DFIG configuration and (b) Proposed SST based DFIG configuration.

The power transfer through the high frequency stage, from

the low voltage DC bus to the high voltage DC bus ( ), is

controlled by introducing a phase shift between the two high

frequency AC voltages with the objective of regulating the DC

bus voltage ( . The grid interfacing converter (GIC)

connects SST to the grid and maintains the DC link by

exchanging active power with the grid.

To provide an effective FRT in the proposed configuration,

a DC chopper is incorporated at bus. During the grid

fault conditions, the power being generated by the wind

turbine is evacuated through the high frequency stage into the

DC chopper. Further, the high frequency stage continues to

maintain the low voltage DC bus ( , allowing the voltages

at the machine terminals to be constant. The presence of GIC

further helps to achieve the recent grid code requirements of

reactive current injection without requiring any additional

control or device. Furthermore, the GIC can provide reactive

power support to the grid during low wind generation periods.

D. DFIG Modeling

The DFIG is modeled using the synchronous

reference frame rotating at synchronous speed as depicted in

[4]. The machine flux equations can be written in the

reference frame as,

(1)

The voltage equations for the stator and rotor are given as,

(2)

The and axes quantities are represented by the

respective subscripts and . and represent the stator and

rotor resistances. and represent the stator, rotor and

mutual inductances referred to stator. represents the

electrical supply frequency and represents the rotor

frequency. Using (1)-(2), the torque equation for the machine

can be obtained as,

(3)

It can be understood from the above equation that on

aligning the stator flux with the -axis, the torque in the

machine can be controlled by varying . This is the basis on

which the rotor side converter is controlled. It can also be

shown that by varying , reactive power output from the

stator can be controlled. Further details on the DFIG modeling

can be obtained from [4].

III. CONTROL OF THE PROPOSED SYSTEM

To ensure smooth operation of the proposed configuration,

the control objectives and algorithms for the RSC, MIC and

the GIC are discussed below and shown in Fig. 4.



4

PWMdq

abc

PI-

+PI

𝑠 𝑠 𝑚

+

-

∗

𝑒∗

i*qr

iqr

𝑚 𝑠

𝑙 + 𝑚

RSC gate

signals

(a)RSC control

PI+

-𝑉𝑙 𝑐∗

𝑉𝑙 𝑐

𝜙

Phase

shift

dq

abc

𝑉𝑙𝑎𝑏𝑐 𝑒𝑓

PLL𝜃

𝑉𝑙 𝑒𝑓

dq

abc𝑉𝑙𝑎𝑏𝑐

PLL𝜃

𝑉𝑙

PI-

𝑉𝑙

𝑉𝑙 𝑒𝑓 dq

abc0PWM

Conv-1

gate

signal

(c) High frequency

stage control

(b) MIC control

0.9

0.5

0.90

Vg

igq

i*gq

Fault signal

+

-

igq

PI

v*gq

dq

abcFault signal

PI

V*hdc

+

-

𝑔𝑚𝑎𝑥2 𝑔

2

Vhdc

i*gd

i*gd

+

-

igd

PI

v*gd

Fault signal

DC

chopper

switch

signals

PWM

Conv-2

gate

signal

(d)GIC control

i*gq

i*gd

--

-

+

vgq

vgd

PLL

vgabc

𝜃

PLL

vlabc

𝜃

( 𝑚𝑒𝑎𝑠𝑝𝑓

)2 – 𝑚𝑒𝑎𝑠2

FS1

FS2

FS3

0

Switch Position Decision

FS1

1 Reactive power support

2(fault) Fault reactive current

FS2

1 DC bus regulation

2(fault) Active power

FS3

1 Generate d-axis reference current

2(fault) DC chopper activation signal

1

1

1

2

2

2

i*gq+

-

Qmeas

PI

Fig. 4. Control diagram of proposed configuration.

