1 General Technical Features and Requirement of GIS Substations 1.0 Scope of Work The scope includes design, engineering, manufacture, fabrication, testing at manufacturers work/testing laboratories, delivery, unloading at site, storage, erection, testing and commissioning at site of the complete 400/220/132/33 kV switchyard including indoor SF6 gas insulated metal enclosed switchgear (GIS), 400 kV, 220 kV, 132 kV and 33 kV (as applicable) outdoor equipments, 400kV/220/132/33kV GIS ducts/EHV cables/Bushings for making connections with outdoor Autotransformers, Shunt Reactor and 400kV, 220 kV, 132 kV and 33 kV overhead lines Control & protection, PLCC equipments and other electrical and mechanical auxiliary systems on turnkey basis. However, equipment/ activities listed in clause 3.0 are excluded. Substations Covered a) 400/220/132 kV Substation at Dasna –Double main bus scheme b) 400/220/33 kV Substation at Indirapuram - Double main bus scheme c) 400/220/33 kV Substation at Ataur - Double main bus scheme The bidders are strongly advised to quote for alternative proposals for various packages whereby enhanced reliability and ease of operation and maintenance would be the key words. The offer should clearly bring out the salient features & cost implications of such alternatives. 2.0 Intent of Specification 2.1 It is the intent of this specification to describe primary features, materials, and design & performance requirements and to establish minimum standards for the work. 2.2 The specification is not intended to specify the complete details of various practices of contractor, but to specify the requirements with regard to performance, durability and satisfactory operation under the specified site conditions. 2.3 The Contractor shall also be responsible for the overall co-ordination with internal/external agencies, project management, training of Owner's manpower, loading, unloading, handling, moving to final destination for successful erection, testing and commissioning of the substation/switchyard. 2.4 Design of the GIS substation and its associated electrical & mechanical auxiliaries systems includes preparation of single line diagrams , electrical layouts, erection key diagrams, electrical and physical clearance diagrams, design calculations for Earth mat, control & protection
This document is posted to help you gain knowledge. Please leave a comment to let me know what you think about it! Share it to your friends and learn new things together.
Transcript
1
General Technical Features and Requirement of GIS Substations
1.0 Scope of Work
The scope includes design, engineering, manufacture, fabrication, testing at manufacturers
work/testing laboratories, delivery, unloading at site, storage, erection, testing and
commissioning at site of the complete 400/220/132/33 kV switchyard including indoor SF6 gas
insulated metal enclosed switchgear (GIS), 400 kV, 220 kV, 132 kV and 33 kV (as applicable)
outdoor equipments, 400kV/220/132/33kV GIS ducts/EHV cables/Bushings for making
connections with outdoor Autotransformers, Shunt Reactor and 400kV, 220 kV, 132 kV and 33
kV overhead lines Control & protection, PLCC equipments and other electrical and mechanical
auxiliary systems on turnkey basis. However, equipment/ activities listed in clause 3.0 are
excluded.
Substations Covered
a) 400/220/132 kV Substation at Dasna –Double main bus scheme
b) 400/220/33 kV Substation at Indirapuram - Double main bus scheme
c) 400/220/33 kV Substation at Ataur - Double main bus scheme
The bidders are strongly advised to quote for alternative proposals for various packages whereby enhanced reliability and ease of operation and maintenance would be the key words. The offer should clearly bring out the salient features & cost implications of such alternatives.
2.0 Intent of Specification
2.1 It is the intent of this specification to describe primary features, materials, and design &
performance requirements and to establish minimum standards for the work.
2.2 The specification is not intended to specify the complete details of various practices of contractor,
but to specify the requirements with regard to performance, durability and satisfactory operation
under the specified site conditions.
2.3 The Contractor shall also be responsible for the overall co-ordination with internal/external
agencies, project management, training of Owner's manpower, loading, unloading, handling,
moving to final destination for successful erection, testing and commissioning of the
substation/switchyard.
2.4 Design of the GIS substation and its associated electrical & mechanical auxiliaries systems
includes preparation of single line diagrams , electrical layouts, erection key diagrams, electrical
and physical clearance diagrams, design calculations for Earth mat, control & protection
fire fighting system, air conditioning system, indoor/outdoor lighting/illumination and other
relevant drawings & documents required for engineering of all facilities under the scope of this
contract.
2.5 Civil Works:
The actual works will be carried out by the Owner/its subsidiaries under the direct supervision of
this package supplier. All design and documents for the civil works shall be given by the package
supplier.
In this eventually cement, steel (construction steel and GIS structures), earthing rod and GIS strip
will be supplied by Owner. However, detailed justified estimate for the same will have to be
provided by package supplier at the start of the project
Laying of earthing mat (below ground) will also be undertaken by Owner under the supervision
of contractor.
DG set, EOT cranes, Air Conditioning, Indoor illumination will also be provided by the Owner at
his discretion.
2.6 Any other items not specifically mentioned in the specification but which are required for
erection, testing and commissioning and satisfactory operation of the substation are deemed to be
included in the scope of the specification unless specifically excluded.
3.0 Specific Exclusions
The following items of work are specifically excluded from the scope of the specifications for all
substations:
a) Transformer and Reactor: These shall be supplied under a separate package. However
erection and commissioning of the same shall form part of this package.
b) Colony/Housing of substation.
c) Outgoing lines (beyond gantries in case of over-head feeders).
d) Approach road up to Substation/Switchyard entrance.
4.0 Single Line Diagram
For Gas Insulated Substation at the 400, 220, 132, 33kV voltage levels, double main bus
switching scheme layout arrangement shall be used. Single line diagram and arrangements
are enclosed and shall be further engineered by the contractor.
The following single line diagrams shall be adhered to: (See Appendix-1)
3
a) 400/220/132 kV Substation at Dasna – (Drawing No.MEIL-D-005)
b) 400/220/33 kV Substation at Indirapuram – (Drawing No.MEIL-D-006)
c) 400/220/33 kV Substation at Ataur – (Drawing No.MEIL-D-007)
Tentative plot layouts are attached at Appendix-2
5.0 The following drawings / documents shall be submitted in addition to the documentation
proposed by the contractor:
a) Single Line Diagram
b) Key Protection Diagram
c) Layout drawings and sections
d) GA Drawings & Schematics
e) Type Test reports
f) Guaranteed Technical Particulars
g) Quality assurance plan
h) Equipment catalogue
i) Equipment O & M manual
j) Mechanical and Electrical Packages detail drawings
All the drawings/documents listed above shall be in the approval category.
6.0 Special Tools and Tackles
A complete list of tools and tackles shall be furnished by the contractor as under:
1. An exhaustive list of tools and tackles that shall be handed over to the owner for
subsequent Operation and Maintenance activities.
2. A list of tools and tackles that shall be brought by the contractor for completion of
Erection, Testing and Commissioning activity but taken back after accomplishment of
work.
7.0 Specific Requirements
7.1 Training of Owner’s Personnel
The contractor shall organize and conduct complete and thorough training program (to be
conducted in English language). The traveling and living expenses of Owner’s personnel, if any,
shall be borne by Owner. The training shall be carried out at the place of manufacture and also at
site/s or as the case may require and as agreed by Owner so as to ensure the complete adequacy
of the program and imparting of detailed knowledge of system/equipment design engineering
and operation and maintenance aspects.
4
The minimum duration of the training shall be as follows:
Design, operation and maintenance of the GIS installations including procedures for fault
attending (at contractor works) for 3 man-weeks.
The contractor shall also provide training in the area of testing, commissioning and
maintenance for atleast 5 personnel for 5 days at one of the GIS Substations.
Design, operation, maintenance and commissioning aspect for 5 (Five) persons at
contractor’s works as per following
a) Circuit Breaker (controlled switching) 3 days
b) Protection and Automation 3 days
c) PLCC 2 days
7.2 The Contractor shall provide auxiliary system (like battery, AC/DC feeders etc) for future bays
also as per single line diagram in addition to bays under present scope.
7.3 As 400 kV, 220kV, 132kV GIS is likely be extended in future, the contractor shall make
available during detailed engineering and document Hand -Over stage, all details such as cross
section, gas pressure etc. required for designing in future for extension of GIS.
7.4 Construction Power and Water: These shall be arranged by the contractor. However in case
the Owner is in a position to provide the same at a later date, the charges for the same shall be
intimated and if acceptable to contractor , these could be availed. It may be noted that reliability
of power and water would not be ensured by the Owner and in no case be held responsible for
any delay in works because of non-availability of power and water.
7.5 The contractor shall be responsible for safety of human and equipment during the working. It
will be the responsibility of the Contractor to co-ordinate and obtain Electrical Inspector's
clearance before commissioning. Any additional items, modification due to observation of such
statutory authorities shall be provided by the Contractor at no extra cost to the Owner.
8.0 Standards and Codes
All applicable standards and code as brought out in the technical specification (Volume-III
Section 3.1A) shall be adhered to.
Further all Central and State Government (UP) guidelines and gazette notifications shall be
complied with. Some applicable notifications are:-
a) CEA notification No.CEA/TETD/MP/R/01/2010 Dt.20/08/10
b) Building Bye Laws-2003 ( inclusive all requirement stipulated in Clause 4g of the gazette
notification )
c) IE Rules 1956 with latest amendments.
5
d) CEA amendment on (installation & operation of meters)Reg.2006 issued on 04.06.2010
e) UP Grid Code-18/04/07
Note: 1. Bidder: The person/party quoting for the package.
2. Contractor: The successful bidder on whom the package order is awarded.
3. Owner: The package awardee.
1 VOL-II/SEC-1 (A): Technical Details of GIS Substation
SECTION-1(A)
1(A) TECHNICAL DETAILS FOR SF6 GAS INSULATED METAL ENCLOSED
SWITCHGEAR (GIS)
1.0 GENERAL CHARACTERISTICS
The SF6 gas insulated metal enclosed switchgear shall be totally safe against inadvertent touch
of any of it's live constituent parts. It should be designed for indoor/outdoor (as specified)
application with meteorological conditions at site.
The arrangement of gas sections or compartments shall be such as to facilitate future extension
of any make on either end without any drilling, cutting or welding on the existing equipment.
To add equipment, it shall not be necessary to move or dislocate the existing switchgear bays.
