Design a Centralized Protection Scheme in Micro-gride Power Systems
MOSTAFA I.SALEH1 , GABER EL-SAADY2, ALI M. YOUSEF3, EL-NOBY A.IBRAHIM4
1Alfanar Testing and commissioning
, Alfanar Company,
Mecca, SAUDI ARABIA
2Electrical Engineering Department,
Faculty of Engineering, Asyut University,
Asyut, EGYPT
3Electrical Engineering Department,
Faculty of Engineering, Asyut University,
Asyut, EGYPT
4Electrical Engineering Department,
Faculty of Engineering, Asyut University,
Asyut, EGYPT
Abstract: —Distributed generators is now widely used in electrical power networks, in some cases it works
seasonally, and some types works at special weather conditions like photo voltaic systems and wind energy, and
because of this continuous change in generation condition which requires adaptive protection system that can
adaptive its setting according to generation changes , central protection unite can be used to control the active
setting group of protection relay according to generation capacity, a proposed method for selecting suitable backup
relay is used, which leads to decrease relays tripping time and increase system stability .
Key-words: —Directional overcurrent relay, protection coordination, Distributed generators, central protection
unite, multiple setting group protection relay.
Received: March 23, 2024. Revised: September 3, 2024. Accepted: September 23, 2024. Published: October 17, 2024.
1. Introduction
Due to increase of using DG in power networks and
the diversity in renewable energy resources, new
optimal protection relay settings need to be considered
in order to keep power system stability. [1]
Some types of DG can be used according to loading
conditions, it can be used at summer only or at rush
hours, also some types can work at daylight like PV
systems; therefore, protection system should be adaptive
to generation condition and should be flexible to system
status.
When a micro-grid is connected to power network,
the configuration is changed to a complicated multi-
source power system, fault currents and fault levels need
to be recalculated and power ratings of protection
equipment’s should be rearranged accordingly, the
protection of microgrid should be in such a way that a
safe and secure protection is provided in both grid-
connected and stand-alone operation modes. [2][3]
Modern multifunction digital relays have a number
of features, which make them an ideal choice for
interconnection protection of dispersed generators. The
most important of these features are user-selectable
functionality, self-diagnostics, communications
capabilities and Oscillo graphic monitoring.[4]
A multiple setting group protection relay has the
ability to change setting locally with selector or remotely
through communication system, as it has the ability to
move between up to eight different setting groups. [5]
Central protection unites communicates with every
network component such as breaker status and relay
setting and each new connection/disconnection is
reported to it. Therefore, Central control unites has the
ability to extract the current state of the network, list the
connected entities and choose a proper relay setting. [6]
The optimum settings of DOCRs need to be
determined for all groups. Here, the major task is to
obtain values of TMS of DOCRs suitable for proper
protection coordination under all the topologies
considered in each group. This can be done by
considering all the primary-backup relay pairs of all the
topologies of a group so that the obtained optimum
values of TMS can coordinate properly in these
topologies.[7]
2. Microgrid Central protection unite
Microgrid Central Protection Unit (MCPU)
communicates with every single relay and distributed
International Journal of Electrical Engineering and Computer Science
DOI: 10.37394/232027.2024.6.24
Mostafa I. Saleh, Gaber El-Saady,
Ali M. Yousef, El-Noby A. Ibrahim
E-ISSN: 2769-2507
203
Volume 6, 2024
generator in the microgrid. The communication with
relays is necessary to update the operating currents of
the relays and to detect the direction of fault currents
and thus isolate the fault properly. DGs, on the other
hand, are monitored to follow their status and
include/disregard their fault contribution if they are
ON/OFF, respectively. [3]
MCPU is used in some studies to be responsible of
calculation of tripping currents, time delays (optional)
and updating of relay operating point [8] and [2], On the
other side, in another study, the programmable scheme
logic in modern multifunctional protective relays is
used, its an extremely powerful tool that allows the user
to adapt the relay logic to very different applications or
to change system conditions[9], while in our study all
tripping currents and time delay at different operating
cases will be stored in relay at different setting group,
MCPU will choose optimal setting group needed
according to generation capacity.
