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Journal of Recent Research in Engineering and Technology, 2(11), 2015, pp 10-15 Article ID

J111503 ISSN (Online): 2349 –2252, ISSN (Print):2349–2260

© Bonfay Publications

16

ADAPTIVE ISLANDING OF DISTRIBUTED ENERGY RESOURCES USING LAB VIEW REAL TIME

MONITORING SYSTEM

1A. Stanly Paul, 2P.Vijayakumar

1Assistant Professor, Karpagam College of Engineering, Coimbatore - 641032, TamilNadu.

2Professor, Kathir College of Engineering, Coimbatore - 641062, TamilNadu

ABSTRACT- In the modernised society, the difficulty of augmented load demand needs essential

progress in smarter infrastructure, it involves a federalized methodology, named smart grid. It is the

combination of renewable energy sources or Dispersed system. Dispersed system forms the

Distributer Energy Resources (DER). The Dispersed Generation can either be operated in parallel

with the grid or independent condition also called as Intentional Islanding. It requires uninterrupted

supervision, control and performance. In conventional method, the monitoring and control of

Islanding detection made with measuring instruments and manual operating mechanical switches.

These methods, do not have powerful monitoring and control, with poor time responding. In modern

power systems, the power quality monitoring is a common practice for utilities. The immersion of

embedded controllers reduces the risk of fault analysing time and enriches the overall performance.

This paper presents a novel approach in power system islanding with Virtual Instruments based

monitoring, Control and recording of Distributer Energy Resources parameters.

KEYWORDS: Dispersed system (DS), Distributed Energy Resources (DER), Islanding Techniques, Rate

of Change of Frequency (ROCOF), Vector Shift, Loss of Mains (LOM), Lab VIEW, Distributed

generations (DGs).

I. INTRODUCTION

In this modern era, the importance of

renewable energy based distributed power

generation and the advancement in power

electronics technologies, a large number of

inverter based DG units have been installed in

conventional low voltage power distribution

systems [1]. To achieve better operation of

multiple DG units, the micro grid concept using

coordinated control among parallel DG interfacing

converters has been well accepted. When the

micro grid is disconnected from the utility, the

grid forms an autonomous islanding system.

On the other hand the islanding micro

grid may have serious power quality problem due

to the increasing presence of nonlinear loads [2].

Islanding, loss of mains (LOM) loss of mains or

loss of grid is a generic term used to describe

scenario where a section of the distribution

network is supplied by a generator

isolated from the main utility supply.

Thus islanding detection is required by G-59, for

any generator that’s wants to be connected to an

electrical distribution network [3]. Such a

generators normally refers to DG and islanding or

LOM protection must be installed on its inter tie to

the utility network; i.e., the DG must allowed to

supply a part of distribution network once it has

become electrically isolated from the main grid

supply.

2. DISTRIBUTED GENERATIONS

Recent revolutions in power electronics

such as fast switching, high voltage Insulated Gate

Bipolar Transistors (IGBT) and developments in




17

power generation technologies have made DG a

considerable alternative to either delaying

infrastructure upgrades or as additional

cogeneration support [4]. Though the cost per

KW-hr is still higher than basic power grid

distribution costs, the increasing trend in the cost

of fossil fuels has resulted in the consideration of

DG as a viable opportunity. Distributed Generators

can be broken into three basic classes: induction,

synchronous and asynchronous. Induction

generators require external excitation (VARs) and

start up much like a regular induction motor. They

are less costly than synchronous machines and are

typically less than 500 KVA. Induction machines

are most commonly used in wind power

applications [2]. Alternatively, synchronous

generators require a DC excitation field and need

to synchronize with the utility before connection.

Synchronous machines are most commonly used

with internal combustion machines, gas turbines,

and small hydro dams. Finally, asynchronous

generators are transistor switched systems such

as inverters. Asynchronous generators are most

commonly used with micro turbines, photovoltaic,

and fuel cells [5]. A comparison of each type of

generation system is shown in Table I.

