l .

Data Center 66/22 KV GIS S/S

For Mohamed Nagib Military Base

SECTION (LI )B
SUBSTATION CONTROL SYSTEM
 SUBSTATION CONTROL SYSTEM (Aiternative-2)

CONTENTS

Item Description Page

1. General 3

2. Work Included 4

3. Bay Level Requirements 4

4. Station Level Requirements 5

5. Functional Requirements 7

6. System Suppmt Functions 12

7. Configuration Tools 13

8. Uninterruptable power supply 14

9. Guarantee 14

10. Testing 14

11. Training 15

12. Spare Pmts 16

13. Submittal 16

Data Center 66/22 KV GIS S/S

For Mohamed Nagib Military Base Page 2 of 17
 SUBSTATION CONTROL SYSTEM (Aiternative-2)

1. General:
This part of the specification covers training, guaranty and the technical requirements for
design, engineering, delivery, installation, testing and commissioning of all necessary
equipment for Substation Automation System.
The Substation Control System shall be com1ected with the protection system & meters in such
a way to have a fully Automation System.
The Substation Control System shall monitor and control the entire substation and shall be
based on IEC 61850 standard protocol.
The Substation control system shall be suitable for the complete substation and any future
extensions.
The Substation Control system shall be based on a decentralized architecture and on the
concept of bay-oriented, distributed control constituted by intelligent electronics devices
(IEDs), connected by a LAN.
All IEDs (i.e. relays, feeder manager and BCUs) shall have dual optic fibre ports and shall be
connected to the LAN directly without any intem1ediate conve1ters or through another lED.
The maintenance, the modification or extension of the components shall not cause any collapse
of a part or the whole automation system.
The devices and fimctions of a substation automation system shall be installed and allocated on
two different levels; bay level and station level.
The flow of information between the bay level (Common BCU, FMs & relays) and the station
level shall be carried out by means of Ethernet network.
A loss of power shouldn't cause any loss of configuration data. After restoration of power the
system shall automatically start up again.
Contractor shall submit the SCS system firmware and the SCS applications firmware.
All software including configuration software, tools and SCS system software should be
submitted with its original copies on CD.
All software provided for the automation system shall be licensed to the Employer for an
unlimited time period.
All equipment (operator & engineering workstations, servers and gateways) which are on the
station level should be supplied together with its license (as dongle separately or any
Equivelant approved by EETC ) enabling EETC engineers to install the licence on similar
equipment in case of its failure or replacement
:rhe offered automation system shall supp01t monitoring and remote control :fi·om control centre
via gateways.
At station level, the entire station shall be controlled and supervised from the operator HMI. It
shall also be possible to control and monitor the bay from the bay level equipment.
All computers and communication equipment of the automation system shall be substation
grade and shall be compliant with IEC-61850-3 and IEEE 1613 enviromnental conditions.
All computers (i.e servers, workstations) should be installed inside desk cabinets with good
ventilation with front glass door.
All computers (i.e servers, workstations) should be in windows platform.
Bidder should submit at the technical evaluation stage the SCS configuration to be approved
with the redundant LAN using standard connection RSTP, PRP or combined (HSR is approved
for medium voltage only), Only approved SCS configuration will be considered in the contract.
The SCS systems offered will evaluated according to their pe1formance in EETC network.

Data Center 66/22 KV GIS S/S

For Mohamed Nagib Military Base Page 3 of 17
 SUBSTATION CONTROL SYSTEM (Alternative-2)

For the new SCS systems (4) year guarantee should be provided.
2. Work Included
Equipment to be installed in the control room , comprising redundant industrial servers with
application software, operator workstation, engineering workstations, printer, managed Ethemet
switches, gateways and GPS receivers, UPS, etc, to perform the specified supervision, control &
monitoring functions.
Remote control panels should cover all SLD and any future extensions bays (equipped or space)
For each 66 KV feeder, a combined control/protection Feeder Manager (FM) shall be
provided as a back-up protection for all feeders & the main protection for bus coupler
and mimic diagram with conventional control facilities.
Bidder may suggest (submit as an optional offer) any other special features based on his
research, development work and experience that may be of significant benefit to the overall
performance of the substation. Suggestions will be subject to EETC approval in case of Contract
(before contract signature).
Each one of the redundant Server, Gateway & switches should be installed in redundant
panels.