Our proposed MCPU shown in figure 1 doesn’t need
to be updated with system current and voltage, just it
will supervise if any change happens in circuit breakers
status, if any change is noticed in system, MCPU will
send signal to all DOCRs and select suitable setting
group to be activated in such case.
With the wide use of optic fiber communication in
distribution grid, it is practicable to achieve MCPU
logic for microgrid [10].
One of the most important advantage in our
proposed MCPU, all relays will be restored to default
setting group, in case of communication fail between
MCPU and relays or breakers and in case of any fault
happed, relay will send trip signal to breaker.
G
G
2
14
1
8
BUS 2
4
13 6712 511
9310
BUS 1 BUS 3 BUS 4
BUS 5 BUS 6
BUS 7
BUS 8
GRID
DGs BUS
WTG
PV
15
17
16
18
20
19
R4
R1
R2
R9
R3
R10
R5
R12
R6
R13
R8
R1 R7
R14
MCPU
R
SIGNAL FROM MCPU TO DOCR
CB STATUS SIGNAL TO MCPU
DOCR
HV CB
Fig. 1. Micro gride central protection unite
3. Protection relay coordination
In order to keep the system stable under any fault
condition, protection relay should isolate faulted area in
the instance of fault occur, if this relay fails to operate
under any condition, nearest relay to faulted zone should
operate as a backup relay.
Earlier studies in directional over current relay
(DOCR) coordination was using protection relay fixed
with single setting group [11].
For multiple setting protection relay, the function of
relay to act as primary or backup depends on the
direction of fault current, each multiple setting DOCR
has many set of independent relay settings we can use
one for forward direction as a primary relay and another
one in reverse direction of fault current as backup relay
[12].
4. Proposed and Conventional Back-
up Relay Selection
The difference in coordination between the primary
back-up relay pairs for proposed and conventional back
up DOCR is shown as in Fig. 2.
Conventional
backup Relay
Primary Relay
i
F1
proposed
backup Relay
jk
Fault current direction Fault current direction
Fig. 2. Primary and back-up relays of distribution
system.
Figure 2 shows apart of IEEE 8-bus system, in case
of occurrence of a fault at the point f1, the relay (i) acts
as primary relay which should operate to isolate the
fault, if this relay fails to operate and after a certain time,
another relay should operate as a backup relay this
backup relay will be as follow: -
- In case of conventional single setting DOCR the
relay (j) should operate after a time delay, this
time delay called coordination time interval
(CTI) , therefore the tripping time of relay (j)
should be more than of relay (i) with this value
of CTI which leads to increase total tripping
time of relays
- In case of proposed multiple setting DOCR the
relay (k) will switch to setting group (2) and
work as a backup relay and will operate after
CTI and this will keep setting group (1) for the
International Journal of Electrical Engineering and Computer Science
DOI: 10.37394/232027.2024.6.24
Mostafa I. Saleh, Gaber El-Saady,
Ali M. Yousef, El-Noby A. Ibrahim
E-ISSN: 2769-2507
204
Volume 6, 2024
condition of occurring fault in the zone of relay
(k), in this case relay J will be primary relay.
Therefore, the reverse side of each relay is deployed
as the backup relay for the next front line where in our
case according to fault direction relay (k) will select
setting group for forward fault current relay will work
according to setting group (1) and reverse direction fault
current the relay will work according to setting group
(2).
To avoid the operation of relay (j), a communication
link is considered to send a block signal on behalf of
relay (k) reverse [13].
5. DOCR Coordination Principles
Using Single and Multiple Setting
Protection Relay
The operating time of inverse definite minimum time
relay IDMT is obtained according to IEEE standard
C37.112- 1996: - [14]
2
28.2 0.1217)
( ) 1
(
ii
fi
pi
t TDS I
I
(1)
Where
ti: The operating time of relay (i) (tipping time)
IF : The fault current passing through relay (i)
IP: The pickup current of relay (i)
TDSi: Time multiplier setting of relay (i)
The value of the pickup current of a relay (i) should
be less than the minimum value of the fault current at
this point [15].
Furthermore, the time dial setting TDSi of relay i is
ranged from 0.1000 to 1.1000 [16].