TABLE I Comparison of DGs Individual capacity

Technology Capacity Typical

Interface

Photovoltaic 10VA to

5000VA inverter

Wind 10VA to

500KVA

Induction and

Synchronous

Generators,

Inverters

Geothermal 100VA to

several

Synchronous

Generator

MVA

Micro Hydro

100VA to

several

MVA

Induction or

Synchronous

Generator

Reciprocating

Engine

1000VA

to

several

MVA

Induction or

Synchronous

Generator

Combustion

Turbine

1000VA

to

several

MVA

Synchronous

Generator

Combined

Cycle

1000VA

to

several

MVA

Synchronous

Generator

Micro

Turbines

10 KVA

to

several

MVA

inverter

Fuel Cells

10 KVA

to

several

MVA

inverter

Distributed or dispersed generation may be

defined as generating resources other than central

generating stations that is placed close to load

being served, usually at customer site. It serves as

an alternative to or enhancement of the traditional

electric power system. The commonly used

distributed resources are wind power, photo

voltaic, hydro power.

Distributed Generation (DG) is not without

problems. DG faces a series of integration

challenges, but one of the more significant overall

problems is that the electrical distribution and




18

transmission infrastructure has been designed in a

configuration where few high power generation

stations that are often distant from their

consumers, ”push” electrical power onto the many

smaller consumers. DG systems are often smaller

systems that are that are locally integrated into

the low voltage distribution system. The Dispersed

one line diagram of the distribution system with

Multiple DG is shown in Figure 1.

DG1 DG2 DG3 DG4 DGn

STS

LD1 LD2 LD3 LD4 LDn

Main

Grid

Pdc1 Pdc2 Pdc3 Pdc4 Pdcn

Fig. 1. Structure of Distributed Energy Resources

Different technical challenges of Distribution

Generations are Voltage Regulation and Losses,

Voltage Flicker, DG Shaft, Over-Torque during

Faults, Harmonic Control and Harmonic Injection,

Increased Short Circuit levels, Grounding and

Transformer Interface, Transient Stability,

Sensitivity of Existing Protection Schemes,

Coordination of Multiple Generators, High

Penetration Impacts are Unclear, Islanding Control

[6].

Area 1 DGs

Area 2 DGs

Area 3 DGs

Main Grid

PCC

PmainArea 1

Area 2

Area 3

Pa1

Pa2

Pa3

LDa1

LDa2

LDa3

FL1 2Max FL2 3Max

Fig. 2. Islanding Area of Distributed Generations

3. ISLANDING IN POWER SYSTEM

Islanding is the situation in which

distribution system has been electrically isolated

from the mail Power system, yet continues to be

energized by DG connected to it. Traditionally, a

distribution system does not have any active

power generating sources in it, and it doesn’t get

power in case of a fault in Transmission line

upstream but the DG, this presumption is no

longer valid. Current Practice DG should be

disconnected from the grid as soon as possible in

case of islanding.

Distributed Energy Resources (DER)

DG-1

DG-2 DG-3

Load-1 Load-2

Load-3 Load-4 Load-5 Load-6

HV

MV

LV

HV / MV

MV / LV MV / LV

LV

CIRCUIT

BRAKER-8

CIRCUIT

BRAKER-9

CIRCUIT

BRAKER-1

CIRCUIT

BRAKER-3CIRCUIT

BRAKER-7

CIRCUIT

BRAKER-6

CIRCUIT

BRAKER-5

CIRCUIT

BRAKER-4

CIRCUIT

BRAKER-2

GRID

Capacitor

Bank-1

Capacitor

Bank-2

Islanding Area

Fig. 3. Islanding of Distributed Energy Resources

IEEE 929-1988 standard requires

the disconnection of DG once it is islanded and

IEEE 1547-2003 standard [3] stipulates a

maximum delay of 2 seconds for detection of an

unintentional island all DGs ceasing to energize

the Distribution system, as they are various issues

with unintentional islanding although there are

some benefits of islanding operation, there are

some drawbacks as well. Some of them are, Line

worker safety can be threatened by DG sources

feeding a system after primary sources have been

opened and tagged out. The voltage and frequency

may not be maintained within a standard

permissible level. The islanded system may be

inadequately grounded by the DG interconnection.

Instantaneous reclosing could result in out of

phase reclosing of DG [7].

As a result of which large

mechanical torques and currents are created that

can damage the generators or prime movers [4].