3. Bay Level Requirements

The bay level shall include the following:
Remote control panels including one Feeder Manager (PM) per bay and mimic diagram with
conventional control facilities.
Metering panel including smart energy meters as specified.
For MV switchgear, combined control/protection unit for each bay having dual optic fibre
ports and compatible with IEC 61850 standard protocol.
One (or more) common Bay Control Unit (BCU) shall also be provided to cater for the
miscellaneous and common signals and alarms not related to the switchgear equipment. The
contractor may install common BCU in the coupler remote control panel with the coupler FM.
Feeder Manager shall provide all bay level functions regarding control and monitoring.
Feeder Manager shall be equipped with analogue and digital input and output cards for
monitoring purposes, and digital output cards for commands.
Feeder Manager shall be directly connected to the switchgear without any need for additional
interposition.
Feeder Manager shall have display unit with sufficient resolution to display the single line
diagram, the associated alarm and measurements, make control and local events.
Each Feeder manager shall be independent from each other and its functioning shall not be
affected by any fault occutTing in any of the other feeder manager of the station.
Feeder manager shall have event & fault recording functions to be activated & to be sent to the
SCS & to be archived inside SCS.
The Feeder manager shall provide the following features, as minimum:
);> Operation of switchgear equipment.
);> Accesses to the transfotmer tap changer and cooling fan control... etc.
);> Status indication of switchgear equipment, measuring values, oil/winding temperature, tap
position, fan control (manual-automatic), tap changer (manual-automatic) and AVR
(ON/off) ... etc.

Data Center 66/22 KV GIS S/S

For Mohamed Nagib Military Base Page 4 of 17
 SUBSTATION CONTROL SYSTEM (Aiternative-2)

~ Initiating alatms in case of failure through a watchdog function.

~ Supervising the operation of breakers through Synchrocheck function.
~ Interlocking logic for relevant bay and horizontal interlocking with other BCUs.
~ Blocking of automatic reclosing.
~ Preventing simultaneous actuation of operating devices.
~ Automatic supervision of power supplies & position indications of breakers and switches.
~ Automatic supervision of breakers and switches operation and trip circuits complete with
circuit breaker diagnostics.
~ Time stamp all events using true GPS clock signal.
~ Phase discrepancy monitoring of the breakers.
~ Operation counter for each circuit breaker trip/closing operation together with tripping
opening currents to allow proper management maintenance.
~ Sequence of event storage (1 000 events at least).
~ Operations counter for each circuit breaker closing/opening.
~ Monitoring the operating time of motor driven switches.
~ Phase discrepancy monitoring of the breakers.
~ Test switch for commissioning & testing of all functions in the device.
~ Synchro-check function.
~ Password access should be available for all the FMs operation
Local/Remote selection switch should be provided to isolate remote operating facilities when
Feeder Manager control is selected.
In the event of power supply failure, the FM & BCU shall retain all parameter settings &
events recorder and functions by mean of non-volatile memory.
Dedicated bay control units shall be provided for substation common signals not relating to
switchgear equipment.
Intelligent metering system for energy (bidirectional MWH and MVARH) shall be provided
and connected to the LAN of the SCS. All meters shall have load profile function, reading
fi·eeze, and shall be able to store measured and calculated values.

4. Station Level Requirements

Station level equipment, to be installed in the control room, comprising the following:

4.1. Redundant LAN

A station LAN with Ethernet based on IEEE 802.3 and OSI TCPIIP shall be used to
interconnect the equipment at the station level. Necessary industrial type managed switches
shall be provided to inter connect the feeder manager, BCU, protection relays, meters and
other IEDs to the station servers.
Necessary industrial managed switches shall be provided to connect the IEDs to the station
servers.
Switches shall meet requirements ofiEC 61850 to allow interoperability.
Switches shall support substation hardened power supply with fail safe contact.
LAN speed should be 100 Mb/s at least for primary and redundant LAN.
The SCS system software should be identified.
Redundant managed switches should be used to manage the data in the redundant LAN (Star
topology)

Data Center 66/22 KV GIS S/S

For Mohamed Nagib Military Base Page 5 of 17
 SUBSTATION CONTROL SYSTEM (Aiternative-2)

KEMA Cettificate test 61850 as managed switch should be provided.