The design should be such that all parts subjected to wear and tear are easily accessible for
maintenance purposes. The equipment offered shall be protected against all types of voltage
surges and any equipment necessary to satisfy this requirement shall be deemed to be included.
The metal-enclosed gas insulated switchgear, including the operating devices, accessories and
auxiliary equipment forming integral part thereof, shall be designed, manufactured, assembled
and tested in accordance with the IEC-62271-203 publications including their parts and
supplements as amended or revised to date.
2.0 LIST OF STANDARDS
The metal-enclosed gas-insulated switchgear, including the operating devices, accessories and
auxiliary equipment forming integral part thereof, shall be designed, manufactured, assembled
and tested in accordance with the following International Electro-technical Commission
(IEC)Publications including their parts and supplements as amended or revised to date:
IEC 62271-203 Gas Insulated metal-enclosed switchgear for rated voltages
above 52KV
IEC 60376 New sulphur hexafluoride
IEC 62271- 100 High voltage alternating current Circuit breakers
IEC 60694 Common clauses for high voltage Switchgear and control-gear
standards
IEC 62271-102 Alternating current disconnectors(isolators) and earthing
switches
IEC 61128 Alternating current disconnectors. Bus-transfer current
switching by disconnectors.
2 VOL-II/SEC-1 (A): Technical Details of GIS Substation
IEC 61129 Alternating current earthing switches. Induced current
switching
IEC 66044-1 Current transformers
IEC 66044-2 Voltage transformers
IEC 60137 Bushings for alternating voltages above 1000 V
IEC 60859 Cable connections for gas-insulated switchgear
IEC 60480 Guide to checking of sulphur hexafluoride taken from
electrical equipment
IEC 60099 -1/4 Non-linear resistor type arresters for AC systems
IEC 60439 Factory-built assemblies of low-voltage switchgear and
control Gear.
IEC 60427 Report on synthetic testing of high-voltage alternating-current
breaker.
IEEE 80 (2000) IEEE Guide for Safety in AC Substation grounding.
CIGRE-44 Earthing of GIS- an application guide. (Electra no.151,
Dec’93).
IEC 61639 Direct connection between Power Transformers and gas
insulated metal enclosed switchgear for rated voltage
72.5 kV and above.
The components and devices which are not covered by the above standards shall conform to,
and comply with, the latest applicable standards, rules, codes and regulations of the
internationally recognized standardizing bodies and professional societies as may be approved
by the Employer. The manufacturer shall list all applicable standards, codes etc. and provide
copies thereof for necessary approval.
In case the requirements laid down herein differ from those given in above standard in any
aspect the switchgear shall comply with the requirements indicated herein in regard thereto.
3.0 DEFINITIONS
3.1 Assembly
Assembly refers to the entire completed GIS equipment furnished under contract.
3.2 Bay
3 VOL-II/SEC-1 (A): Technical Details of GIS Substation
Bay refers to the area occupied by one Circuit Breaker and associated equipments used to
protect one feeders/line/bus coupler in double bus scheme.
3.3 Compartment
When used in conjunction with GIS equipment, compartment refers to a gas tight volume
bounded by enclosure walls and gas tight isolating barriers.
3.4 Enclosure
When used in conjunction with GIS equipment, enclosure refers to the grounded metal housing
or shell which contains and protects internal Power system equipment (breaker, disconnecting
switch, grounding switch, voltage transformer, current transformer surge arresters,
interconnecting bus etc.)
3.5 Manual Operations
Manual operation means operation by hand without using any other source of Power.
3.6 Module
When used in conjunction with GIS equipment, module refers to a portion of that equipment.
Each module includes its own enclosure. A module can contain more than one piece of
equipment, for example, a module can contain a disconnecting switch and a grounding switch.
3.7 Reservoir
When used in conjunction with GIS equipment reservoir refers to a larger gastight volume.
4.0 GENERAL DESIGN AND SAFETY REQUIREMENT
4.1 The GIS assembly shall consist of separate modular compartments e,g Circuit Breaker
compartment, Bus bar compartment filled with SF6 Gas and separated by gas tight partitions so
as to minimize risk to human life, allow ease of maintenance and limit the effects of gas leaks
failures & internal arcs etc. These compartments shall be such that maintenance on one feeder
may be performed without de-energizing the adjacent feeders. These compartments shall be
designed to minimize the risk of damage to adjacent sections and protection of personnel in the
event of a failure occurring within the compartments. Rupture diaphragms with suitable
deflectors shall be provided to prevent uncontrolled bursting pressures developing within the
enclosures under worst operating conditions, thus providing controlled pressure relief in the
affected compartment.
4.2 The workmanship shall be of the highest quality and shall conform to the latest modern
practices for the manufacture of high technology machinery and electrical switchgear.
4 VOL-II/SEC-1 (A): Technical Details of GIS Substation
4.3 The switchgear, which shall be of modular design, shall have complete phase isolation. The
conductors and the live parts shall be mounted on high graded epoxy resin insulators. These
insulators shall be designed to have high structural strength and electrical dielectric properties
and shall be free of any voids and free of partial discharge at a voltage which is atleast 5 %
greater than the rated voltage .They should be designed to have high structural and dielectric
strength properties and shall be shaped so as to provide uniform field distribution and to
minimize the effects of particle deposition either from migration of foreign particles within the
enclosures or from the by-products of SF6 breakdown under arcing conditions.
4.4 Gas barrier insulators and support insulators shall have the same basis of design. The support
insulators shall have holes on both sides for proper flow of gas.
4.5 Gas barrier insulators shall be provided so as to divide the GIS into separate compartments.
They shall be suitably located in order to minimize disturbance in case of leakage or
dismantling. They shall be designed to withstand any internal fault thereby keeping an internal
arc inside the faulty compartment. Due to safety requirement for working on this pressurized
equipment, whenever the pressure of the adjacent gas compartment is reduced, it should be
ensured by the contractor that adjacent compartment would remain in service with reduced
pressure. The gas tight barriers shall be clearly marked on the outside of the enclosures.
4.6 The material and thickness of the enclosures shall be such as to withstand an internal flash over
without burns through for a period of 300 ms at rated short time withstand current. The material
shall be such that it has no effect of environment as well as from the by-products of SF6
breakdown under arcing condition.
4.7 Each section shall have plug- in or easily removable connection pieces to allow for easy
replacement of any component with the minimum of disturbance to the remainder of the
equipment. Inspection windows shall be provided for disconnector and earth switches.
4.8 The material used for manufacturing the switchgear equipment shall be of the type,
composition and have physical properties best suited to their particular purposes and in
accordance with the latest engineering practices. All the conductors shall be fabricated of
aluminum/ copper tubes of cross sectional area suitable to meet the normal and short circuit
current rating requirements. The finish of the conductors shall be smooth so as to prevent any
electrical discharge. The conductor ends shall be silver plated and fitted into finger contacts or
tulip contacts. The contacts shall be of sliding type to allow the conductors to expand or
contract axially due to temperature variation without imposing any mechanical stress on
supporting insulators.
5 VOL-II/SEC-1 (A): Technical Details of GIS Substation
4.9 Each pressure filled enclosure shall be designed and fabricated to comply with the equirements
of the applicable pressure vessel codes and based on the design temperature and design
pressures as defined in IEC-62271-203.
4.10 The manufacturer shall guarantee that the pressure loss within each individual gas-filled
compartment shall not be more than half percent (0.5%) per year.
4.11 Each gas-filled compartment shall be equipped with static filters, density switches, filling
valve and safety diaphragm. The filters shall be capable of absorbing any water vapour which
may penetrate into the enclosures as well as the by-products of SF6 during interruption. Each
gas compartment shall be fitted with separate non-return valve connectors for evacuating &
filling the gas and checking the gas pressure etc.
4.12 The switchgear line-up when installed and operating under the ambient conditions shall
perform satisfactorily and safely under all normal and fault conditions. Even repeated
operations up to the permissible servicing intervals under 100% rated and fault conditions shall
not diminish the performance or significantly shorten the useful life of the switchgear. Any
fault caused by external reasons shall be positively confined to the originating compartment and
shall not spread to other parts of the switchgear.
4.13 The thermal rating of all current carrying parts shall be minimum for one sec. for the rated
symmetrical short-circuit current.
4.14 For single phase transformer, automatic insertion of the spare transformer incase of problem
with a healthy transformer should be offered. Other options can also be given but estimated
time for changing the transformer and down time should be provided by the contractor.
4.15 The switchgear shall be of the free standing, self-supporting with easy accessibility to all the
parts during installation & maintenance with all high-voltage equipment installed inside gas
insulated metallic and earthed enclosures, suitably sub-divided into individual arc and gasproof
compartments preferably for:
a) Bus bars
b) Intermediate compartment
c) Circuit breakers
d) Line disconnectors
e) Voltage Transformers
f) Lightning Arrester
6 VOL-II/SEC-1 (A): Technical Details of GIS Substation
g) Gas Insulated bus duct section between GIS and XLPE cable/Overhead Conductor (as
applicable)
h) Gas Insulated bus section between GIS & Oil filled Transformer and Reactor (if
applicable). The bus enclosure should be sectionalized in a manner that maintenance
work on any bus disconnector ( when bus and bus disconnector are enclosed in a single
enclosure ) can be carried out by isolating and evacuating the small effected section and
not the entire bus.
Detailed technical specifications are given in Volume-II/Sec1 (B)
4.16 The arrangement of the individual switchgear bays shall be such so as to achieve optimum
space-saving, neat and logical arrangement and adequate accessibility to all external
components.
4.17 The layout of the substation equipment, bus-bars and switchgear bays shall preferably be based
on the principle of “phase grouping”. Switchgear layout based on the “mixed phases” principle
shall not be accepted without mutual specific agreement between supplier and owner. The
arrangement of the equipment offered must provide adequate access for operation, testing and
maintenance.
4.18 Control and Protection
400kV lines shall have Main-I & Main-II protection and also have numerical distance
protection scheme as three zone distance type with carrier aided inter-tripping feature. The
Main-I & Main-II shall be of different make for reliability. In case of LILO of lines, suitable
system shall be provided based on the existing scheme. All 765 & 400kV lines shall have two-
stage over-voltage protection. Further, all these lines shall be provided with single and three
phase auto-reclosing facility in case of transient faults.