Also, transients are created, which are potentially

damaging to utility and other customer

equipment. Out of phase reclosing, if occurs at a

voltage peak, will generate a very severe




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capacitive switching transient and in a lightly

damped system, the crest over-voltage can

approach three times rated voltage [5]. Due to

these reasons, it is very important to detect the

islanding quickly and accurately. The main

philosophy of detecting an islanding situation is to

monitor the DG output parameters and/or system

parameters and decide whether or not an

islanding situation has occurred from change in

these parameters.

4. TECHNIQUES FOR ISLANDING DETECTION

Techniques propose for islanding

detection can be generally divided into two

categories; Active methods and passive methods

are based on monitoring one or more system

parameters and they make their trip decision

without directly interacting with system

operation. Active methods directly and actively

interact with the power system to detect the part

of the network that has been islanded [8]. The

main passive techniques proposed for islanding

protection include rate of change of Frequency

(ROCOF), vector shift, under/over frequency,

under/over voltage and reverse VAr. beside these

scheme, many other passive techniques have been

proposed for islanding detection such as change of

output power, rate of change of voltage and power

factor ROVAP. Elliptical trajectory techniques ERT,

ratio of the frequency change to the outer power

change ∂f/∂P and voltage balance and (THD) Total

Harmonic Distortion.

The main active techniques of islanding

detection are Reactive Power Error Export

Detection (REED), Fault Level monitoring and

system impedance monitoring. Active methods are

generally considered more effective and robust

than passive methods, because they detect

islanding by continuously interacting with the

output of the DG.

The schemes that interact by injecting a small

disturbance in to the network might be an adverse

impact of on power quality and the dynamics of

the overall systems. Furthermore their

effectiveness may be a problem if multiple DGs are

connected in the islanded network this introduces

the possibility of interference between the signals

are disturbance injected at each DG. Therefore for

such technical reasons, and perhaps more

importantly higher cost, active methods are not

favoured by industry and rarely implemented.

Passive Method Active Method

Local TechniquesRemote

Techniques

Hybrid Method Utility methodCommunication

Based Method

Under/Over Voltage (UVP/OVP) and

Under/Over Frequency (UFP/OFP)Detection Imbalance measurement

Voltage Phase Jump (VPJ) Detection

Detection of Voltage and Current Harmonics

Detection of Impedance at Specific Frequency

Slip mode Frequency Shift (SMFS)

Frequency Bias @ active frequency drift (AFD)

Variation of Active Power and Reactive Power

Sandia Frequency Shift (SFS)

Sandia Voltage Shift (SVS)

Frequency Jumb (FJ)

Main Monitoring units with alloocated all-pole

switching device conected in series (MSD)

General Electrical Frequency Scheme

Impedance Insertion Transfer Trip Scheme

Power line carrier communication (PLCC)

Power Line signaling Scheme

Islanding Technique

Satellite communication and Data

Acquisition (SCADA)

Fig. 4. Islanding Techniques

Passive methods for loss of mains LOM

protection dominated due to their simplicity and

low cost, and of these ROCOF and Vector shift are

the most widely used. Although popular, problems

in there application are experienced with the load

and generation on the part of the network that

become islanded are closely matched, this

limitation is recognized in engineering

recommendation (ETR) 113, further more passive

method can, on some network fail to discriminate




20

between an actual LOM and other transient

events. Nuisance tripping can occur if the system

frequency varies suddenly due to load switching,

loss of bulk generation or network faults.

In conventional LOM techniques are not

sufficient to prevent islanding, and then a transfer-

trip scheme with reliable mains of communication

may be necessary. A transfer trip scheme also

referred to “inter-tripping” is conceptually

different from the above mentioned passive and

active techniques in that it doesn’t operate based

on measuring any electrical system parameters. It

works on the basis of monitoring the open or

closed status of all the circuit breakers and re-

closes in the utility network that put result in a DG

supporting an Island without a connection to the

utility network. A transfer trip scheme does not

suffer the problem of a non-detection zone like

other LOM techniques.