4.2. Redundant Station Controllers (station server I Gateway) (installed in the control room)
Station Controllers can be of a modem industrial type computer (without any moving pmts),
and shall have the supervisory and control function, the substation database and the
application programs.
Shall have the latest platform available.
Station Controllers shall work in hot-hot configuration; one automatically replaces the other in
case of failure.
Each Station Controller shall have the capacity to configure the whole substation equipment.
Each of the two redundant Station Controllers shall be accessed through redundant LAN.
The station controller shall fulfil the following minimum requirements:
~ Two independent non mechanical solid state drives (SSD)
~ RAID 1 option for SSD with capacity 1 Tera for each hard disk
~ Latest multi-core processors (> 2.6 GHz).
~ 8 GB RAM minimum.
~ Type test according to IEC 61850-3
~ 5 USB 2.0 potts
~ Redundant power supply
~ Up to 6 Ethemet potts
~ Option for 8 serial connections (RS232/RS485)
~ Option for fibre optic connection

4.3. Operation Workstation

One (1) workstation shall be provided for the operators. It shall be equipped with four 32 inch
LED monitors.
The workstation shall be dedicated industrial type computer (without any moving parts)
communicating via LAN with the station servers, running HMI software package which shall
contain supervisory control and data acquisition (SCADA) functions, under Windows
professional operating system and connected to both LAN.
The HMI shall display switchgear status by a customized overview and by detailed single line
diagrams which represent status, measured values, and transformer tap position.
Workstations desk should have enough space to accommodate 2 telephones, files.
A password should be used to use the operator workstation as system engineering workstation.
It shall be responsible for system configuration & editing, modification of the IEDs settings,
displays generation & modification & for the display of the disturbance recordings, editing &
modifYing database.

4.4. Redundant Gateways

The station logic should be functional over the substation controller gateway in order to keep
the station functioning even if all the station computers are malfunction.
Control centres shall be capable of monitoring the (switchgear status, measurements,
metering, event list, alarm list, fault record, etc) even if all the station computers are
malfunction.

Data Center 66/22 KV GIS S/S

For Mohamed Nagib Military Base Page 6 of 17
 SUBSTATION CONTROL SYSTEM (Aiternative-2)

Redundant gateways equipped with all necessmy hardwm·e and software shall be provided in
order to permit the control and monitoring of the substation from control centres, and each one
shall have two ports to communicate with each of the control centres.
Shall guarantee no loss of events in case of gateway switchover.
Redundant gateway should be equipped with an embedded industrial grade operation system
dedicated machine.
Each gateway should be provided with minimum ports:
);>Three other ports suppmt IEC 60870-5-104 for RCC & DCC.
The gateways shall support the following communication protocols:
);> IEC 60870-5-101
);> IEC 60870-5-104
);> IEC 60870-5-103
);> IEC 61850
);> DNP3
);> MODBUS
);> Any other protocol used in NECC & RCC for the communication with the gateway.

4.5. GPS receiver

A Global Positioning System (GPS) receiver shall be provided for the synchronization of all
relays, energy meters and multi measuring devices and to be connected to SCS LAN.
The receiver should have an outdoor antenna which must be installed in a proper location
connected with a suitable coaxial cable length.
The accuracy of the synchronization in the system shall be better than 1 msec.
Time synchronization shall be petformed via master clock which shall be cotmected to the
station bus and supporting equipment and the GPS receiver shall provide two (NTP/SNTP)
ports for redundancy, ill.JG-B port and 4 PPS ports.
The station controller and equipment shall be synchronized by direct GPS connection and
each device with suitable intetface.
The time stamp shall be transferred through the relevant system component as integral part of
the event information.
Upon failure of GPS receiver in the time synchronization system, the GPS receiver shall
activate an alatm to both the HMI and SCADA and common alarm panel.
The receiver should have an outdoor antenna which must be installed in a proper location.
Installed in 19" rack panel.

4.6. Printers
High-speed colour laser printer shall be provided for repotts printing can be accessed by any
of the workstations.
A printout of each display shall be possible on the hard copy printer.

5. Functional Requirements
5.1. User access levels
To minimize the risk, which might be caused by unauthorized access, the system must be
password protected. Different groups of users with different authorities shall be definable, e.g.
for monitoring only, for monitoring and control, for configuration, or for supervision.