All transformers shall be provided with differential, restricted earth fault, over-current, earth
fault and over-fluxing protection and overload alarm. Similarly, reactors shall be provided with
differential, restricted earth fault and back-up impedance protection. Busbars shall be protected
with high speed differential protection with selective operation for each bus. Local breaker
back-up protection shall be provided to de-energize the stuck breaker from both sides.
Time synchronization system shall be provided to receive time signal through GPS or from
National Physical Laboratory (NPL) through INSAT.
See detailed technical specification under Section-A
7 VOL-II/SEC-1 (A): Technical Details of GIS Substation
4.19 Substation Automation System (SAS)
The functions of control, annunciation, disturbance recording, event logging, and measurement
of all parameters shall be integrated into SAS. It shall also be provided with facility of
communication and control for remote end operation. See detailed technical specification under
Section-A
4.20 All the elements shall be accessible without removing support structures for routine inspections
and possible repairs. The removal of individual enclosure parts or entire breaker bays shall be
possible without disturbing the enclosures of neighboring bays.
4.21 It should be impossible to unwillingly touch live parts of the switchgear or to perform
operations that lead to arcing faults without the use of tools or brute force.
4.22 In case of any repair or maintenance on one bus-bar/ disconnector, the other bus-bar should be
live and in service.
4.23 All interlocks that prevent potentially dangerous mal-operations shall be constructed such that
they cannot be operated easily, i.e. the operator must use tools or brute force to over-ride them.
4.24 In general the contours of energized metal parts of the GIS and any other accessory shall be
such, so as to eliminate areas or points of high electrostatic flux concentrations. The surfaces
shall be smooth with no projection or irregularities which may cause visible corona. No corona
shall be visible in complete darkness which the equipment is subjected to specified test voltage.
There shall be no radio interference from the energized switchgear at rated voltage.
4.25 The enclosure shall be of continuous design and shall meet the requirement as specified in
clause no. 10 (special considerations for GIS) of IEEE- 80, Year- 2000. The enclosure shall be
sized for carrying induced current equal to the rated current of the Bus. The conductor and the
enclosure shall form the concentric pair with effective shielding of the field internal to the
enclosure.
4.26 The fabricated metal enclosures shall be of Aluminium alloy having high resistance to
corrosion, low electrical loses and negligible magnetic losses. All joint surfaces shall be
machined and all castings shall be spot faced for all bolt heads or nuts and washers. All screws,
bolts, studs and nuts shall conform to metric system.
4.27 The breaker enclosure shall have provision for easy withdrawal of the interrupter assemblies.
The removed interrupter assembly must be easily and safely accessible for inspection and
possible repairs.
8 VOL-II/SEC-1 (A): Technical Details of GIS Substation
4.28 The enclosure shall be designed to practically eliminate the external electromagnetic field and
thereby electrodynamics stresses even under short circuit conditions.
4.29 The elbows, bends, cross and T-sections of interconnections shall include the insulators bearing
the conductor when the direction changes take place in order to ensure that live parts remain
perfectly centered and the electrical field is not increased at such points.
4.30 The Average Intensity of electromagnetic field shall not be more than 50 micro –Tesla on the
surface of the enclosure. The contractor shall furnish all calculations and documents in support
of the above during detailed engineering.
4.31 The Contractor shall furnish the following information regarding the loosely distributed
metallic particles within the GIS encapsulation.
a) Calculations of critical field strength for specific particles of defined mass and geometry.
b) The methodology and all the equipment for electrical partial discharge (PD) detection
and/or acoustic detection methods, including that mentioned in the specification elsewhere.
4.32 The switchgear shall have provision for connection with ground mat risers. This provision shall
consist of grounding pads to be connected to the ground mat riser in the vicinity of the
equipment.
4.33 The ladders and walkways shall be provided wherever necessary for access to the equipment.
A portable ladder with adjustable height may also be supplied to access to the equipment.
4.34 Wherever required, the heaters shall be provided for the equipment in order to ensure the
proper functioning of the switchgear at specified ambient temperatures. The heaters shall be
rated for 240V AC supply and shall be complete with thermostat, control switches and fuses,
connected as a balanced 3-phase, 4-wire load. The possibility of using heaters without
thermostats in order to achieve the higher reliability may be examined by the contractor and
accordingly included in the offer but it shall be ensured by the contractor that the temperature
rise of different enclosures where heating is provided should be within safe limits as per
relevant standards. One copy of the relevant extract of standard to which the above arrangement
conforms along with cost reduction in offer. If any, shall also be furnished along with the offer.
The heaters shall be so arranged and protected as to create no hazard to adjacent equipment
from the heat produced.
4.36 The enclosure & support structure shall be designed such that a mechanic 1780 mm in height
and 80 Kg in weight is able to climb on the equipment for maintenance.
4.36 The sealing provided between flanges of two modules / enclosures shall be such that long term
tightness is achieved.
9 VOL-II/SEC-1 (A): Technical Details of GIS Substation
4.37 Alarm circuit shall not respond to faults for momentary conditions. The following indications
including those required elsewhere in the specifications shall be generally provided in the alarm
and indication circuits.
4.37.1. Gas Insulating System:
a) Loss of Gas Density.
b) Loss of Heater power(if required)
c) Any other alarm necessary to indicate deterioration of the gas insulating system.
4.37.2. Operating System:
a) Low operating pressure.
b) Loss of Heater power.
c) Loss of operating power.
d) Loss of control.
e) Pole Disordance.
4.38 The equipment will be operated under the following ambient conditions:
a) The ambient temperature varies between 0 degree-C and 50 degree-C. However, for design
purposes, ambient temperature should be considered as 50 degree-C.
b) The humidity will be about 95% (indoors)
c) The elevation is less than 1000 metres.
4.39 Temperature rise of current carrying parts shall be limited to the values stipulated in IEC-694,
under rated current and the climatic conditions at site. The temperature rise for accessible
enclosure shall not exceed 20 degree C above the ambient temperature of 50 degree C. In the
case of enclosures, which are accessible but need not be touched during normal operation, the
temperature rise limit may be permitted upto 30 degree C above the ambient of 50 degree C.
These conditions shall be taken into account by the supplier in the design of the equipment.
5.0 Bellows or Compensating Units:-
Adequate provision shall be made to allow for the thermal expansion of the conductors and of
differential thermal expansion between the conductors and the enclosures. The bellows shall be
metallic (preferably of stainless steel) of following types or other suitable equivalent
arrangement shall be provided wherever necessary.
1. Lateral / Vertical mounting units: These shall be inserted, as required, between sections of
busbars, on transformer, shunt reactor and XLPE cable etc. Lateral mounting shall be made
possible by a sliding section of enclosure and tubular conductors.
10 VOL-II/SEC-1 (A): Technical Details of GIS Substation
2. Axial compensators : These shall be provided to accommodate changes in length of busbars
due to temperature variations
3. Parallel compensators: These shall be provided to accommodate large linear expansions
and angle tolerances.
4. Tolerance compensators: These shall be provided for taking up manufacturing, site
assembly and foundation tolerances.
5. Vibration compensators: These bellow compensators shall be provided for absorbing
vibrations caused by the transformers and shunt reactors when connected to SF6 switchgear
by oil- SF6 bushings.
6. The electrical connections across the bellows or compensating units shall be made by
means of suitable connectors.
5.1 Indication and Verification Of Switch Positions
Indicators shall be provided on all circuit breakers, isolators and earth-switches, which shall
clearly show whether the switches are open or closed. The indicators shall be mechanically
coupled directly to the main contact operating drive rod or linkages and shall be mounted in a
position where they are clearly visible from the floor or the platform in the vicinity of the
equipment. Windows shall also be provided with all isolators and earth switches so that the
switch contact positions can be verified by direct visual inspection.
5.2 Pressure Relief:-
Pressure relief devices shall be provided in the gas sections to protect the main gas enclosures
from damage or distortion during the occurrence of abnormal pressure increase or shock waves
generated by internal electrical fault arcs (preferably in downward direction). Pressure relief
shall be achieved either by means of diaphragms or plugs venting directly into the atmosphere
in a controlled direction. If the pressure relief devices vent directly into the atmosphere, suitable
guards and deflectors shall be provided. Contractor shall submit to the owner the detailed
criteria/ design regarding location of pressure relief Devices/Rupture Diaphragms.
5.3 Pressure Vessel Requirements
The enclosure shall be designed for the mechanical and thermal loads to which it is subjected in
service. The enclosure shall be manufactured and tested according to the pressure vessel code
(SME/CENELEC code for pressure Vessel.) Each enclosure has to be tested as a routine test at
1.5 time the design pressure for one minute. The bursting strength of Aluminium castings has to
be a at least 5 times the design pressure. A bursting pressure test shall be carried out at 5 times
the design pressure as a type test on each type of enclosure.
11 VOL-II/SEC-1 (A): Technical Details of GIS Substation
5.4 Grounding
The grounding system shall be designed and provided as per IEEE-80-2000 and CIGRE-44 to
protect operating staff against any hazardous touch voltages and electro-magnetic interferences.
The GIS supplier shall define clearly what constitutes the main grounding bus of the GIS. The
GIS supplier must supply the entire material for grounding bus of GIS viz conductor, clamps,
joints, operating and safety platforms etc. The GIS supplier is also required to supply all the
earthing conductors and associated hardware material for the following:
1. Connecting all GIS equipment, bus ducts, enclosures, control cabinets, supporting structure
etc. to the ground bus of GIS.
2. Grounding of transformer, reactor, CVT, SA and other outdoor switchyard equipments/
structures etc.
The enclosure of the GIS may be grounded at several points so that there shall be grounded
cage around all the live parts. A minimum of two nos. of grounding connections should be
provided for each of circuit breaker, transformer terminals, cable terminals, surge arrestors,
earth switches and at each end of the bus bars. The grounding continuity between each
enclosure shall be effectively interconnected with Cu/ Al bonds of suitable size to bridge the
flanges. . In case the contractor does not offer external bonding, the contractor shall
demonstrate that the connectivity offered by them between each enclosure is effective and does
not require external bonding. Further similar design should have been in service. Subassembly
to subassembly bonding shall be provided to provide gap & safe voltage gradients between all
intentionally grounded parts of the GIS assembly & between those parts and the main
grounding bus of the GIS.