A. RSC Control

The rotor side control ensures the variable speed operation

of DFIG by enabling the generator to work in super

synchronous or sub synchronous modes. In super synchronous

mode, the total power generated is partially evacuated through

the RSC. Under sub synchronous modes, the RSC injects

active power into the rotor. The RSC in the proposed

converter is controlled using a decoupled synchronous

frame reference. The -axis of the reference frame is aligned

with the machine stator voltage. On doing this, as per (3), the

torque produced by the machine can be directly controlled by

controlling the -axis rotor current . Moreover, the reactive

power produced at the stator terminal can also be controlled

by controlling the -axis rotor current . The control

schematic for the same is shown in Fig. 4. A suitable MPPT

curve is used to track the optimal rotor speed and is compared

with the measured rotor speed. The error is processed by a PI

controller to produce the reference torque ( ∗) for the

machine. Using (3), the rotor -axis reference current ( ∗ ) is

calculated. This current is compared with the actual rotor -

axis current ( and the error is processed by a PI controller

to generate the -axis reference voltage ( ∗ In the proposed

configuration, the stator terminals are completely decoupled

from the grid through the SST. The GIC supplies any reactive

power requirement from the grid and the machine only

generates active power. This eliminates the need for control

over the 𝑎𝑥 𝑠 rotor current and voltage. Thus, the

𝑎𝑥 𝑠 rotor voltage reference for RSC ( ∗ ) is maintained

as zero. The axis reference voltages are then converted

to three phase and used to generate the gate pulses for the



5

RSC. Further details regarding the control system can be

obtained in [4].

B. MIC control

The MIC is the first stage of the SST connecting the low

voltage machine output to the high frequency stage. This

converter is controlled to maintain 1 p.u. voltage (0.575 kV) at

50 Hz at the stator terminals of the machine.

The control is achieved by generating a reference voltage

and comparing the -axis component of the reference ( ∗

with the voltage at the output of the converter ( ). The

power generated at the stator terminals of the machine is thus

absorbed by the low voltage DC bus connected to MIC

operating at 1.15 kV.

C. High frequency stage control

The high frequency stage transforms the low voltage DC

bus voltage (1.15 kV) into high voltage DC (50 kV). The DC

voltages are converted into high frequency AC voltages by the

two half bridge converters. Power is transferred by

introducing a phase shift between the AC voltages of the two

converters linked together by a high frequency transformer.

The equation that governs the transfer of power is given as,

(4)

Where 𝜙 is the phase shift between the AC voltages and is

the leakage inductance of the high frequency transformer. The

complete derivation of the power transfer equation and further

details can be obtained in [23]-[25].

The control objective of high frequency stage, in the

proposed configuration, is to maintain the low voltage DC bus

voltage ( ) at a constant level. In order to achieve this, the

reference voltage ∗ is compared with the measured value

and the resulting error is processed by a PI controller which

produces the required phase shift 𝜙 that transfers the active

power from the low voltage DC bus to the high voltage DC

bus. The schematic for control is shown in Fig. 4 (c).

D. GIC control

While the control of other converters remains the same in

fault and normal conditions, GIC is controlled differently

during fault conditions. The control and operation of GIC is

discussed in two modes. Fault detection switches are used that

are triggered when a fault is detected. The positions of the

switches and their operation are summarized in a table in Fig.

4 (d).

1) Normal mode

Under normal mode of operation, the objective of the GIC is

to ensure that the active power produced by the wind system is

delivered to the grid. Additionally, it is suggested in this paper

that the GIC provide reactive support as per user defined

power factor to the grid when the wind generation is lower

than rated value. Fig. 4 (d) shows the overall control of GIC.

90 %80 %

50 %

15%

0 150 625 1733 2683 3 min

100 %

1 p.u

50 %

V/Vn dV/Vn

dI/In

(a) (b)

Fig.5. Latest FRT grid code requirements (a) The Fault Ride Through

requirement and (b) The reactive current requirement.

The control of the converter is designed based on the

reference frame. The -axis current ( controls the flow of

active power and the DC bus voltage while the -axis current

( controls the reactive power flow. The -axis reference

grid current ( ∗ is generated based on the user defined power

factor requirement which is used to calculate the reference

reactive power ( ∗ which is compared with the measured

reactive power and passed through a PI controller.