Data Center 66/22 KV GIS S/S

For Mohamed Nagib Military Base Page 7 of 17
 SUBSTATION CONTROL SYSTEM (Aiternative-2)

The access rights shall be defmed by passwords assigned during the log-in procedure. Only
the system administrator shall be able to add/remove users and change access rights.
For more Security, it is also recommended to make access by hardware dongle.

5.2. Control hierarchy

- The high-voltage equipment within the substation shall be operated fi·om different places,
selector switches should be provided to allow the following operation hierarchy:
Local control panel.
Conventional control (switches on mimic) (installed on the Remote Control Panel)
Feeder manager (FM) (installed on the Remote Control Panel)
Operation workstation (HMI)
Remote control centres ( RCC & NECC via soft switch)

The medium-voltage equipment within the substation shall be operated fi·om different places:
One selector switch should be provided and installed on the 22 KV cubicle with
Local/Remote to allow the control for 22 KV cubicle or HMI.
M. V switchgear
Feeder manager device
Operation workstation (HMI)

Operation shall be only possible from one control level at a time. The priority shall always be
on the lowest enabled control level.
It shall be possible to open the selected Circuit Breaker with a push button in case of
emergency.
The operation level having currently the proper authority to control the switchgear in addition
the transformer facilities such as (tap changer and cooling fans ... .etc.) shall be indicated at the
HMI screen and the control centre. A change in control authority shall be logged in the event
list.
The HMI Should also have an option of Synchrocheck By-Pass and indication for
Synchrocheck selection switch (Auto/ Manual)

5.3. Monitoring of Switching Devices Status

The positions of circuit breakers, isolators, eatthing switches, transformer facilities such as
(tap position, fan control (manual/automatic), tap changer (manual/ automatic) and A VR
(ON/off) .. ...etc) shall be supervised continuously, and displayed in the single line diagram on
the station HMI.
Every detected change of position shall be recorded in the event list.
Alatms shall be initiated in the case of spontaneous position changes.

5.4. Measming and Metering Values Monitoring

The actual and calculated measured values of voltage (KV), cunent (Amp), active power
(MW), reactive power (MVAR), apparent power (MVA), Tap changer position, MWH,
MVARH ... etc
All measured and calculated values (MW, MVAR, MVA, Amp, P.F, Hz, Tap changer
position, MWH, MVARH . ... etc.) shall be displayed on the single line diagram.

Data Center 66/22 KV GIS S/S

For Mohamed Nagib Military Base Page 8 of 17
 SUBSTATION CONTROL SYSTEM (Aiternative-2)

5.5. Control of Switching Devices

In order to ensure a high degree of security against undesired operation, a "select before
execute" command procedure shall be provided in the BCU & in the working station.
No more than one command shall be executed at the same time.
After command execution the operator shall receive a confirmation that the new switching
position has been reached or that the switching procedure was unsuccessful with the indication
of the reason for non-functioning.
A new command may not be released before the previous one has been executed or cancelled.

5.6. Interlocking
A comprehensive interlocking system shall be provided.
The interlocking scheme shall be implemented locally in the IEDs, and also centrally in the
station controller.
Station wide interlocking shall be done using IEC 61850 mechanisms between the IEDs.
The station wide interlocking shall also be available when the station computer fails.
HMI Page for interlocking table is required and interlock reason display for each equipment
interlock

5.7. Automatic Switching Sequences

The available automatic sequences in the system should be listed and described, (e.g.
sequences related to the bus transfer).
It shall be possible to initiate pre-defined automatic sequences by the operator and also defme
new automatic sequences.

5.8. Alarm Management

Faults and errors occulTing ill the substation shall be listed in an almm list and shall be
immediately transmitted to the control centre.
The alarms shall be blinking until their acknowledgment. During this phase the system shall
produce a sound alarm, turned off with the acknowledgment.
Alarms are generated either by the switchgear, by the IED, or by the station level unit. They
shall be recorded in a separate list and appear on the screen.
The almms shall be time tagged.
The alarms shall be grouped in categories of priorities associated to a colour; groups and
colours can be customized. Filters for selection of a certairt type or group of almms shall be
available.
The list of signal shall be defined during the project and shall be agreed with the Employer.
Communication faults, errors in network shall be listed in separate alarm list.
Almm lists should have ability to insert a comment by the operator.