TABLE II Comparison of Islanding Techniques

Islandin

g

Techniq

ues

Advantage

s

Disadvant

ages Examples

Remote

Techniq

ues

Highly

reliable

Expensive Transfer

trip

scheme

PLS

scheme

Local Techniques

1.Passiv

e

Techniq

ues

Short

detection

Time, Do

not

perturb

the

Difficult to

detect

islanding

special

care has

to be

ROCOOP

Scheme,

ROCOF

Scheme,

ROCOFOP

Scheme,

system,

Accurate

taken

while

setting the

thresholds

Nuisance

tripping

COI

Scheme,

Voltage

Unbalance,

Scheme,

Harmonic

Distortion

scheme

2.Active

techniqu

es

Small NDZ Introduce

perturbati

on

Detection

time is

slow

degrades

the power

quantity

RPEED

Schem

e

Impedance

Measurem

ent

Scheme

SMS, AFD,

AFDPF

and ALPS

3.Hybrid

Techniq

ues

Small

NDZ.

Perturbati

on is

introduce

d

More

Islanding

Detection

Time

Positive

feedba

ck and

voltage

imbalance

Technique

voltage

and

Reactive

power shift

5. LabVIEW

LabVIEW (Laboratory Virtual Instrument

Engineering Workbench) is a system-design

platform and development environment for

a visual programming language from National

Instruments. The graphical language is named "G".

Originally released for the Apple Macintosh in

1986, LabVIEW is commonly used for data

acquisition, instrument control, and industrial

automation on a variety of platforms

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http://en.wikipedia.org/wiki/Automation




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including Microsoft Windows, various versions

of UNIX, Linux, and Mac OS X. The latest version of

LabVIEW is LabVIEW 2013, released in August

2013. In this paper the LabVIEW based hybrid

islanding techniques with real time monitoring is

briefly discussed with corresponding simulation

results.

5.1. FOCOF RELAY

The rate of change of frequency, df/dt, will be

very high when the DG is islanded. The rate of

change of frequency (ROCOF) can be given by [9]

dt

df = HP2

1 × f

(1)

Where,

P is power mismatch at the DG side

H is the moment of inertia for DG/system

G is the rated generation capacity of the

DG/system

Large systems have large H and G where

as small systems have small H and G giving larger

value for df/dt ROCOF relay monitors the voltage

waveform and will operate if ROCOF is higher than

setting for certain duration of time. The setting has

to be chosen in such a way that the relay will

trigger for island condition but not for load

changes. This method is highly reliable when there

is large mismatch in power but it fails to operate if

DG’s capacity matches with its local loads.

However, an advantage of this method along with

the rate of change of power algorithm is that, even

they fail to operate when load matches DG’s

generation, any subsequent local load change

would generally lead to islanding being detected

as a result of load and generation mismatch in the

islanded system.

Main Grid

SG

PSG

L PL

ROCOF CBPSYS

Fig. 5. Equivalent Circuit of ROCOF Relay

Figure 5 presents an equivalent circuit of

a synchronous generator equipped with a ROCOF

relay operating in parallel with a distribution

network. In this figure, a synchronous generator

(SG) feeds a load (L). The difference between the

electrical powers PSG supplied by the generator

and PL consumed by the load is provided (or

consumed) by the main grid. Therefore, the

system frequency remains constant. If the circuit

breaker (CB) opens, due to a fault for example, the

system composed by the generator and the load

becomes islanded.

Fig. 6. Frequency variation in islanding with

respect to different inertia constant of DG

In this case, there is an electrical power

imbalance due to the lost grid power P SYS This

power imbalance causes transients in the islanded

system and the system frequency starts to vary

dynamically. Such system behavior can be used to

detect an islanding condition. However, if the

power imbalance in the islanded system is small,

then the frequency will change slowly. Thus, the

rate of change of frequency df/dt can be used to

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accelerate the islanding detection for this

situation. [10]

The rate of change of frequency is

calculated considering a measure window over a

few cycles, usually between 2 and 50 cycles. This

signal is processed by filters and then the resulting

signal is used to detect islanding. If the value of the

rate of change of frequency is higher than a

threshold value, a trip signal is immediately sent

to the generator CB. Typical ROCOF settings

installed in 60-Hz systems are between 0.10and

1.20 Hz/s. Another important characteristic

available in these relays is a block function by

minimum terminal voltage. If the terminal voltage

drops below an adjustable level Vmin, the trip

signal from the ROCOF relay is blocked. This is to

avoid, for example, the actuation of the ROCOF

relay during generators start-up or short circuits

[11].