CTI value ranges from 0.2 to 0.3 sec. In this paper
0.2 sec value is chosen [17].
In case of using conventional DOCR our object
function will be :-
󰇛󰇜
 [18]
In this case we need to get the optimal values of
pickup current and TDS values of each relay.
While in case of using proposed multiple setting
DOCR , each relay will be installed with two different
setting , first one will be used at forward fault and
second setting group will be used in reverse direction
faults and object function will be as equation :-
󰇛󰇜 󰇛 
 󰇜
In this case the parameters which need to be
optimized for each relay will be duplicated, where two
values of pickup current and TDS is needed to each
relay.
6. Under Study System
To study the effect of using multiple setting DOCR
in micro-grid systems IEEE 8-bus test system is used,
and in order to clarify our study, two different types of
distributed generator (DG) is connected at bus-2, first is
photo voltaic (PV) system and second is wind turbine
generator (WTG).
All data of our studied IEEE 8-bus test system taken
from [19], the data for proposed DGs available at [20]
To get the value of maximum short circuit current
sensed at each relay on the system, system is simulated
using Etap software, for simplicity the values of pickup
current of each relay is considered constant and taken
from [14].
Grey Wolf Optimizer (GWO) [21] algorithm is
developed using MATLAB software to achieve optimal
TDS values.
7. Study Methodology
IEEE 8-bus system is simulated using Etap software,
our study will be concentrated only under three different
cases shown in table (I) and figure 3 : -
Case-1 CB-15 is opened, which means no DGs is
connected at bus-2.
Case-2 CB-15 is closed, CB-16 is closed and CB-17
is opened, in this case PV system connected at bus-2.
Case-3 CB-15 is closed, CB-16 is opened and CB-
17 is closed, in this case WTG system connected at bus-
2.
Fig. 3. DGs connected at bus-2 of IEEE 8-bus test
system
TABLE I. IEEE 8-BUS SYSTEM STUDY CASES
CB
Case-1
Case-2
Case-3
CB-
15
open
close
close
Corresponding author: at testing and commissioning
engineering section, Western region, Alfanar
Company, Saudi Arabia
(mostafa09368@eng.aun.edu.eg) Tel:
+966562628469
International Journal of Electrical Engineering and Computer Science
DOI: 10.37394/232027.2024.6.24
Mostafa I. Saleh, Gaber El-Saady,
Ali M. Yousef, El-Noby A. Ibrahim
E-ISSN: 2769-2507
205
Volume 6, 2024
CB-
16
open
close
open
CB-
17
open
open
close
Syste
m
Without
DGs
PV
connected
WTG
connected
For the three different cases the maximum fault
current sensed by each relay is calculated with ETAP
and the results is shown in table (II), moreover the
conventional and proposed backup relays also
considered in study as in table (III).
TABLE II. MAXIMUM FAULT CURRENT FOR
IEEE 8-BUS SYSTEM FOR DIFFERENT CASEES
Primary Relay
Fault current
(A)
Conventional
Back-up relay
Proposed
Back-up relay
Fault
current(A)
Case-1
Case-2
Case-3
Case-1
Case-2
Case-3
1
323
2
35
08
41
71
6
13
32
32
32
32
323
2
8
617
7
62
44
64
54
9
2
11
60
11
73
121
5
8
617
7
62
44
64
54
7
14
19
03
19
56
212
4
2
602
0
62
01
67
61
1
8
10
03
11
13
152
2
9
246
7
25
11
26
14
10
3
24
67
25
11
261
4
2
602
0
62
01
67
61
7
14
19
03
19
56
212
4
3
354
7
36
53
38
99
2
9
35
47
36
53
389
9
1
0
387
4
39
51
41
19
11
4
23
35
24
11
257
9
6
619
5
62
54
64
46
5
12
11
93
12
05
124
3
6
619
5
62
54
64
46
14
7
18
87
19
35
208
9
1
3
298
8
32
64
39
27
8
1
29
88
29
88
298
8
1
4
527
7
54
18
58
52
9
2
11
60
11
73
121
5
7
530
2
54
48
59
08
5
12
11
93
12
05
124
3
1
4
527
7
54
18
58
52
1
8
10
03
11
30
152
2
7
530
2
54
48
59
08
13
6
99
4
11
29
155
1
4
377
2
38
43
40
01
3
10
22
33
23
03
246
1
1
1
370
3
38
16
40
85
12
5
37
03
38
16
408
5
5
238
5
24
25
25
21
4
11
23
85
24
25
252
1
1
2
599
0
61
78
67
54
13
6
99
4
11
29
155
1
1
2
599
0
61
78
67
54
14
7
18
87
19
35
208
9
TABLE III. CONVENTIONAL AND PROPOSED BACKUP
RELAYS FOR IEEE 8-BUS SYSTEM
Prima
ry
relay
no.