5.9. Recording Measured data:

All monitored data should be recorder for each bay each 1 hour for 60 days as minimum and
to be archived in the station server as follows:
-Volt
-Ampere

Data Center 66/22 KV GIS S/S

For Mohamed Nagib Military Base Page 9 of 17
 SUBSTATION CONTROL SYSTEM (Aiternative-2)

-MW
- MVAR
-MVA
- MWH
-MVARH
- Frequency
- Power Factor
-Transfmmer oil temperature
-Transformer windings temperature
- SF6 status for CB compatiment
- SF6 status for GIS compartment.
- Volt should be recorded in case of± 10% voltage level.

5.10. Event Recording and Management

The event recording shall be carried out by acquiring the information from the field through
the lED which will communicate with the server of the substation.
The event list shall contain events that are important for the control and monitoring of the
substation.
Events are generated either by the switchgear, by the lED, or by the station level unit. They
shall be recorded in a separate list and appear on the screen.
The events shall be time-tagged.
The operator shall be able to call up the clu·onological event list on the monitor at any time for
the whole substation or sections of it.
The list of signal shall be defmed during the project and shall be agreed with the Employer.

5.11. Disturbance Recording

The disturbance recording shall be carried out by acquiring the information from the field
through the lED which will communicate with the server of the Substation Automation
System.
The disturbance recorders should be gathered from all IEDs (i.e relays & FM).
The list of signal which will constitute the disturbance information shall be defmed during the
project and shall be agreed with the Employer.
It will allow to the identification of the type and intensity of disturbance and to the monitoring
of protection.
The ability to edit the list of signals according to substation needs in the future by the operator
shall be provided.

5.12. Fault Recording and Fault Location

The workstation shall have a user friendly tool for the analysis of fault records.
The localization offaults shall be carried out acquiring the infmmation from the field through
the lED which will communicate to the server of the substation.
It shall allow the identification of the type of fault and its distance fi:om the substation.

Data Center 66/22 KV GIS S/S

For Mohamed Nagib Military Base Page 10 of 17
 SUBSTATION CONTROL SYSTEM (Aiternative-2 )

5.13. Reporting
The system shall supp01t creating and printing user-defmed reports.
The layout shall be user defmed; a print preview shall ease the design. Printing of pre-defmed
repmts can be initiated by events, time schedules, or by the operator.

5.14. Trend Display

It shall be possible to illustrate all types of process data as trends - input and output data,
binary and analogue data.
The trends shall be displayed in graphical form as column or curve diagrams. Adjustable time
span and scaling ranges must be provided.

5.15. Archiving of Data

The memory management shall be configurable by the operator to modifY the time period for
recording. Software tools shall be available to expmt data from the database to a mass
memory to keep a copy of all historical data.
The HMI is to store historical data continuously with a time interval user-defmable in the
database. The archived data shall cover measured and metered values.
The management and the size for the database shall be configurable by the operator.
It should have the ability to make daily backup from the system and its database. In case of
emergency failure to ease restoring data using External storage media.
Archiving disturbance histmy for query purpose.

5.16. Time Synchronization

Time synclu·onization shall be performed via master clock which shall be connected to the
station bus (NTP/SNTP).
The station controller shall be synclu·onized by direct GPS connection.
The time stamp shall be transferred through the system as an integral part of the event
information.
Upon failure of GPS receiver in the time synchronization system, the GPS receiver shall
transmit an alarm to both the HMI and SCADA.

5.17. System Engineering

- The engineering workstation shall be used for the following purposes:
System configuration
System testing
Help functions
Downloading and uploading of applications
System commissioning
Database management
It shall be possible to access all IEDs for reading the parameters (settings) from the
engineering workstation.

5.18. Process Visualization (HMI)

HMI shall have graphic displays for the entire switchgear bays as well as for each individual
bay fmming the interface between the operator and the automation system.

Data Center 66/22 KV GIS S/S

For Mohamed Nagib Military Base Page 11 of 17
 SUBSTATION CONTROL SYSTEM (Aiternative-2)

Topological colouring shall be supported.