5.2. VECTOR SURGE RELAY

Main Grid

E1L VT

VS ISYS

Xd

∆V ISG CB

Fig. 7. Equivalent Circuit of Vector Surge Relay

A synchronous generator equipped with a

VS relay operating in parallel with a distribution

network is depicted in Figure 7. There is a voltage

drop V between the terminal voltage VT and the

generator internal voltage EI due to the generator

current ISG passing through the generator

reactance Xd. Consequently, there is a

displacement angle between the terminal voltage

and the generator internal voltage, whose phasor

diagram is presented in Figure 9(a). In Figure 7, if

the CB opens due to a fault, for example, the

system composed by the generator and the load L

becomes islanded. At this instant, the synchronous

machine begins to feed a larger load (or smaller)

because the current ISYS provided (or consumed)

by the power grid is abruptly interrupted. Thus,

the generator begins to decelerate (or accelerate).

Consequently, the angular difference between VT

and EI is suddenly increased (or decreased) and

the terminal voltage phasor changes its direction,

as shown in Figure 9(b).

Analyzing such phenomenon in the time

domain, the instantaneous value of the terminal

voltage jumps to another value and the phase

changes the phase position changes as depicted in

Figure 9, the point A indicates the islanding

instant. Additionally, the frequency of the terminal

voltage also changes. This behavior of the terminal

voltage is called vector surge.

Fig. 8. Voltage waveform of DG in of loss of mains

VS relays are based on such phenomena.

VS relays available in the market measure the

duration time of an electrical cycle and start a new

measurement at each zero rising crossing of the

terminal voltage. The current cycle duration

(measured waveform) is compared with the last

one (reference cycle). In an islanding situation, the

cycle duration is either shorter or longer,

depending on if there is an excess or a deficit of

active power in the islanded system, as shown in

Figure 8.




23

∆Ɵ

∆V

Ɵ

E1E1VT

V'T

∆V'

(a) (b)

Fig. 9. Internal and terminal voltage phasors (a)

before opening with CB (b) after opening with CB

This variation of the cycle duration results

in a proportional variation of the terminal voltage

angle, which is the input parameter of VS relays. If

the variation of the terminal voltage angle exceeds

a predetermined threshold, a trip signal is

immediately sent to the CB. Usually [9], VS relays

allow this angle threshold to be adjusted in the

range from 2 to 20. The relay is also disabled if the

magnitude of the terminal voltage drops below a

threshold value to avoid false operation. To avoid

false operation, ROCOF and VS relays are disabled

if the terminal voltage decreases below a

determined voltage threshold. Showed that

ROCOF relays require a smaller active power

imbalance level than VS relays for successful

islanding detection. On the other hand, ROCOF

relays are much more susceptible to false

operation than VS relays

6. PROPOSED TECHNIQUES

Integrations of Distributed Generations

(DGs) in the distribution network is expected to

play an increasingly important role in the electric

power system infrastructure and market. As more

DG systems become part of the power grid, there

is an increased safety hazard for personnel and an

increased risk of damage to the power system.

Despite the favorable aspects grid-connected DGs

can provide to the distribution system, a critical

demanding concern is islanding detection and

prevention [12].

The traditional design and operation of

electricity distribution networks and their

associated protection and (limited) control

systems always assumed power flows from higher

voltage networks to lower voltage networks (i.e.

the networks were passive in nature). However, in

active distribution networks, the connection and

operation of significant distributed energy

resources (of varying technologies) and energy

storage devices alters many network

characteristics, making the existing assumptions

relating to network design, operation, control and

protection less applicable.

There are many characteristics of active

distribution networks that differ from a typical

passive distribution network, such as bi-

directional power flows, high fault level

variability, converter-interfaced generation,

incorporation of energy storage and so on. These

factors, and many others, have led to significant

research efforts being expended towards

addressing problems associated with the

operation, control and protection of future

networks with large amounts of embedded

generation (much of which will be powered by

renewable sources). However, one of the main

obstacles to future development, from a power

system protection perspective, is to ensure that

anti islanding or loss of mains (LOM) protection

operates effectively with respect to the criteria of

sensitivity and stability [9].

This specific issue represents the main

focus of this paper. The Islanding Relays are highly

sensitive in nature and immediately trip the

circuit when detect a small disturbances, Due to

this unwanted nuisance tripping will happened

continuously, To avoid this nuisance tripping, 2

seconds delay is initiated in the relay circuit to




24

restore the actual parameters. This new approach

is given in the proposed method as shown in

Figure 10. And the point of common coupling was

changed to speed up the total process [14].