Reference reactive power ∗ can be calculated from the power

factor as

∗ 𝑚𝑒𝑎𝑠

𝑝𝑓 – 𝑚𝑒𝑎𝑠

(5)

The -axis reference current is generated by passing the

error between the measured DC bus voltage and its reference

through a PI controller. An outer loop voltage controller then

generates the -axis reference voltage ∗ . Similarly, the -

axis reference voltage ∗ is obtained from a PI controller on

the -axis current.

2) Fault mode

The objective of the GIC under fault conditions is to supply

the reactive currents as per the grid codes. The fault in the

system is identified by monitoring the positive sequence grid

voltage which is effective in both symmetrical and

unsymmetrical fault conditions.

Upon identifying the fault, the fault switches (FS1 to FS3)

shown in Fig.4 (d) are activated. Under fault conditions,

preference is given to reactive current injection and the control

of DC bus by the GIC is deactivated by FS3. The reactive

current reference enabled by FS2 for the GIC is generated as

per the grid codes in [19] and [20] shown in Fig. 5 and is

calculated as,

∗

∗

𝑓

𝑝 𝑓

(6)

Where , is the difference between the pre-fault voltage

and the current grid voltage and is the rated nominal

voltage. is the difference between the pre-fault reactive

current and the reactive current during fault and is the

rated current value. In the case considered in this paper is



6

1 p.u. and there is no pre-fault reactive current, thus,

is

equal to the reactive current to be injected i.e. ∗ .

Recent grid codes in some countries have even more

aggressive reactive current requirements sometimes

requiring the wind farm to supply up to 1.2 p.u. reactive

currents [26]. The -axis reference current is then compared

with the measured one. The error is processed by a PI

controller to generate the -axis reference voltage ( ∗ ).

When the fault is less severe and the voltage dip is less than

1 p.u. the grid codes do not impose any restriction on

injecting active power into the grid. Hence, after prioritizing

reactive current injection, the remaining capacity of the GIC

is used to continue to inject any active power possible by

switching FS1. The reference for the -axis current is

generated as follows based on the maximum allowable

rating of the GIC, and is expressed as

∗

(7)

Upon identification of fault, in order to prevent the DC bus

voltage from rising, a DC chopper is employed (FS3 at

position 2). The measured error between the high voltage DC

bus reference ∗ and the measured value ( is passed

through a hysteresis relay that produces the switching signal

for DC chopper circuit. which is designed to allow for a two

percent variation in bus voltage.

𝑓

∗ 𝑉

𝑓 ∗ 𝑉

(8)

IV. SYSTEM SIMULATION AND ANALYSIS

To verify the effectiveness of the proposed configuration,

detailed simulations are carried out. The simulated system is

as represented in Fig. 3. A detailed model of proposed

configuration is developed using the SIMULINK and

SimPowerSystems toolbox in MATLAB. All the system

parameters are given in Table I. The performance of proposed

system is evaluated under different operating conditions. All

the results shown are in p.u. on a base of 5.1 MVA with

respective voltages.

A. Normal operation

Firstly, the operation of the proposed configuration is

shown under normal grid conditions in Fig. 6. In this scenario

(between 4.9 to 5 sec), the wind turbine is operated at a speed

of 13 𝑚 𝑠 thus not producing peak power. The wind turbines

produce a total of 4.2 MW active power. Like general DFIG,

the system delivers this wind generated active power to the

grid as shown in Fig. 6 (e) through the SST.

That is, there is no reactive power support from the GIC.

Figs. 6 (a) and (b) show the grid voltages and currents at the

output of the GIC. Figs 6. (c) and (d) give the stator terminal

voltages and machine currents at 0.575 kV.

TABLE I

SYSTEM PARAMETERS

Parameter Value

System Data

Rated power 5 MVA

No. of wind turbines 3

Wind Turbine data

Rated power 1.5 MW

Rated wind speed 15m/s

Generator Data

Rated apparent power 1.66 MVA

Rated voltage 0.575 kV

No of poles 6

Rated frequency 50 Hz

Stator to rotor turns ratio 575/1975

Stator resistance,

Inductance

0.0023 p.u.,0.18 p.u.