HMI shall have graphic displays for the trending of analogue parameters of the switchgear
bays.
A graphical representation of the secondary equipment and its status shall be provided.
The overview diagram shall show the switching status of the whole switchgear in a simplified
version. In overview diagrams, no control or acknowledgments shall be carried out.
The detailed diagrams shall show all relevant information of the feeders of one voltage level.
In the detailed diagrams, the measured and calculated values to be displayed.
Display the sequence of event list, and the alarm list and enable acknowledgement and
clearance.
Display curves, either real time or based on archived.
Shall be configured as per IEC 61850 via a standard SCD file.
Tagging facility should be implemented to perform the following tasks [petmit to work,
control inhibit, remove from operation and block and substitute measures.

6. System Support Functions

6.1. Diagnosis
To increase the reliability and the availability of the equipment and to reduce their
maintenance, the system shall be provided with self supervision and auto diagnostic facilities.
The runtime diagnostics should be capable of detecting and alanning any failures and
deficiencies as they occur in any parts of control system during service.

6.2. Interoperability
The system shall support interoperability between the IEDs from different suppliers, by
supporting the following:
The devices shall be connectable to the common protocol
The devices shall understand the information provided by other devices.
The devices shall perform together a common or joint function if applicable.
6.3. Expendability
The Supplied hardware and software shall have adequate hard disk and memory capacities
to satisfY their requirements, (i.e. the operating system, applications, data ... etc).
There shall be enough spare capacity left in the system as extension capacity for future use.
Hardware, Software systems and the data bases shall be sized to accommodate the current
size and 50% spare for future extensions (25% of which shall be equipped spare).
Each bidder shall state the maximum expendability of the offered system which shall be
easy expandable to its maximum extent, adding new software function or hardware
equipment or adding complete bay (even from third party) shall be possible through a well
defined procedures for which EETC trainees shall be trained.
6.4. Availability and Reliability
The Substation Automation System shall have a total availability of 99.98% (i.e. the ratio
of total time duration minus the actual outage duration to total time duration)
The system must provide a high MTBF (mean time between failure) and a low MTTR
(mean time to repair) rate.

Data Center 66/22 KV GIS S/S

For Mohamed Nagib Military Base Page 12 of 17
 SUBSTATION CONTROL SYSTEM (Aiternative-2)

The availability calculations should be included of all subsystems in well documented and
clearly described fotm.
To provide highest reliability, HMI and the gateways shall work completely independent
meaning retrieving the process data directly from the bay level devices. Additionally the
gateways shall be configured fully redundant to ensure full functionality.
6.5. Security
System shall provide the following security features:
Malware protection
Patch management
Security architecture
Security manual
Encryption
Any Input/output peripherals activities shall be recorded in non editable text file.
6.6. Perfonnance pammeters
The following parameters should be tested during the FAT & SAT of the SCS:
Retrieval of status or measurement to the HMI or gateway shall be less than 2 seconds for
66 KV part and less than 3 seconds for 22 KV patt
Control command shall be executed within 1 s from the HMI or gateway to the process for
66 KV patt and less than 1.5 s for the 22 KV part.
LAN redundancy latency shall be less than (1 ms).
Measurement accuracy for 66 KV shall be 0.25% for RMS current and voltage values
(including up to 101h harmonic) and more than 0.5% for active and reactive powers. For 22
KV feeders the accuracy ofRMS cunent shall be more than 1%.
Sequence of events should have one millisecond (1ms) resolution. (At least 200 events
during one week during communication failure).
Loss ofFeeder Manager power shouldn't result in the loss of stored events.
In case of sudden change in equipment status, system should provide scan by exception.
7. Configumtion Tools
The configuration of the station shall be made using the operation and engineering
workstation in the Windows 7 environment as minimum. The various functionalities shall
be customized by easy-to-use interactive configuration tools. The configuration shall
include the visual presentation of the object, adaptations needed in the process database,
and adaptations of the communication configuration data.
A portable Personal Computer (PC) as a service unit shall be provided for on-site
modifications of the control devices. This service unit shall be used for testing and
commissioning.
The PC- based service & engineering workstation system shall be used for the following
purposes:
- System configuration
- System testing
- Help functions
- Program documentation
- System commissioning
- Data base management
- Changing peripheral parameters

Data Center 66/22 KV GIS S/S Page 13 of 17

For Mohamed Nagib Military Base
 SUBSTATION CONTROL SYSTEM (Aiternative-2)