Time

Time to

detect Fault

Contact

Parting Time

Time taken to detect Islanding by

Local methods

Local methods

Remote Method

New

Method

Fault Detected by

circuit breaker

Circuit Breaker

opens up

= Total Islanding

Detection times

Fig. 10. Time taken for Different Islanding

Techniques

The (PCC) parameter are measured nearer

(PCC) to the grid side, when islanding happened

after a particular time the relays are energised and

doing the islanding operation, in between the

network values are restored the unwanted tripping

is avoided [15]. The new monitoring point is shown

in the Figure 11.

PCC

Monitoring pont of new approach

Ciruit Breaker

Load

GRIDDG

Fig. 11. Monitoring Parameters advanced position

The new algorithm was devolped and

implimented in different controllers to control the

isalnding detection under hybrid topology [16]. If

multiple DGs are connected in a network the

controller should compare all source parameters

with Grid parameters symaltaniously [17]. Here a

single source with Gris monitoring and controlling

algorithm[18] is shown in Figure 12.

start

Read Voltage and

Frequency

If V > 239 If F > 52

If V < 210 If F < 48

Initiate 2 sec

delay to the

Circuit breaker

to eliminate

nuisance

tripping

Do islanding

Dont make Islanding

If V and F

2 times > rated

value

Fig. 12. Hybrid islanding algorithm

8. SIMULATION RESULTS

The LabVIEW simulation results

with the impact of change in parameters of DER is

discussed below, the under voltage/Over voltage,

Under Frequency/Over frequency waveforms [13]

are recorded and displayed. When the connected

sources are in healthy condition, all the circuit

breakers will be in normally closed position and the

LabVIEW front panel indicators will be in green as

shown in Figure 13.

Fig. 13. DER parameters in normal conditions




25

The output voltage of the wind mill during

feasible condition is shown in Figure 14.

Fig. 14. Wind mill output in feasible Levels

Fig. 15. Functional diagram of LabVIEW in DER

The function diagram of LabVIEW

build with numerous functions is shown in Figure

15. When any one of the connected source

parameter is deviated from the IEEE standard value

[3] (under/over voltage or under/over frequency),

the corresponding circuit breakers will get opened

and the respective source will turns to islanded

mode, the consequent source parameter indicators

will be in warning mode. After two seconds of time

delay the parameters are not restored the normal

value, the LabVIEW front panel status indicators will

be in RED as shown in Figure 16.

Fig. 16. DER parameters in islanding conditions

The recorded parameters of the distributed

energy resources under various circumstances are

listed in the Figure 17. The fundamental

frequencies of the connected sources are shown in

the Figure 19.




26

Fig. 17. Recorded DER parameters

Fig. 18. Fundamental Frequencies in DER

The harmonics are developed in the

Distributed Network with numerous reasons. The

harmonics of the connected resources are shown in

the Figure 19. And the Total Harmonic Distortion

(THD) of the network is calculated and the value is

displayed in the Figure 17, the graphical

representation is given in the Figure 20.

Fig. 19. Distributed Energy Resources Harmonics

Fig. 20. Total Harmonics Distortion of DER

7. CONCLUSION

From the simulation results the design

and analysis of Distributed Generations leads a

new dawn to the power quality issues. The

Distributed Generations has lot of benefits to

modern power system. The protection scheme of

DER is a serious issue in many interconnection

sessions. In this new approach, initiates a certain

time delay to the relay circuit and the reliability of

system can improved by avoiding unwanted

tripping. As the LabVIEW is a versatile tool in

monitoring and control the modern power system,

the different parameters of DER in various

environments is discussed.

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[2] A. V. Timbus, R. Teodorescu, and P.

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on Active Power Variations and Grid Voltage

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[3] Thomas S. Basso, Member, IEEE and Richard

DEBLASIO, Senior Membe, IEEE. “IEEE 1547

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[4] Pukar Mahat, Zhe Chen, and Brigitte Bak-

Jensen, “Review of islanding detection methods for

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Power Technologies (DRPT), pp. 2743-2748, April

2008.




27

[5] V. Menon, and M. H. Nehrir, “A hybrid

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