Conventiona
l
Backup
relay no.
Proposed
Backup
relay no.
1
6
13
2
1
8
2
7
14
3
2
9
4
3
10
5
4
11
6
5
12
6
14
7
7
5
12
7
13
6
8
9
2
8
7
14
9
10
3
10
11
4
11
12
5
12
13
6
12
14
7
13
8
1
14
9
2
14
1
8
8. Results and Discussion
GWO algorithm used to get optimal TDS value for
each relay at different cases and the result TDS values
in case of using conventional backup relays is shown
in table (IV), while in case of using proposed backup
relay, every relay will be installed with two different
TDS per case, which means every relay will be installed
with 6 six different setting groups as in table (V), while
in conventional backup relay only three setting group
needed per relay because same value of TDS will be
used in case of primary and backup protection .
Using the TDS values from table (IV) and (V), the
value tripping time for primary and backup relays is
calculated in case of conventional and proposed backup
relays at the three different cases and shown in tables
(VI) and (VII).
International Journal of Electrical Engineering and Computer Science
DOI: 10.37394/232027.2024.6.24
Mostafa I. Saleh, Gaber El-Saady,
Ali M. Yousef, El-Noby A. Ibrahim
E-ISSN: 2769-2507
206
Volume 6, 2024
From table (VI), it can be noted that primary relays
tripping time in case of using proposed backup relay is
less than its values when using conventional backup
relay, as in table (VI) trip time is reduced by 33,35 and
37 % for case-1, case-2 and case 3 respectively, which
increases system performance in decreasing total
tripping time.
G
G
2
14
1
8
BUS 2
4
13 6
7
12 511
9310
BUS 1 BUS 3 BUS 4
BUS 5 BUS 6
BUS 7
BUS 8
GRID
Fig. 4. IEEE 8-bus test system
Fig. 5. IEEE 8-bus test system simulation using ETAP
TABLE IV. IEEE 8-BUS TEST SYSTEM TDS VALUES
USING GWO WITH CONVENTIONAL BACKUP RELAYS
Rela
y no.
`TDS value
Case-1
Case-2
Case-3
1
0.10001
0.10003
0.10002
2
0.21702
0.23003
0.2615
3
0.22237
0.23439
0.2626
4
0.10896
0.11113
0.11634
5
0.1
0.10001
0.1
6
0.38496
0.36599
0.33468
7
0.10451
0.11259
0.13145
8
0.35545
0.33329
0.29986
9
0.1
0.10001
0.1
10
0.29295
0.29778
0.30944
11
0.1776
0.18802
0.2122
12
0.55267
0.58186
0.64994
13
0.1
0.1
0.10001
14
0.10011
0.10003
0.10042
Rela
y
setti
ng
grou
p
Setti
ng
grou
p (1)
Setti
ng
grou
p (2)
Setti
ng
grou
p (3)
TABLE V. TDS OF RELAYS FOR IEEE 8-BUS TEST
USING GWO WITH PROPOSED BACK UP RELAYS
Relay no.