8. Uninterruptable Power Supply (UPS inverter type)

The SCS shall be powered from the UPS system. However, Feeder Manager & Bay
Control Units shall be supplied from the substation 220 VDC system.
UPS system shall be sized with enough capacity to supply the loads + 25 % spare for
future loads.
The UPS should be designed & synchronized to the main fi·equency so that an automatic
change over doesn't cause an interruption to the load. Once nmmal supply is resumed a
static by pass switch shall change over to previous position.
For maintenance reasons a manual switch shall be capable of changing over the load
without interruption of supply.
Preferably all equipments should be supplied directly from 220 V DC Station supply.
The UPS should withstand the total load after at least 3 hours for power loss.

9. Guarantee
During guaranty period, the Contractor shall take continual actions to ensure the
guaranteed availability and shall make available all the necessary resources such as
specialist personnel, spare patts, tools, test devices etc. for replacement or repair of all
defective patts and shall have prime responsibility for keeping the system operational.

10. Testing
The Contractor shall submit test cettificates required to demonstrate that the equipment to
be supplied under this specification meets the electrical and mechanical duties required
herein and by the referenced codes and standards. The contactor shall submit test
procedures before testing to be reviewed I approved.
Contractor shall submit a complete test certificate for the same offered type of equipment
in addition to the certificate of automation system compliance with IEC 61850 protocol.
All data obtained from receiving, storage, maintenance, and testing of the equipment shall
be recorded and submitted to the Employer.
Test rep01ts shall include the following:
Summaty of the test
Date that testing was performed
Test procedure followed by reference number
Description and identification of the equipment tested
Test equipment used and due date of next calibration
Test results
Conclusions
Contractor shall perform the following tests and allow the authorized representatives of
Employer to witness them.
Actual End to End test shall be done between substation field and control centre
(NECC&CRCC)
)> Factory Acceptance Test (FAT):
The contractor should petform a combined FAT for SCS & protection.
Factory Acceptance Testing (FAT) is a complete test of an integrated system at the
Contractor facility with functions, database, HMI, displays, protection relays, feeder
managers and logs.
IEC 61850 communication conformance and interoperability shall be met. The Contractor

Data Center 66/22 KV GIS 5/S Page 14 of 17

For Mohamed Nagib Military Base
 SUBSTATION CONTROL SYSTEM (Aiternative-2)

shall comply fully with the logical nodes described in the standard for the devices where
they are required.
The manufactUrer shall submit the test procedures and test fonns for factory -acceptance
test which will be performed for the protection relays & Substation Automation System
components, and approved by the EETC prior to the start.
The manufacturer shall be able to show the test plan and rest result executed on the system
architecture similar to the one in the project.
The equipment shall be subjected to Contractor's routine shop tests in compliance with
requirements of applicable codes and standards and specified additional tests.
In addition, performance and functional tests for the supplied equipment shall be
conducted on a system basis to demonstrate that all functions are available & performance
is guaranteed.
Contractor shall notifY Employer at least 60 days in advance of such tests, trials, assembly
and nomination letter to EETC central project protection sector, giving the date and place
where such tests will be made, to permit three (3) EETC engineers to be present to witness
the factory tests at the place of manufacturer for a combined FAT for SCS & protection
(the same engineers to attend the FAT for SCS & protection).
The three (3) EETC engineers: one from central protection sector, one from central project
protection sector & one :fi·om electric zone.

);> Site Acceptance Test (SAT):

A site acceptance test is run to verifY that the system will operate properly in the field with
real devices connected to other equipment.
The Contractor shall demonstrate their availability guaranteed by conducting the
availability test (for 720 hours) on the total substation automation system after
commissioning, test records -shall be examined to determine the conformance with
availability criterion.
In case of any outage during the availability test, the Contractor shall rectify the problem
and after rectification, the test period start after such rectification. If test object has not
been met, the test shall continue until the specified availability is achieved.
After the satisfactory conclusion of test, both Contractor and Employer shall mutually
agree to the test results before the test is considered to be completed successfully.
After that the system shall be taken over by the Employer and then the guaranty period
shall start.
The purpose of the Site Acceptance Test of the system shall be the inspection of the
general operation of the SCS following its site commissioning.
Tests and inspection shall be provided in accordance with the test documents submitted by
supplier and approved by the user.
The employer and EETC representatives shall witness all SAT tests.