Each marshalling box, local control panel, power and control cable sheaths and other non
current carrying metallic structures shall be connected to the grounding system of GIS via
connections that are separated from GIS enclosures.
The grounding connector shall be of sufficient mechanical strength to withstand
electromagnetic forces as well as capable of carrying the anticipated maximum fault current
without overheating. At least two grounding paths shall be provided to connect each point to
the main grounding bus. Necessary precautions should be under taken to prevent excessive
currents from being induced into adjacent frames, structures of reinforcing steel and to avoid
establishment of current loops via other station equipment.
12 VOL-II/SEC-1 (A): Technical Details of GIS Substation
All flexible bonding leads shall be tinned copper. All connectors, for attaching flexible bonding
leads to grounding conductors and grounding conductors to support structures shall be tinned
bronze with stainless steel or tinned bronze hardware.
The contractor shall provide suitable measure to mitigate transient enclosure voltage caused by
high frequency currents caused by lightning strikes, operation of surge arrestor, ph. / earth fault
and discharges between contacts during switching operation. The grounding system shall
ensure safe touch & step voltages in all the enclosures. The contractor shall provide suitable
barrier of non-linear resistor/ counter discontinued SF6/ Air termination, SF6/ Transformer or
Reactor termination, SF6/ HV cable bushing etc. to mitigate transient enclosure voltage.
5.5 TYPE TEST
The offered 400kV, 220kV, 132kV, 33kV GIS equipments shall conform to the type tests as per
IEC-62271-203. Contractor shall submit type test reports for the following type tests.
S.No Description of the Type Test for 400kV, 220kV, 132kV, 33kV GIS
1 Tests to verify the insulation level of the equipment and dielectric test on auxiliary circuits
2 Tests to prove the temperature rise of any part of the equipment and measurement of the resistance of the main circuit
3 Tests to prove the ability of the main and Earthing circuits to carry the rated peak and rated short time withstand current
4 Tests to verify the making and breaking capacity of the included switching devices
5 Tests to prove the satisfactory operation of the included switching devices
6 Tests to prove the strength of the enclosures
7 Gas tightness tests
8 Tests on partitions
9 Tests to prove the satisfactory operation at limit temperatures
10 Tests to assess the effects of arcing due to internal fault
11 Verification of the degree of protection of the enclosure
12 Tests to prove performance under thermal cycling and gas tightness tests on insulators
13 Additional tests on auxiliary and control circuits
13 VOL-II/SEC-1 (A): Technical Details of GIS Substation
14 Tests to prove the radio interference voltage (RIV) level (if applicable)
15 Electromagnetic Compatibility Test (EMC)
The test reports of the above type tests for GIS shall be submitted for approval and the test reports shall be of tests conducted within 10 (ten) years. In case the test reports are older than 10(ten) years, the contractor shall repeat those tests at no extra cost to the purchaser.
6.0 Circuit Breakers
General
SF6 gas insulated metal enclosed circuit breakers shall comply with the latest revisions of IEC-
62271-100 & relevant IEC except to the extent explicitly modified in the specification and shall
meet with requirements specified. Circuit breakers shall be equipped with the operating
mechanism. Circuit breakers shall be of single pressure (puffer) type. Complete circuit breaker
with all necessary items for successful operation shall be supplied. The circuit breakers shall be
designed for high speed single and three phase reclosing with an operating sequence and timing
as specified.
6.1 Duty Requirements
Circuit breaker shall be C2 - M2 class as per IEC 62271-100.
Circuit breaker shall meet the duty requirements for any type of fault or fault location also for
line charging and dropping when used on 400/220 kV effectively grounded system, with
transmission lines of lengths and perform make and break operations as per the stipulated duty
cycles satisfactorily.
a) Pre Insertion Resister
400 kV circuit breakers for line bay shall be provided with single step pre insertion closing
resistors (wherever the requirement of PIR is explicitly specified so) to limit the switching
surges to a value of less than 2.3 p.u. The value of the pre-insertion resistor and the
duration of pre-insertion time shall be as given in clause 1.1 of SECTION-1 (B). The
resistor shall have thermal rating for the following duties:
i) TERMINAL FAULT
Close .... 1 Min ........ Open ...... Close open 2 min ........ close ....... 1 Min ........ open
close open.
ii) RECLOSING AGAINST TRAPPED CHARGES
14 VOL-II/SEC-1 (A): Technical Details of GIS Substation
Duty same as under (i) above. The first, third and fourth closures are to be on de-
energised line while second closing is to be made with lines against trapped charge of
1.2 p.u. (Based on 1 pu = 653kV) of opposite polarity.
iii) OUT OF PHASE CLOSING
One closing operation under phase opposition that is with twice the voltage across the
terminals.
iv) No allowance shall be made for heat dissipation of resistor during time interval
between successive closing operations. The resistors and resistor supports shall
perform all these duties without deterioration. Calculations and test reports of resistors
proving thermal rating for duties specified above shall be furnished along with the bid.
The calculations shall take care of adverse tolerances on resistance values and time
settings.
6.2 The circuit breaker shall be capable of: i) Interrupting the steady and transient magnetizing current corresponding to 400 kV/220 kV
class transformers of 250 MVA to 630 MVA ratings on both 400 kV & 220 kV side.
ii) Interrupting line/cable charging current as per IEC without re-strikes and without use of
opening resistors.
iii) Clearing short line fault (Kilometric faults) with source impedance behind the bus
equivalent to symmetrical fault current specified.
iv) Breaking 25% the rated fault current at twice the rated voltage under phase opposition
condition.
v) The breaker shall satisfactorily withstand the high stresses imposed on them during fault
clearing, load rejection and re-energisation of lines with trapped charges.
vi) 400 kV breakers shall be able to switch in and out the 400 kV shunt reactor for any value
from 50 MVAR up to 80 MVAR without giving rise to overvoltage more than 2.3 p.u.
Laboratory test and or field test reports in support of the same shall be furnished along
with the bid.
6.3 Total Break Time
The total break time shall not be exceeded under any of the following duties :
i) Test duties T10,T30,T60,T100 (with TRV as per IEC- 62271-100 )
ii) Short line fault L90, L75 (with TRV as per IEC-62271-100 )
ii) The Contractor may please note that total break time of the breaker shall not be exceeded
under any duty conditions specified such as with the combined variation of the trip coil
voltage (70-110%), pneumatic/hydraulic pressure and SF6 gas pressure etc. While
15 VOL-II/SEC-1 (A): Technical Details of GIS Substation
furnishing the proof for the total break time of complete circuit breaker, the contractor
may specifically bring out the effect of non simultaneity between poles and show how it is
covered in the total break time.
The values guaranteed shall be supported with the type test reports.
6.4. Constructional Features
The features and constructional details of breakers shall be in accordance with requirements
stated hereunder:
6.4.1. Contacts
All making and breaking contacts' shall be sealed and free from atmospheric effects.
Contacts shall be designed to have adequate thermal and current carrying capacity for
the duty specified and to have a life expectancy so that frequent replacement due to
excessive burning will not be necessary. Provision shall be made for rapid dissipation
of heat generated by the arc on opening.
6.4.2. Any device provided for voltage grading to damp oscillations or, to prevent re-strike
prior to the complete interruption of the circuit or to limit over voltage on closing, shall
have a life expectancy comparable of that of the breaker as a whole.
6.4.3. Breakers shall be so designed that when operated within their specified rating, the
temperature of each part will be limited to values consistent with a long life for the
material used. The temperature rise shall not exceed that indicated in IEC-62271-100
under specified ambient conditions.
6.4.4. The gap between the open contacts shall be such that it can withstand atleast the rated
phase to ground voltage for eight hours at zero pressure above atmospheric level of SF6
gas due to its leakage. The breaker should be able to withstand all dielectric stresses
imposed on it in open condition at lockout pres-sure continuously (i.e. 2 pu. power
frequency voltage across the breaker continuously)
6.4.5. In the interrupter assembly there shall be an adsorbing product box to minimize the
effect of SF6 decomposition products and moisture. The material used in the
construction of the circuit breakers shall be such as to be fully compatible with SF6 gas
decomposition products.
6.4.6. Provisions shall be made for attaching an operational analyzer to record travel, speed
and making measurement of operating timings etc. after installation at site.
6.5. Operating Mechanism
16 VOL-II/SEC-1 (A): Technical Details of GIS Substation
6.5.1. General Requirements :
a) Circuit breaker shall be operated by spring charged mechanism or electro hydraulic
mechanism or a combination of these. The mechanism shall be housed in a dust proof
cabinet and shall have IP: 42 degree of protection.
b) The operating mechanism shall be strong, rigid, not subject to rebound or to critical
adjustments at site and shall be readily accessible for maintenance.
c) The operating mechanism shall be suitable for high speed reclosing and other duties
specified. During reclosing the breaker contacts shall close fully and then open. The
mechanism shall be anti-pumping and trip free (as per IEC definition) under every
method of closing.
d) The mechanism shall be such that the failure of any auxiliary spring will not prevent
tripping and will not cause trip or closing operation of the power operating devices.
e) A mechanical indicator shall be provided to show open and close position of the
breaker. It shall be located in a position where it will be visible to a man standing on
the ground level with the mechanism housing closed. An operation counter shall also
be provided in the central control cabinet.
f) Working parts of the mechanism shall be of corrosion resisting material, bearings
which require grease shall be equipped with pressure type grease fittings. Bearing pin,
bolts, nuts and other parts shall be adequately pinned or locked to prevent loosening or
changing adjustment with repeated operation of the breaker.
g) The contractor shall furnish detailed operation and maintenance manual of the
mechanism alongwith the operation manual for the circuit breaker.