` Case-1
Case-2
Case-2
primar
y
Backu
p
primar
y
Backu
p
primar
y
Backu
p
1
0.100
1
0.253
1
0.100
2
0.238
12
0.100
38
0.214
32
2
0.100
9
0.1
0.100
5
0.1
0.112
39
0.1
3
0.100
6
0.292
9
0.103
2
0.623
54
0.100
07
0.309
54
4
0.100
1
0.1
0.1
0.1
0.100
01
0.100
02
5
0.1
0.327
2
0.1
0.339
18
0.100
04
0.369
34
6
0.141
0.1
0.107
6
0.1
0.102
06
0.100
02
7
0.101
7
0.100
1
0.100
1
0.1
0.100
04
0.1
8
0.100
1
0.1
0.120
3
0.1
0.150
43
0.1
9
0.1
0.283
8
0.100
1
0.297
16
0.100
01
0.321
95
10
0.101
1
0.214
4
0.100
1
0.224
22
0.109
85
0.246
81
11
0.100
2
0.198
8
0.100
1
0.202
06
0.100
01
0.210
29
12
0.118
1
0.1
0.102
8
0.1
0.101
69
0.1
13
0.100
1
0.278
0.100
1
0.263
86
0.100
07
0.241
2
14
0.101
7
0.100
1
0.100
1
0.100
01
0.100
72
0.1
Relay setting
group
Setting group
(1)
Setting group
(2)
Setting group
(3)
Setting group
(4)
Setting group
(5)
Setting group
(6)
International Journal of Electrical Engineering and Computer Science
DOI: 10.37394/232027.2024.6.24
Mostafa I. Saleh, Gaber El-Saady,
Ali M. Yousef, El-Noby A. Ibrahim
E-ISSN: 2769-2507
207
Volume 6, 2024
9. DOCR Setting Group Control
Using MCPU
Now, after getting the optimal TDS values for all
relays, every relay will be programmed with six
(proposed backup relay method) or three different
setting groups (conventional backup relay method),
MCPU in figure 1 is used to supervise the CBs
condition as in table I and upon this condition, MCPU
will chose suitable setting group and make it active
through communication link with all relays, Fig. 6
shows flow chart of our study in case of using proposed
backup relay method, MCPU will keep connected with
system until detecting any change of CB15, CB16 and
CB17, and upon this change it will change setting group
according to table (V).
TABLE VI. PRIMARY RELAYS TRIPPING TIME
FOR IEEE 8-BUS SYSTEM
Relay NO.
` Case-1
` Case-2
` Case-3
Conventi
onal
proposed
Conventi
onal
proposed
Conventi
onal
proposed
1
0.112
8
0.112
8
0.097
1
0.097
3
0.071
7
0.072
0
2
0.136
4
0.063
4
0.137
7
0.060
1
0.136
5
0.058
6
3
0.154
1
0.069
7
0.154
7
0.081
2
0.155
7
0.059
3
4
0.157
9
0.145
0
0.155
4
0.139
9
0.150
7
0.129
6
5
0.202
7
0.202
7
0.196
0
0.196
0
0.181
4
0.181
5
6
0.118
0
0.043
2
0.110
9
0.032
6
0.097
8
0.029
8
7
0.050
9
0.049
5
0.052
6
0.046
8
0.054
6
0.041
5
8
0.109
3
0.030
7
0.101
2
0.036
5
0.087
5
0.043
9
9
0.189
4
0.189
4
0.182
9
0.182
9
0.169
0
0.169
0
10
0.175
5
0.060
5
0.172
9
0.058
1
0.168
1
0.059
6
11
0.156
6
0.088
3
0.157
2
0.083
7
0.157
7
0.074
3
12
0.176
6
0.037
7
0.178
9
0.031
6
0.180
0
0.028
1
13
0.130
6
0.130
7
0.110
7
0.110
8
0.079
5
0.079
6
14
0.078
5
0.079
8
0.075
0
0.075
0
0.066
1
0.066
3
Total trip
time
1.950
7
1.304
1
1.884
1
1.219
9
1.757
2
1.093
8
TABLE VII. BACKUP RELAYS TRIPPING TIME
FOR IEEE 8-BUS SYSTEM
Conventional back-
up
Proposed back-up
Case-1
Case-2
Case-3
TRIP TIME
(SEC)
Conventional
back-up
TRIP TIME (SEC)
Proposed back-up
TRIP TIME (SEC)
Conventional
back-up
TRIP TIME
(SEC)
Proposed back-
up
TRIP TIME
(SEC)
Conventional
back-up
TRIP TIME
(SEC)
Proposed back-
up
1
8
1.5
83
0.9
44
1.1
67
0.7
25
0.5
31
0.3
53
2
9
0.3
54
0.2
70
0.3
54
0.2
68
0.3
55