11. Training N. A unless required from the owner

All training documentations and manuals shall be handed over to the trainee.
Contractor shall include a description of the proposed course content, duration & technical
level of the instruction.
The trainees should be having a certificate at the end of the training period.

Data Center f;G/22 KV GIS S/S PagelS of 1?

For Mohamed Nagib Military Base
 SUBSTATION CONTROL SYSTEM (Aiternative-2)

On shore & offshore training should include the following topics:

Software configuration.
Operation.
Troubleshooting.
• On-Shore Training:
Contractor has to take into consideration that six (6) engineers shall have training courses
ofSCS for two week at site (without any extra prices).
The ON-JOB training should take place at the substation site during site test &
commissioning.
• Off-Shore Training:
Contractor has to take into consideration that a combined training for SCS and protection
should be petformed for three (3) engineers in the factories and design offices of protective
relays & SCS manufacturers for two weeks.
The three (3) EETC engineers: one from central protection sector, one from central project
protection sector & one from electric zone.
All expenses including visa, travelling tickets, accommodation, medical treatment,
transportation & living expenses and all other needed expenses of this training has to be
included in the price.
Training agenda, program, documents and nomination letter should be provided before
training by 60 days for approval to EETC central project protection sector.
• Training for engineers that include:
Protective relay overview.
Software application for protective relays.
SCS, FM, BCU and gateway general overview.
Operator training.
SCS, FM, BCU and gateway software maintenance.
SCS, FM, BCU and gateway hardware maintenance.
Communication protocol.
Engineering tools and system configuration tools utility.
Building and modifying databases.
Building and modifYing single line diagram
• Training for operator:
SCS, FM, BCU and gateway general overview.
Use of the HMI & system software tools.
Control & supervision philosophy
All training documentation, manuals shall be handed over to the trainee.
Contractor shall include a description of the proposed course content, duration, and
technical level of the instmction.
The on job training shall take place at the substation site during site test and
commissioning.
12. Spare Parts :
According to spare patt list (Section-14)

13. Submittal
Soft and hard copies of all detailed drawings, calculations, test procedures, test reports, and
literature are pertaining to specified items. The submittals shall include but not limited to
the following:

Data Center 66/22 KV GIS S/S Page 16 of 17

For Mohamed Nagib Military Base
 SUBSTATION CONTROL SYSTEM (Aiternative-2 )

);;> With Tender

- Reference list, data related to the offered devices and type test reports.
- Brief description of the systems to give full information about the offered
systems.
- Manufacturer's catalogues for each component.
- Others which are required by tender document.
- SCADA system schematic diagram.
- Dl &DO for each BCU.
~ At the design and erection stages (for approved by Employer/EETC)
- Licence key (hardware &software)
- Clear procedure describing how to add an lED in future
- Complete documentation of implemented protocols
- Functional Design Document
- Guaranteed availability
- MTBF and MTTR figures for all equipment
- I/0 Signal lists.
- LAN Configuration and Ethernet Switch interconnection details
- Lists of specified equipment manufacturer's recommended spare parts
- Lists of all equipment manufacturer's recommended special tools, test
equipment, and software required for efficient operation
- Listing of routine tests
- Logic Diagram (hardware & software)
- Panels layout drawing
- Power Input Distribution drawings for all equipment
- Hardware Specification
- Product Manuals
- Schematic diagrams
- System Architecture Drawing
- Test Specification for Factory Acceptance Test
- The operation and maintenance manual
- Other documents as may be required during detailed engineering.
~ Piior to final acceptance, Contractor shall submit the following
documentation, as a minimum:
- All "As-Built" documentation for the system
- Copies of all Commissioning Test data
- Copies of fmal SCD (Substation Configuration Description) and CID
(Configured lED Description) files
- Copies of the fmal SCL (Substation Configuration Language) files for all lED's
installed (in accordance with IEC 61850 format)
- Copies of other fmal configuration data (such as relays/lED settings, etc)
- Operator's/Operations Manuals for all equipment

~ Three sets of hard copy and four sets of CD ROM containing all the as built
documents/drawings should be provide

Data Center 66/22 KV GIS S/S Page 17 of 17

For Mohamed Nagib Military Base