6.5.2. Control
a) The close and trip circuits shall be designed to permit use of momentary-contact
switches and push buttons.
b) Each breaker pole shall be provided with two (2) independent tripping circuits, valves,
pressure switches, and coils each connected to a different set of protective relays.
c) The breaker shall normally be operated by remote electrical control. Electrical tripping
shall be performed by shunt trip coils. However, provisions shall be made for local
electrical control. For this purpose a local/remote selector switch and close and trip
control switch/push buttons shall be provided in the breaker central control cabinet.
d) The trip coil shall be suitable for trip circuit supervision during both open and close
position of breaker.
e) Closing coil and associated circuits shall operate correctly at all values of voltage
between 85% and 110% of the rated voltage. Shunt trip and associated circuits shall
17 VOL-II/SEC-1 (A): Technical Details of GIS Substation
operate correctly under all operating conditions of the circuit breaker upto the rated
breaking capacity of the circuit breaker and at all values of supply voltage between
70% and 110% of rated voltage. If additional elements are introduced in the trip coil
circuit their successful operation and reliability for similar applications on circuit
breakers shall be clearly brought out in the additional information schedules. In the
absence of adequate details the offer is likely to be rejected.
f) Densimeter contacts and pressure switch contacts shall be suitable for direct use as
permissives in closing and tripping circuits. Separate contacts have to be used for each
of tripping and closing circuits. If contacts are not suitably rated and multiplying relays
are used then fail safe logic/schemes are to be employed. DC supplies for all auxiliary
circuit shall be monitored and for remote annunciations and operation lockout in case
of dc failures.
g) The auxiliary switch of the breaker shall be positively driven by the breaker operating
rod.
6.5.3. Spring operated Mechanism
a) Opening spring and closing spring with limit switch for automatic charging and other
necessary accessories to make the mechanism a complete operating unit shall also be
provided.
b) As long as power is available to the motor, a continuous sequence of the closing and
opening operations shall be possible. The motor shall have adequate thermal rating for
this duty.
c) After failure of power supply to the motor one close open operation shall be possible
with the energy contained in the operating mechanism.
d) Breaker operation shall be independent of the motor which shall be used solely for
compressing the closing spring. Facility for manual charging of the closing spring shall
also be provided. The motor rating shall be such that it required preferably not more
than 60 seconds for full charging of the closing spring.
e) Closing action of circuit breaker shall compress the opening spring ready for tripping.
f) When closing springs are discharged after closing a breaker, closing springs shall
automatically be charged for the next operation and an indication of this shall be
provided in the local and remote control cabinet.
g) Provisions shall be made to prevent a closing operation of the breaker when the spring
is in the partial charged condition.
h) Mechanical interlocks shall be provided in the operating mechanism to prevent
discharging of closing springs when the breaker is in the closed position.
18 VOL-II/SEC-1 (A): Technical Details of GIS Substation
i) The spring operating mechanism shall have adequate energy stored in the operating
spring to close and latch the circuit breaker against the rated making current and also to
provide the required energy for the tripping mechanism in case the tripping energy is
derived from the operating mechanism.
6.5.4. Hydraulically Operated Mechanism:
a) Hydraulically operated mechanism shall comprise of operating unit with power
cylinder, control valves, high and low pressure reservoir, motor etc.
b) The hydraulic oil used shall be fully compatible for the temperature range to be
encountered during operation.
c) The oil pressure switch controlling the oil pump and pressure in the high pressure
reservoir shall have adequate no. of spare contacts, for continuous monitoring of low
pressure, high pressure etc. at switchyard control room.
d) The mechanism shall be suitable for at-least two close open operations after failure of
AC supply to the motor starting at pressure equal to the lowest pressure of auto reclose
duty plus pressure drop for one close open operation.
e) The mechanism shall be capable of operating the circuit breaker correctly and
performing the duty cycle specified under all conditions with the pressure of hydraulic
operated fluid in the operating mechanism at the lowest permissible pressure before
make up.
f) Trip lockout shall be provided to prevent operations of the circuit breaker below the
minimum specified hydraulic pressure. Alarm contacts for lost of Nitrogen shall also be
provided.
g) All hydraulic joints shall have no oil leakage under the site conditions and joints shall
be tested at factory against oil leakage.
6.6. ADDITIONAL DATA TO BE FURNISHED ALONG WITH THE OFFER :
a) Drawing showing contacts in close, arc initiation, full arcing, arc extinction and open
position.
b) Data on capabilities of circuit breakers in terms of time and number of operations at
duties ranging from 100 fault currents to load currents of the lowest possible value
without requiring any maintenance or checks.
c) Curves supported by test data indicating the opening time under close open operation
with combined variation of trip coil voltage and hydraulic pressure.
6.7. TESTS
19 VOL-II/SEC-1 (A): Technical Details of GIS Substation
6.7.1. The circuit breaker alongwith its operating mechanism shall conform to the type tests
as per IEC-62271-100.
6.7.2. Routine Tests
Routine tests as per IEC: 62271-100 shall be performed on all circuit breakers. In
addition to the mechanical and electrical tests specified by IEC, the following shall also
be performed.
Speed curves for each breaker shall be obtained with the help of a suitable operation
analyzer to determine the breaker contact movement during opening, closing, auto-
reclosing and trip free operation under normal as well as limiting operating conditions
(control voltage, pneumatic pressure etc.). The tests shall show the speed of contacts
directly at various stages of operation, travel of contacts, opening time, closing time,
shortest time between separation and meeting of contacts at break make operation etc.
This test shall also be performed at site for which the necessary operation analyzer
along with necessary transducers, cables, console etc. shall be furnished as mandatory
maintenance equipment.
7.0 DISCONNECTORS (ISOLATORS)
7.1 General
Disconnectors shall be of the single-pole, group operated type, installed in the switchgear to
provide electrical isolation of the circuit breakers, the transformers, shunt reactor, double bus
and transmission lines. The disconnectors shall conform to IEC- 62271.
7.2. Construction & Design.
7.2.1 The single pole group operated disconnectors shall be operated by electric motor
suitable for use on 220V DC system and shall be equipped with a manual operating
mechanism for emergency use. The motor shall be protected against over current and
short circuit.
7.2.2 Disconnectors shall be designed as per relevant IEC. These shall be suitable to make
and break the charging currents during their opening and closing. They shall also be
able to make and break loop current which appears during transfer between bus bars.
The contact shielding shall also be designed to prevent restrikes and high local stresses
caused by transient recovery voltages when these currents are interrupted.
7.2.3 The disconnecting switches shall be arranged in such a way that all the three phases
operate simultaneously. All the parts of the operating mechanism shall be able to
20 VOL-II/SEC-1 (A): Technical Details of GIS Substation
withstand starting torque of the motor mechanism without damage until the motor
overload protection operates.
7.2.4 It shall be possible to operate the disconnecting switches manually by cranks or
handwheels. The contacts shall be both mechanically and electrically disconnected
during the manual operation.
7.2.5 The operating mechanisms shall be complete with all necessary linkages, clamps,
couplings, operating rods, support brackets and grounding devices. All the bearings
shall be permanently lubricated or shall be of such a type that no lubrication or
maintenance is required.
7.2.6 The opening and closing of the disconnectors shall be achieved by either local or
remote control. The local operation shall be by means of a two-position control switch
located in the bay module control cabinet.
7.2.7 Remote control of the disconnectors from the control room shall be made by means of
remote/ local transfer switch.
7.2.8 The disconnector operations shall be inter-locked electrically with the associated circuit
breakers in such a way that the disconnector control is inoperative if the circuit breaker
is closed.
7.2.9 Each disconnector shall be supplied with auxiliary switch having four normally open
and four normally closed contacts for future use over and above those required for
switchgear interlocking and automation purposes. The auxiliary switch contacts are to
be continuously adjustable such that, when required, they can be adjusted to make
contact before the main switch contacts.
7.2.10 The signaling of the closed position of the disconnector shall not take place unless it is
certain that the movable contacts will reach a position in which the rated normal
current, peak withstand current and short-time withstand current can be carried safely.
7.2.11 The signaling of the open position of the disconnector shall not take place unless the
movable contacts have reached such a position that the clearance between the contacts
is at least 80 percent of the rated isolating distance.
7.2.12 All auxiliary switches and auxiliary circuits shall be capable of carrying a current of at
least 10 A DC continuously.
7.2.13 The auxiliary switches shall be capable of breaking at least 2 A in a 220 V DC circuit
with a time constant of not less than 20 milliseconds.
21 VOL-II/SEC-1 (A): Technical Details of GIS Substation
7.2.14 The disconnectors and safety grounding switches shall have a mechanical key (pad
locking key) and electrical inter-locks to prevent closing of the grounding switches
when isolator switches are in the closed position and to prevent closing of the
disconnectors when the grounding switch is in the closed position.
7.2.15 The local control of the Isolator and high-speed grounding switches from the bay
module control panel should be achieved from the individual control switches with the
remote/local transfer switch set to local.
7.2.16 All electrical sequence interlocks will apply in both remote and local control modes.
7.2.17 Each disconnector shall have a clearly identifiable local, positively driven mechanical
position indicator, together with position indicator on the bay module control cabinet
and provisions for taking the signals to the control room. The details of the inscriptions
and colouring for the indicator are given as under:
SIGN COLOUR
Open position Open Green
Closed position Closed Red
7.2.18 All the disconnecting switches shall have arrangement allowing easy visual inspection
of the travel of the switch contacts in both open and close positions, from the outside of
the enclosure.
7.2.19 The disconnecting switches shall be provided with rating plates and shall be accessible
for inspection.
7.2.20 The disconnecting switches shall be capable of being padlocked in both the open and
closed positions with the operating motor automatically disengaged. The padlocking
device shall be suitable for a standard size lock with a 10 mm shank. The padlock must
be visible and directly lock the final output shaft of the operating mechanism. Integrally
mounted lock when provided shall be equipped with a unique key for such three phase
group. Master key is not permitted.
8.0 SAFETY GROUNDING SWITCHES
8.1 Three-pole, group operated, safety grounding switches shall be operated by electric motor for
use on 220 V DC ungrounded system and shall be equipped with a manual operating
mechanism for emergency use. The motor shall be protected against over-current and short
circuit.
22 VOL-II/SEC-1 (A): Technical Details of GIS Substation
8.2 Each safety grounding switch shall be electrically interlocked with its associated disconnector
and circuit breaker such that it can only be closed if both the current breaker and disconnector
are in open position. Safety grounding switch shall also be mechanically key interlocked with
its associated disconnector.
8.3 Each safety grounding switch shall have clearly identifiable local positive driven mechanical
indicator together with position indicator on the bay module control cabinet and provision for
taking the signal to Control room.
8.4 The details of the inscription and colouring for the indicator are given as under:
SIGN COLOUR
Open position Open Green
Closed position Closed Red
8.5 Interlocks shall be provided so that manual operation of the switches or insertion of the manual
operating device will disable the electrical control circuits.