0.2
59
3
10
0.3
58
0.3
45
0.3
55
0.3
40
0.3
50
0.3
29
4
11
0.4
02
0.4
02
0.3
96
0.3
96
0.3
81
0.3
81
5
12
0.9
66
0.6
13
0.9
41
0.5
98
0.8
68
0.5
56
6
13
0.3
13
0.3
13
0.2
97
0.2
97
0.2
72
0.2
72
7
14
0.3
38
0.6
17
0.3
43
0.5
78
0.3
37
0.4
78
8
1
0.3
32
0.3
30
0.3
11
0.3
11
0.2
80
0.2
80
9
2
1.0
42
2.5
69
1.0
11
2.4
64
0.9
21
2.1
70
10
3
0.3
89
0.3
89
0.3
82
0.8
01
0.3
69
0.3
69
11
4
0.3
75
0.3
87
0.3
72
0.3
61
0.3
68
0.3
12
12
5
0.3
56
0.2
88
0.3
57
0.2
83
0.3
57
0.2
74
13
6
1.6
28
0.9
67
1.1
22
0.7
00
0.5
08
0.3
39
14
7
0.6
30
0.3
29
0.5
93
0.3
12
0.4
98
0.2
65
Total Trip
Time
9.0
66
8.7
63
7.9
61
8.4
39
6.4
02
6.6
42
International Journal of Electrical Engineering and Computer Science
DOI: 10.37394/232027.2024.6.24
Mostafa I. Saleh, Gaber El-Saady,
Ali M. Yousef, El-Noby A. Ibrahim
E-ISSN: 2769-2507
208
Volume 6, 2024
MCPU
SYSTEM RUN
CHECK CB15
STATUS
CHECK FAULT
DIRECTION
CHECK CB16
STATUS
OPEN
CHANGE
DOCRs TO
SETTING GROUP
2
CHANGE
DOCRs TO
SETTING GROUP
1
FORWARD
REVERSE
CLOSE
CHECK CB17
STATUS
OPEN
CHECK FAULT
DIRECTION
CHANGE
DOCRs TO
SETTING GROUP
3
CHANGE
DOCRs TO
SETTING GROUP
4
CLOSE
FORWARD
REVERSE
CHECK FAULT
STATUS
CLOSE
CHANGE
DOCRs TO
SETTING GROUP
5
CHANGE
DOCRs TO
SETTING GROUP
6
FORWARD
REVERSE
OPEN
Fig. 6. IEEE 8-bus test system protection control using
MCPU
10. Conclusion
This paper presented effect of using MCPU in
microgrid, in case of connecting DGs, MCPU monitor
system status and changes relay setting group according
to generation capacity, while in case of taking fault
current directional in our consideration, a proposed
backup relay will be useful in decreasing relays tripping
time.
It’s found that MCPU is important in case of
presence DGs in system, MCPU will keep relay
coordination and protection stability at right way even if
changing fault current due to DGs connecting in
microgrid.
Our proposed MCPU was designed with simple rules
which doesn’t required a special system memory or data
processing unite, sense it depends only on a simple logic
in changing relay setting group according to DGs
connection in microgrid.
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Mostafa I. Saleh, Gaber El-Saady,
Ali M. Yousef, El-Noby A. Ibrahim
E-ISSN: 2769-2507
209
Volume 6, 2024
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research, at all stages from the formulation of the
problem to the final findings and solution.
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Scientific Article or Scientific Article Itself
No funding was received for conducting this study.
Conflict of Interest
The authors have no conflicts of interest to declare
that are relevant to the content of this article.
Creative Commons Attribution License 4.0
(Attribution 4.0 International, CC BY 4.0)
This article is published under the terms of the
Creative Commons Attribution License 4.0
https://creativecommons.org/licenses/by/4.0/deed.en
_US
International Journal of Electrical Engineering and Computer Science
DOI: 10.37394/232027.2024.6.24
Mostafa I. Saleh, Gaber El-Saady,
Ali M. Yousef, El-Noby A. Ibrahim
E-ISSN: 2769-2507
210
Volume 6, 2024