Rotor resistance,

inductance

0.0016 p.u.,0.16 p.u.

Inertia constant 0.685 s

SST Data

Low voltage DC bus ( 1.15 kV

operating frequency 3 kHz

HF transformer turns ratio 1:50

HF transformer inductance 5.95

High voltage DC bus ( 50 kV

The high and low voltage DC bus voltage profiles are

illustrated in Figs.6 (f) and (g), respectively. Fig. 6 (h)

provides the controlled inner loop -axis and -axis currents

of the GIC that control the active and reactive power injection

into the grid, respectively. Fig. 6 (i) shows the rotor speed of

the machine which remains constant at 1.2 p.u.

B. Reactive Power Support during steady-state

The feature of using the GIC capacity to provide reactive

power support during lower wind speeds is also shown in Fig.

5 (between time interval of 5 sec to 5.1 sec). At 5 𝑠𝑒𝑐, the

reactive power reference is activated to fully utilize the GIC

capacity. With 13 𝑚 𝑠 wind speed (i.e. 4.2 MW), the

proposed configuration can inject 2.7 MVar (Fig. 5 (e)).

C. Symmetrical Fault

The performance of proposed configuration to meet FRT

requirements in recent grid codes are discussed in this section.

A severe LLL-G fault is applied at upstream grid when the

DFIG is producing maximum power (at 15 𝑚 𝑠). The results

are shown in Fig. 7. The fault is detected by sensing the

positive sequence voltage magnitude. Fig. 7 (a) shows the grid

voltages during the fault which is introduced at 3 𝑠𝑒𝑐 and lasts

for 150 𝑚𝑠 as per the grid code requirement. Fig. 7 (b) shows

the grid currents injected by the GIC. Figs.7 (c) and (d) depict

the stator voltage and currents of the machine, respectively.

Note that the turbine does not see any change in the operating

condition as MIC maintains the rated stator voltages despite



7

the severe fault condition. Figure 7(f) shows the low voltage

DC bus which remains constant. Further, as seen from Fig. 7

(g), the DC chopper evacuates the active power generated by

the turbines successfully. Thus, in the proposed configuration,

turbines seamlessly ride through the grid fault. On the grid

side, the GIC is controlled to inject necessary reactive current

to meet the grid codes.

(𝑎)

(𝑏)

(𝑐)

( )

(𝑓)

(𝑔)

(ℎ)

(𝑒)

( )

-1

0

1

49

50

51

0.5

1

1.5

-1

0

1

-1

0

1

-1

0

1

-1 0

2

3.5

5

4.9 4.95 5 5.05 5.10

1

-1

0

1

-1

0

1

45

55

-1

0

1

-1

0

1

-1

0

1

1

1.5

0

1

-1

0

1

0

2

3.5

5

𝑔

𝑔

𝑙 𝑐

𝑠

𝑠

𝑔

𝑔

𝑔

𝑔

ℎ 𝑐

(𝑎)

(𝑏)

(𝑐)

( )

(𝑓)

(𝑔)

(𝑒)

(ℎ)

( )

Fig 6. Normal operation of proposed configuration showing dynamics of P

and Q injection. (a) Grid voltages, (b) grid currents,(c) stator terminal

voltages, (d) stator currents, (e) active and reactive power injected by the

system, (f) high voltage DC bus voltage, (g) low voltage DC bus voltage, (h)

inner loop controlled axis grid currents and (i) rotor speed.

Fig. 7 (e) shows the and -axis currents of the GIC,

and , respectively. In pre-fault conditions it can be seen that

is at 1 p.u. since the wind turbine is operated at maximum

capacity. The 𝑎𝑥 𝑠 current on the other hand is at zero

as no reactive power is being injected. At 3 𝑠𝑒𝑐, when the

fault occurs, the fault switch (FS2) is set to position 2 and the

reactive current reference ∗ is calculated as per (6). The

GIC, thus, injects 0.9 p.u reactive current that can be seen in

Fig. 7 (e). The - axis current ( is calculated as per (7).