8.6 Each ground switch shall be fitted with auxiliary switches having four normally open and four
normally closed contacts for use by others over and above those required for local interlocking
and position indication purposes.
8.7 Provision shall be made for padlocking the ground switches in either the open or closed
position.
8.8 All portions of the grounding switch and operating mechanism required for grounding shall be
connected together utilizing flexible copper conductors having a minimum cross sectional area
of 100 sq. mm.
8.9 The main grounding connections on each grounding switch shall be rated to carry the full short
circuit rating of the switch for 1 sec. and shall be equipped with a silver- plated terminal
connector suitable for steel strap of adequate rating for connection to the grounding grid.
8.10 The safety grounding switches shall conform to the requirements of IEC- 62271- 102
8.11 Mechanical position indication shall be provided locally at each switch and remotely at each
bay module control cabinet/ substation automation system.
9.0 HIGH SPEED MAKE PROOF GROUNDING SWITCHES:
Grounding switches located at the beginning of the line feeder bay modules shall be of the high
speed, make proof type and will be used to discharge the respective charging currents, in
23 VOL-II/SEC-1 (A): Technical Details of GIS Substation
addition to their safety grounding function. These grounding switches shall be capable of
interrupting the inductive currents and to withstand the associated TRV.
Single phase switches shall be provided with operating mechanism suitable for operation
from a 220v DC.
The switches shall be fitted with a stored energy closing system to provide fault making
capacity.
The short circuit making current rating of each ground switch shall be at least equal to its peak
withstand current rating of 125/100 kA (As applicable). The switches shall have inductive/
capacitive current switching capacity as per IEC-62271-102.
Each high speed make proof grounding switch shall have clearly identifiable local positive
driven mechanical indicator together with position indicator on the bay module control cabinet
and provision for taking the signal Control Room.
The details of the inscription and colouring for the indicator shall be as under:-
SIGN COLOUR
OPEN POSITION Open Green
CLOSED POSITION Closed Red
High speed ground switch operation should be possible locally from the bay module control
cabinet, or remotely from the control room in conjunction with opening of the associated
disconnector.
These high speed grounding switches shall be electrically interlocked with their associated
circuit breakers and disconnectors so that the grounding switches cannot be closed if the circuit
breakers and disconnectors are closed.
Interlocks shall be provided so that the insertion of the manual operating devices will disable
the electrical control circuits.
Each high speed ground switch shall be fitted with auxiliary switches having four NO & four
NC auxiliary contacts for use by others, over and above these required for local interlocking
and position indication. All contacts shall be wired to terminal blocks in the local bay control
cabinet. Provision shall be made for padlocking the ground switches in their open or closed
position.
All portion of the grounding switches and operating mechanism required for connection to
ground shall be connected together utilizing copper conductor having minimum cross-sectional
area of 100 sq. mm.
24 VOL-II/SEC-1 (A): Technical Details of GIS Substation
The main grounding connection on each grounding switch shall be rated to carry the peak
withstand current rating of the switch for 1 sec. and shall be equipped with a silver plated
terminal connector suitable for steel strap of adequate design for connection to the grounding
grid.
The high speed make proof grounding switches shall confirm to the requirements of IEC
62271-102.
10.0 INSTRUMENT TRANSFORMERS
10.1. Instrument Transformers:
10.1.1 Current Transformers
A) General:
i. The current transformers and accessories shall conform to IEC : 60044-1 and
other relevant standards except to the extent explicitly modified in the
specification.
ii. The particulars of the various cores may change within reasonable limits as per
the requirements of protection relay supplier. The manufacturer is required to
have these values confirmed from the purchaser before proceeding with design of
the cores. The other characteristics of CTs shall be as given in TECHNICAL
PARAMETER of Current Transformer.
B) Ratios and Characteristics
The number, rating, ratios, accuracy class, etc. for the individual current transformers
secondary cores shall be in accordance with Table-1,2 & 3 Where multi-ratio current
transformers are required the various ratios shall be obtained by changing the
effective number of turns on the secondary winding.
C) Rating and Diagram Plates
Rating and diagram plates shall be as specified in the IEC specification incorporating
the year of manufacture. The rated extended current rating voltage and rated thermal
current shall also be marked on the name plate. The diagram plates shall show the
terminal markings and the relative physical arrangement of the current transformer
cores with respect to the primary terminals (P1 & P2).
The position of each primary terminal in the current transformer SF6 gas section shall
be clearly marked by two plates fixed to the enclosure at each end of the current
transformer.
25 VOL-II/SEC-1 (A): Technical Details of GIS Substation
D) Constructional Details:
a) The current transformers incorporated into the GIS will be used for protective
relaying and metering and shall be of metal- enclosed type. All the current
transformers shall have effective electromagnetic shields to protect against high
frequency transients.
b) Each current transformer shall be equipped with a marshalling box with terminals
for the secondary circuits, which are connected to the local control cubicle. The
star/delta configuration and the inter connection to the line protection panels will
be done at the CT terminal block located in the local control cubicle.
c) Current transformers guaranteed burdens and accuracy class are to be intended as
simultaneous for all cores.
d) The rated extended primary current shall be 150% at highest ratio and 200% at
ratios other than highest ratios.
e) The instrument security factor at all ratios shall be less than five (5) for metering
core. If any auxiliary CTs/reactor are used in the current transformers then all
parameters specified shall have to be met treating auxiliary CTs as an integral
part of the current transformer. The auxiliary CTs/reactor shall preferably built in
construction of the CTs.
f) The wiring diagram, for the interconnections of the three single phase CTs shall
be provided inside the marshalling box.
g) The current transformers shall be suitable for high speed auto-reclosing.
h) Provisions shall be made for primary injection testing either within CT or outside.
i) Electromagnetic shields to be provided against high frequency transients typically
1-30 MHz.
10.1.2 VOLTAGE TRANSFORMERS
A) General
The voltage transformers shall conform to IEC- 60044-2 and other relevant standards
except to the extent explicitly modified in the specification. Voltage transformers shall
be of the electromagnetic type with SF6 gas insulation. The earth end of the high
voltage winding and the ends of the secondary winding shall be brought out in the
terminal box. However, for 400 kV on the lines outdoor type Capacitive Voltage
Transformers suitable for carrier coupling shall be provided.
B) Ratios and Characteristics
26 VOL-II/SEC-1 (A): Technical Details of GIS Substation
The rating, ratio, accuracy class, connection etc. for the voltage transformers shall be in
accordance with Table-4.
C) Rating and diagram plates
Rating and diagram plate shall be provided complying with the requirements of the IEC
specification incorporating the year of manufacture and including turns ratio, voltage
ratio, burden, connection diagram etc.
D) Secondary Terminals, Earthing and Fuses
The beginning and end of each secondary winding shall be wired to suitable terminals
accommodated in a terminal box mounted directly on the voltage transformer section of
the SF6 switchgear.
All terminals shall be stamped or otherwise marked to correspond with the marking on
the diagram plate. Provision shall be made for earthing of the secondary windings
inside the terminal box.
E) The transformer shall be able to sustain full line to line voltage without saturation of
transformer.
The accuracy class will be at maximum tap. F) Constructional Details of Voltage Transformers:
i) The voltage transformers shall be located in a separate bay module on the bus and
will be connected phase- to ground and shall be used for protection, metering and
synchronization.
ii) The voltage transformers shall be of inductive type, nonresistant and shall be
contained in their own-SF6 compartment, separated from other parts of
installation. The voltage transformers shall be effectively shielded against high
frequency electromagnetic transients. The voltage transformers shall have three
secondary windings.
iii) Voltage transformers secondaries shall be protected by HRC cartridge type fuses
for all the windings. In addition fuses shall be provided for the protection and
metering windings for fuse monitoring scheme. The secondary terminals of the
VT’s shall be terminated to the stud type non-disconnecting terminal blocks in the
secondary boxes via the fuse.
iv) The voltage transformer should be thermally and dielectrically safe when the
secondary terminals are loaded with the guaranteed thermal burdens.
27 VOL-II/SEC-1 (A): Technical Details of GIS Substation
v) The accuracy of 0.2 on secondary III should be maintained throughout the entire
burden range upto 100 VA on all the three windings without any adjustments
during operation.
vi) The diagram for the interconnection of the VTs shall be provided inside the
marshalling box.
10.1.3 TESTS:
Current and voltage transformers shall conform to type tests and shall be subjected to
routine test in accordance with IEC.
Though SLD does not show separate metering CT and CVT same shall be provided for all
voltage classes in the feeders .
11.0 OUTDOOR BUSHINGS:
A) General
Outdoor bushings, for the connection of conventional external conductors to the SF6 metal
enclosed switchgear, shall be provided where specified.
The dimensional and clearance requirements for the metal enclosure will be the
responsibility of the manufacturer and their dimensions must be coordinated with the
switchgear.
Bushings shall generally be in accordance with the requirements of IEC publication 137 as
applicable.
B) Insulation levels and creepage distances
All bushings shall have an impulse and power frequency withstand level that is greater than
or equal to the levels specified for GIS.
The creepage distance over the external surface of outdoor bushings shall not be less than
31mm/kV.
C) Bushing types and fitting
Condenser type bushings will be preferred but alternative types can also be considered.
Liquid filled bushings shall be provided with liquid level gauges clearly visible from
ground level, preferably of the direct reading prismatic type or the magnetic type. Other
types of liquid level gauges will only be accepted if specifically approved.
28 VOL-II/SEC-1 (A): Technical Details of GIS Substation
D) Mechanical forces on bushing terminals
Outdoor bushings must be capable of withstanding cantilever forces due to weight of
busduct and short circuit forces. Design calculations in support of the cantilever strength
chosen shall be submitted for owners review and approval.
12.0 SURGE ARRESTORS
The surge arrestors shall conform in general to latest IEC –60099-4.
12.1 INSULATION CO-ORDINATION AND SELECTION OF SURGE ARRESTOR
The contractor shall be fully responsible for complete insulation co-ordination of switchyard
including GIS. Contractor shall carry out detailed studies and design calculations to evolve the
required parameters locations, energy capability etc. of surge arrestors such that adequate
protective margin is available between peak impulse, surge and power frequency discharge
voltages and BIL of the protected requirement. If the contractor feels that at some more
locations the surge arrestors are required to be provided the same should also be included in the
offer. The contractor shall perform all necessary studies. The report shall detail the limits of all
equipment parameters which could affect the insulation co-ordination .The report shall also
detail the characteristics of the surge arrestor and shall demonstrate that the selected arrestor’s
protective and withstand levels, discharge and coordinating currents, and arrestor ratings and
comply with the requirement of this specification. The contractor shall also consider in the
studies the open circuit breaker condition, fast transients generated by slow operation of
disconnecting switches. The study report and design calculations shall be submitted for
Owner’s approval.
12.2 Duty requirements
a) The surge arrester shall be of heavy duty station class and gapless (Metal oxide) type
without any series or shunt gaps.
b) The surge arresters shall be capable of discharging over-voltages occurring during
switching of unloaded transformers, reactors and long lines.
c) 420 kV class Surge arresters shall be capable of discharging of severe reenergisation
switching surges on a 400 kV, 450 Km long line with surge impedance of 300 ohms and
capacitance of 11986 nF/Km and over voltage factor of 2.3 p.u
d) 420 kV class arrester shall be capable of discharging energy equivalent to class 4 of IEC for
a 420 kV system on two successive operation followed immediately by 50 HZ energisation
with a sequential voltage profile as specified below:
705 kVp for 3 peaks
29 VOL-II/SEC-1 (A): Technical Details of GIS Substation
580 kVp for 0.1 Sec.
565 kVp for 1 Sec.
550 kVp for 10 Secs.
e) 245 kV class arrester shall be capable of discharging energy equivalent to class 3 of IEC for
245 kV system on two successive operations. See Vol.II-Sec.1 ( B ) for further details.
f) The reference current of the arresters shall be high enough to eliminate the influence of
grading and stray capacitance on the measured reference voltage.
2.3 Constructional Features
The nonlinear blocks shall be of inferred metal oxide material. These shall be provided in such
a way as to obtain robust construction, with excellent mechanical and electrical properties even
after repeated operations.
The arrestor enclosure shall be vertically or horizontally mounted to suit the layout of the
switchgear as suggested by the manufacturer and shall be fitted with a discharge counter
located in an easily accessible position.
The main grounding connection from the surge arrestor to the earth shall be provided by the
contractor. The size of the connecting conductor shall be such that all the energy is dissipated to
the ground without getting overheated.
12.4 Tests
In accordance with the requirements stipulated the surge arrestors shall conform to type tests
and shall be subjected to routine and acceptance tests in accordance with IEC document.
Each metaloxide block shall be tested for the guaranteed specific energy capability in addition
to the routine/acceptance test as per IEC-60099.
Test on Surge Monitors :
The Surge monitors shall also be connected in series with the test specimens during residual
voltage and current impulse withstand tests to verify efficacy of the same.
Additional routine/functional tests with one 100A and 10 kA current impulse, (8/20 micro sec.)
shall also be performed on the surge monitor.
13.0 400 kV, 220 kV, 132kV and 33kV GIS BUILDING :
a) The buildings shall house 400 kV, 220 kV, 132 kV, 33kV Gas Insulated Switchgear
(GIS) and other associated equipments inside in each of the GIS buildings.
30 VOL-II/SEC-1 (A): Technical Details of GIS Substation
b) The contractor shall submit the design & construction proposal of the building along with
necessary information, data, and drawings in the techno- commercial bid according to the
complete requirements.
14.0 Seismic Design Criteria:
The equipment shall be designed for operation in seismic zone for earthquake resistance. The
seismic loads are due to the horizontal and vertical acceleration which may be assumed to act
non concurrently. Seismic level Zone- IV, as per new IS- 1893, Year-2002 has to be considered
for the design of equipment. The seismic loads shall be equal to static loads corresponding to
the weight of the parts multiplied by the acceleration. The equipments along with its parts shall
be strong enough and sufficiently well connected to resist total operating stresses resulting from
the forces in normal operation but in case of abnormal condition shall also resist with forces
superimposed due to earthquakes. The copies of type test reports for similar rated equipment, if
tested earlier, should be furnished along with the tender. If the equipment has not been type
tested earlier, design calculations of simulated parameters should be furnished along with the
offer.
To prevent the movement of GIS sub assemblies i.e. various bay modules during the
earthquake, suitable devices shall be provided for fixing the sub assemblies to the foundation.
The contractor shall supply necessary bolts for embedding in the concrete foundation. The
fixing of GIS sub assemblies to the foundation shall be designed to withstand the seismic
events. It will also be ensured that the special devices as well as bolts shall not be over stressed.
The details of the devices used and the calculations for establishing the adequacy shall be
furnished by the supplier and shall be subject to the purchase’s approval.
15.0 PARTIAL DISCHARGE MONITORING SYSTEM & DEW POINT METER:
Portable P.D meter & Dew point meter shall be offered and shall be considered for evaluation
of bid.
16.0 QUALITY OF SF6 GAS
a) The SF6 gas insulated metal-clad switchgear shall be designed for use with SF6 gas
complying with the recommendations of IEC 376, 376A & 376B, at the time of the first
charging with gas. All SF6 gas supplied as part of the contract shall comply with the
requirements of IEC as above as a minimum & should be suitable in all respects for use
in the switchgear under all operating conditions.
b) The high pressure cylinders in which SF6 gas is supplied & stored at site shall comply
with the requirements of following standards & regulations:
31 VOL-II/SEC-1 (A): Technical Details of GIS Substation
IS : 4379 Identification of the contents of industrial gas cylinders.
IS:7311 Seamless high carbon steel cylinders for permanent & high pressure
liquefiable gases. The cylinders shall also meet Indian Boilers Regulations.
(Mandatory)
c) Test
SF6 gas shall be tested for purity, dew point, air, hydrolysable fluorides and water
contents as per IEC:376, 376A & 376B and test certificates shall be furnished to the
owner indicating all test results as per IEC standards for each lot of SF6 gas. Further
site tests for moisture, air con-tent, flash point and dielectric strength to be done during
commissioning of GIS. Gas bottles should be tested for leakage during receipt at site.
d) The contractor shall indicate diagnostic test methods for checking the quality of gas in
the various sections during service. The method proposed shall, as a minimum check
the moisture content & the percentage of purity of the gas on annual basis.
e) The contractor shall also indicate clearly the precise procedure to be adopted by
maintenance personnel for handling equipment that are exposed to the products of
arcing in SF6 Gas so as to ensure that they are not affected by possible irritants of the
skin and respiratory system. Recommendations shall be submitted for suitable
protective clothing, method of disposal of cleaning utensils and other relevant matters.
f) The contractor shall also indicate the details and type of filters used in various gas
sections, and should also submit the operating experience with such filters.
17.0 SF6 GAS MONITORING DEVICES AND ALARM CIRCUITS:-
17.1 Dial type temperature compensated gas density or density monitoring devices with associated
pressure gauge will be provided. The devices shall provide continuous & automatic monitoring
of the state of the gas & a separate device shall be provided for each gas compartment so that
each compartment can be monitored simultaneously as follows:-
1) Compartments except circuit breaker
a) Gas Refill level
This will be used to annunciate the need for the gas refilling. The contractor shall provide
a contact for remote indication.
b) 'Zone Trip' level
This is the minimum level at which the manufacturer will guarantee the insulation rating
of the assembly. Contacts shall be in accordance with requirement.
32 VOL-II/SEC-1 (A): Technical Details of GIS Substation
2) Circuit Breaker
a) 'Gas Refill' level
This will be used to annunciate the need for gas refilling. The contractor shall provide a
contact for remote indication.
b) 'Breaker Block' level
This is the minimum gas density at which the manufacturer will guarantee the rated fault
interrupting capability of the breaker. At this level the breaker block contact shall operate
& the trip-ping & closing circuit shall be blocked.
c) 'Zone Trip' level
This is the minimum level at which the manufacturer will guarantee the insulation rating
of the assembly. Contacts shall be in accordance with requirement.
The contractor should furnish temperature v/s pressure curves for each setting of density
monitor along with details of the monitoring device. It shall be possible to test all gas
monitoring relays/devices without de-energizing the primary equipment & without
reducing pressure in the main section. Plugs & sockets shall be used for test purposes. It
shall also damp the pressure pulsation while filling the gas in service, so that flickering of
the pressure switch contacts does not take place.
17.2 a) Gas Leakage
The maximum gas leakage shall not exceed 0.5% (half percent) per year for the whole
equipment and for any individual gas compartment separately.
b) Gas Supply
The contractor shall include the supply of all SF6 gas necessary for filing & putting into
operation the complete switchgear installation being supplied. In addition 20% of total
gas requirement shall be supplied in separate cylinders as spare requirement, over &
above the requirement of gas for successful commissioning.
18.0 GAS FILLING AND EVACUATING PLANT:
All the plant necessary for filling and evacuating the SF6 gas in the switchgear shall be
supplied with the contract to enable any maintenance work to be carried out. This shall include
all the necessary gas cylinders for temporarily storing the evacuated SF6 gas. The capacity of
the temporary storage facilities shall at least be sufficient for storing the maximum quantity of
33 VOL-II/SEC-1 (A): Technical Details of GIS Substation
gas that could be removed when carrying out maintenance or repair work on the switchgear and
associate equipment of at least one complete bay. Where any item of the filling and evacuating
plant is of such a weight that it cannot easily be carried by maintenance personnel, it shall be
provided with lifting hooks for lifting and moving with the overhead cranes.
The capacity of evacuation plant will be as under : Vacuum Pump: 40 M3/Hour(Nominal
a) Township Lighting: Minimum 3No. Feeders from LV board to be provided with
suitable no. of spares of each type for township lighting.
b) Any other equipment/material required for completing the specified scope.
c) AC Auxiliary power distribution system: 2no.of LT transformer, 33/0.415kVA
auxiliary transformer shall be used to feed the substation auxiliaries.