D. Unsymmetrical fault condition

The performance of the proposed configuration is tested

under unsymmetrical faults condition as well. A single phase

L-G fault is applied at the upstream grid when the DFIG is

producing maximum power (15 𝑚 𝑠). Fig.8 (a) shows the grid

voltages when the fault occurs at 3 𝑠𝑒𝑐 and lasts for 150 𝑚𝑠.

Fig. 8 (b) shows the grid currents injected by the GIC. Note

that the currents remain symmetrical despite the

unsymmetrical fault. Figs.8 (c) and (d) show the stator

voltages and currents which remain undisturbed as the MIC

maintains rated stator voltages similar to the symmetrical case.

-1

0

1

45

55

-1

0

1

-1

0

1

-1

0

1

0

1

1.5

2.95 3 3.1 3.20

1

-1

0

1

𝑔

𝑔

(𝑎)

(𝑏)

(𝑐)

( )

(𝑓)

(𝑔)

𝑠

𝑠

𝑔

𝑔

(𝑒)

(ℎ)

𝑙 𝑐

ℎ 𝑐

Fig 7. Performance of the proposed configuration under three-phase

symmetrical LLL-G fault. (a) Grid voltages, (b) grid currents,(c) stator

terminal voltages, (d) stator currents, (e) inner loop controlled axis grid

currents, (f) low voltage DC bus (g) high voltage DC bus voltage and (h)

rotor speed.

Fig. 8 (f) shows the low voltage DC bus. Fig.8 (g) shows

the chopped DC bus voltage. Note that during a single phase

fault, active power is still being transferred to the grid and the

amount of power evacuated through the DC chopper is lesser



8

than the case of a severe three phase fault. During this fault,

the positive sequence voltage drops to 0.8 p.u. giving the

reactive reference current ( ∗ ) as 0.4 p.u. The reactive and

axis currents, and are shown in Fig. 8 (e),

respectively.

-1

0

1

45

55

-1

0

1

-1

0

1

-1

0

1

0

1

1.5

2.95 3 3.1 3.20

1

-1

0

1

𝑔

𝑔

(𝑎)

(𝑏)

(𝑐)

( )

(𝑓)

(𝑔)

𝑠

𝑠

𝑔

𝑔

(𝑒)

(ℎ)

𝑙 𝑐

ℎ 𝑐

Fig 8. Performance of the proposed configuration under three-phase

unsymmetrical L-G fault. (a) Grid voltages, (b) grid currents,(c) stator

terminal voltages, (d) stator currents, (e) inner loop controlled axis grid

currents, (f) low voltage DC bus (g) high voltage DC bus voltage and (h)

rotor speed.

E. Comparison

In order to showcase the advantages of the proposed

configuration, a comparison has been made in Fig. 9, of DFIG

operation without any FRT techniques, with a DC chopper

installed and under the proposed configuration. As can be seen

in Fig. 9 (a)-(g), in the case with no FRT techniques, the grid

and rotor currents increase significantly up to four times the

nominal value. The DC link voltage between the back to back

converters of the DFIG increases to nearly two times the

nominal value as the power coming from the rotor is not

evacuated into the grid. The high voltages can be potentially

damaging to the rotor side converter switches, whereas the

high currents on the grid and rotor side can lead to potential

damage to the machine.

Fig. 9 (h) to (n) show the results upon installing a DC

chopper on the DC link of the regular DFIG configuration.

DC chopper is a commonly used FRT technique that prevents

the DC link voltage from rising by evacuating power coming

from the rotor using a switch and a resistor. Further details

regarding DC chopper operation can be found in [27]-[28]. In

the presented case, the DC link voltage is allowed to vary by

100 V which is around ten percent of the nominal voltage. It

can be observed from Fig. 9 (m) that, with the DC chopper,

the DC link voltage is prevented from increasing. This

protects the RSC switches from overvoltage. However, the

grid and rotor side currents are still very high. In order to

eliminate this problem, additional techniques need to be

employed, such as, crowbar protection for rotor and dynamic

braking resistors for the grid side [27].

In the proposed configuration, whose results are shown in

Fig. 9 (o) to (u), the machine seamlessly rides through the

fault. Further, the DC bus voltages are maintained constant

and grid and rotor side currents are not affected by the fault.

Additionally, the proposed configuration has the capability to

inject reactive currents during fault that has been further

elaborated previously in Figs. 7 and 8.

V. CONCLUSION

In this paper, a new system configuration that combines

DFIG and SST operation has been proposed. This

configuration replaces the regular fundamental frequency

transformer with advanced power electronics based SST. The

key features of the proposed configuration are outlined below:

- Replacement of regular fundamental frequency

transformer with SST leading to smaller footprint.

- Direct interface with SST to inject active power.

- Elimination of GSC in a standard DFIG system as the

active power to/from RSC is regulated by MIC.

- Simplified DFIG control as machine supports only active

power. The reactive power is supported by GIC during

both normal and fault conditions.

- Seamless fault ride through operation during both

symmetrical and unsymmetrical faults as per the latest

grid codes.



9

-1

0

1

-1

0

1

-1

0

1

-1

0

1

0

1

1.5

2.95 3 3.1 3.20

1

-1

0

1

-1

0

1

-4

-2

0

2

4

-1

0

1

-4

-2

0

2

4

0

1

1.5

2.95 3 3.1 3.20

1

-4

-2

0

2

4

-1

0

1

-4

-2

0

2

4

-1

0

1

-4

-2

0

2

4

0

11.5

2.95 3 3.1 3.20

1

-4

-2

0

2

4

(𝑎)

(𝑏)

(𝑐)

( )

(𝑓)

(𝑔)

(𝑒)

(ℎ)

( )

(𝑗)

( )

(𝑚)

(𝑛)

(𝑙)

(𝑜)

(𝑝)

( )

( )

( )

( )

(𝑠)

𝑔

𝑠

𝑠

𝑙 𝑐

𝑜 𝑜

𝑔 𝑔

𝑔 𝑔

𝑠 𝑠

𝑠 𝑠

𝑜 𝑜 𝑜 𝑜

𝑙 𝑐 𝑙 𝑐

REGULAR DFIG W/O FRT REGULAR DFIG WITH DC CHOPPER PROPOSED CONFIGURATION

Fig. 9 (a)-(g) Operation of regular DFIG without FRT, (h)-(n) operation of DFIG with DC chopper installed and (o)-(u) operation of proposed configuration

under fault.

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Imran Syed received his B.Tech degree from

National Institute of Technology, Triruchirapalli,

India (NIT, Trichy) in 2009, followed by an M.Sc

degree in electrical power engineering from the

Masdar Institute of Science and Technology, Abu

Dhabi, United Arab Emirates, in 2013.

From 2009-2011, he was working as an assistant

manager at National Mineral Development

Corporation (NMDC, Ltd), in charge of plant

operations and maintenance. Currently, he is pursuing a Ph.D degree at

Masdar Institute of Science and Technology. He was a visiting doctoral

student at Massachusetts Institute of Technology (MIT), Cambridge, MA,

USA from February 2015 to May 2015. His research interests include power

electronics applications to power systems, grid integration of renewable

energy sources and regulation of electric power sector.

Vinod Khadkikar (S’06, M’09, SM’15) received his

M. Tech. from the Indian Institute of Technology

(IITD), New Delhi, India, in 2002 and Ph.D. degree

from the École de Technologie Supérieure (E.T.S.),

Montréal, QC, Canada, in 2008, all in Electrical

Engineering.

From December 2008 to March 2010, he was a

Postdoctoral Fellow at the University of Western

Ontario, London, ON, Canada. From April 2010 to

December 2010, he was a visiting faculty at Massachusetts Institute of

Technology, Cambridge, MA, USA. Currently he is an Associate Professor at

Masdar Institute of Science and Technology, Abu Dhabi, UAE. His research

interests include applications of power electronics in distribution systems and

renewable energy resources, grid interconnection issues, power quality

enhancement, active power filters and electric vehicles.

Dr. Khadkikar is currently an Associate Editor of the IEEE Transactions

on Industrial Electronics and IET Power Electronics Journal.

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