HT side of transformer 33/0.415kVA auxiliary transformer shall be connected to tertiary
of auto transformer through HT cable. Approximate route length of 100Meters per run
(maximum) has to be been consider from SEB upto auxiliary transformer. EB supply
shall be made available by contractor at the substation premises.
d) Capacitor bank: Technical particulars of capacitor bank are as follows:
Nominal Voltage 132kV 33kV
Highest System
Voltage
145kV 36kV
Design Voltage 152kV 36kV
44 VOL-II/SEC-1 (A): Technical Details of GIS Substation
Bank Rating 50MVAR 45MVAR
Bank Rating at
design voltage
66.3 MVAR 60MVAR
Sub Bank rating 12.5MVAR 7.5MVAR
Capacitor bank should be provided with NCT protection and earthing blade for each
group. The complete bank shall be controlled by a suitable circuit breaker. The
capacitor bank switching control scheme shall be MANUAL.
The capacitor banks shall be of out-door type having internal fuse units, Suitable for
operation in the specified climatic conditions and also suitable for mounting on steel
racks. The mounting arrangement: could be either a Single /Two or Three tier
arrangement.
Each group of capacitor banks shall be connected in star formation, as per the protection
scheme offered, with their neutral points ungrounded.
The number of parallel units in each series group shall be such that failure of one unit
shall not preferably create more than 10% voltage rise on other units in the bank.
The details of over-voltage imposed on remaining unit with the blowing off of each
internal fuses should be clearly mentioned. It should be clearly mentioned as to how
many elements can go off without the need to trip the capacitor bank.
Individual capacitor units of banks shall be self contained, outdoor type, having single to
two bushing with a rating as per manufacturers practice to give the required total bank
capacity at 50Hz. The bushings should be of porcelain and shall be joined to the case by
solder-sealing method. The creepage distance of bushing shall not be less than
31mm/kV of voltage stress appearing between the terminal & the case. The Bushings
shall be suitable for heavily polluted atmospheric conditions.
The impregnant shall be non-PCB & the impregnation shall be carried out under high
degree of vacuum and the units shall be of totally sealed type.
Each capacity unit shall be provided with an internal discharge resister designed to drain
out the residual charge upto 50 volts within 10 minutes after disconnection from supply.
Each capacitor unit shall have internal fuses suitably rated for load current.
Each unit shall satisfactorily operate at 130% rated KVAR including the factor of over
voltage due to harmonic currents and manufacturing tolerances.
45 VOL-II/SEC-1 (A): Technical Details of GIS Substation
Terminal and mounting arrangement may be in accordance with Manufacturer’s
standard practice.
The containers of capacitor units shall all be of sufficiently thick sheet Steel, painted
with suitable anti-rust synthetic enamel primer paint and two finishing coats of paint as
per the manufacturer’s standard practices.
The capacitor banks shall conform to latest edition of IS:13925(Part –1), 1998/IEC-70.
Mounting racks
The mounting racks shall be fabricated from suitable steel section duly hot dip
galvanised to impart durable weather resistance.
The racks shall be complete with rack insulators foundation bolts and other hardwares
etc., for assembly into complete banks. Suitable terminal connectors/ clamps for
connection with other equipments shall also be provided. All various parts including
Bolts & Nuts shall be hot dip galvanised.
The height of the racks of capacitor banks shall be such that for making electrical
connections with other equipment, proper electrical clearance is maintained.
However, the capacitor banks shall be enclosed inside the pale fencing.
Tests: The equipment shall comply with the requirements of type test as per IS: 2834
and copies of these type test reports should be submitted along with offer. The capacitor
offered must have been also endurance tested as per IEC: 871-2/IS: 13925 and copies of
reports submitted alongwith offer. The capacitors under the package shall also be type
tested as per relevant IS/IEC.
Acceptance & routine test: The equipment shall comply with all routine and
acceptance tests as per IS – 2834. Sampling to be done as per IS –2834.
34.0 LT switchgear: Contractor has to give LT Switchgear system as per the specifications
mentioned at Section-C, complete with all auxiliaries, accessories, spare parts and warranting a
trouble free safe operation of the installation.
35.0 Diagnostic Tools: List given at Annexure-I. Quantity will be minimum 1 set. However
additional items which are not mentioned at annexure and are mandatory, contractor shall
specify the same.
36.0 Mandatory Spares
46 VOL-II/SEC-1 (A): Technical Details of GIS Substation
The Mandatory Spares (Annexure-II) shall be included in the bid proposal by the contractor.
The prices of these spares shall be given by the Contractor. It shall not be binding on the Owner
to procure all of these mandatory spares.
The contractor may note that no mandatory spares shall be used during the commissioning of
the equipment. Any spares required for commissioning purpose shall be arranged by the GIS
supplier without extra cost. The unutilized spares if any brought for commissioning purpose can
be taken back by the supplier
47 VOL-II/SEC-1 (A): Technical Details of GIS Substation
TABLE-1
REQUIREMENTS FOR 420 kV CURRENT TRANSFORMER
No. of
core
Core no.
Application Current ratio
OutputBurden(VA)
Accuracy Class as Per IEC:
44-1
Min. Knee pt. Voltae
Vk
Max. CT Sec. Wdg.
Resistance (ohm)
Max. Excitation Current at Vk (in mA)
5 1 BUS DIFF CHE-CK
3000- 2000- 1000/1
- - 2000/ 2000/ 1000
15/10/5 20on3000/1tap 30on2000/1tap 60on1000/1tap
2 BUS DIFF
MAIN
3000- 2000- 1000/1
- - 2000/ 2000/ 1000
15/10/5 20on3000/1tap 30on2000/1tap 60on1000/1tap
3 METERING 3000- 2000- 1000/1
- - -
4 TRANS BACK
UP/ LINE
PRTN.
3000- 2000- 1000/1
4000/ 4000/ 2000
15/10/5 20on3000/1tap 30on2000/1tap 60on1000/1tap
5 TRANS DIFF/ LINE
PRTN.
3000- 2000- 1000/1
4000/ 4000/ 2000
15/10/5 20on3000/1tap 30on2000/1tap 60on1000/1tap
All relaying CTs shall be of accuracy class PS as per IS: 2705
48 VOL-II/SEC-1 (A): Technical Details of GIS Substation
TABLE-2
REQUIREMENTS FOR 420 KV CURRENT TRANSFORMER
(For Transformer/ Reactor feeder)
No. of cores
Core no.
Application Current ratio
OutputBurden
(VA)
Accuracy Class as Per
IEC 44-1
Min. Knee pt. Voltage
Vk
Max. CT Sec. Wdg.
Resistance (ohm)
Max. Excitation Current at Vk (in mA)
5 1 BUS DIFF
CHE-CK
2000- 1000/1
- - 2000/ 1000
10/5 30 on 2000/1 tap. 60 on 1000/1 tap
2 BUS DIFF
MAIN
2000- 1000/1
- - 2000/ 1000
10/5 30 on 2000/1 tap. 60 on 1000/1 tap
3 METERING 2000- 1000- 500/1
20 20 20
0.2 0.2 0.2
- - -
4 TRA-NS BACK
UP/ LINE PRTN.
2000- 1000- 500/1
- - 4000/ 2000/ 1000
10/5/ 2.5
30 on 2000/1 tap. 60 on 1000/1 tap 120 on 500/1 tap
5 TRA-NS DIFF/ LINE
PRTN.
2000- 1000- 500/1
- - 4000/ 2000/ 1000
10/5/ 2.5
30 on 2000/1 tap. 60 on 1000/1 tap 120 on 500/1 tap
All relaying CTs shall be of accuracy class PS as per IS: 2705
49 VOL-II/SEC-1 (A): Technical Details of GIS Substation
TABLE-3
REQUIREMENTS FOR 245 kV CURRENT TRANSFORMER
No. of cores
Core no.
Application Current ratio
Output Burden
(VA)
Accuracy Class as Per IEC:
44-1
Min. Knee pt. Voltage
Vk
Max. CT Sec. Wdg. Resistance
(ohm)
Max. Exci-tationCurrent at Vk (in mA)
5 1 BUS DIFF
CHECK
1600- 800/1
- - 1600/ 800/
8/4 25 on 1600/1 tap. 50on 800/1 tap
2 BUS DIFF
MAIN
1600- 800/1
- - 1600/ 800/
8/4 25 on 1600/1 tap. 50on 800/1 tap
3 METERING 1600- 800/1
20 0.2 - - -
4 TRANS BACK
UP/ LINE
PRTN.
1600- 800/1
- - 1600/ 800/
8/4 25 on 1600/1 tap. 50on 800/1 tap
5 TRANS DIFF/ LINE
PRTN.
1600- 800/1
- - 1600/ 800/
8/4 25 on 1600/1 tap. 50on 800/1 tap
All relaying CTs shall be of accuracy class PS as per IS: 2705
50 VOL-II/SEC-1 (A): Technical Details of GIS Substation
TABLE-4
REQUIREMENT OF VOLTAGE TRANSFORMERS
Sl.No
PARTICULARS
400 kV
220kV
1
Rated primary voltage
420/√3 kV
245/√3 kV
2
Type
Electromagnetic, or Single phase capacitor VT
Electromagnetic
3
No. of secondaries
3
3
4
Rated voltage factor
1.2 continuous
1.2 continuous
1.5-30 seconds
1.5-30 seconds
5
Phase angle error
±20 minutes
±20 minutes
Sec I Sec II Sec III Sec I Sec II Sec III
6
Rated voltage (V)
110/√3
110/√3
110/√3
110/√3
110/√3
110/√3
7
Application
Protection
Protection
Metering
Protection
Protection
Metering
8
Accuracy
3P
3P
0.2
3P
3P
0.2
9
Output burden (VA)
(minimum)
50
50
50
50
50
50
Note: For 132kV and 33kV contractor shall propose its rating which shall be approved by the owner at the
time of contract.
51 VOL-II/SEC-1(B): Technical Particulars of GIS
SECTION-1(B)
TECHNICAL PATICULARS FOR SF6 GAS INSULATED METAL ENCLOSED SWITCHGEAR
1.0 INDOOR SWITCH GEAR TECHNICAL PARAMETER
S.No Parameter 400kV System 220kV System 132kV System 33kV System
1 Rated Voltage(kV) 400 220 132 33
2 System Highest Voltage(kV) 420 245 145 36
3 Rated Frequency(Hz) 50
4 Frequency Variation(%) +3 / -5
5 Max. design Ambient Temp.(deg C)
50
6 Rated short time withstand current rating(kA for 1 sec)
50 50 31.5 25
7 Rated Peak withstand current rating (kAp)
125 100 80 63
8 Siesmic level (kAp) Zone-IV as per IS 1893
9 Rated 1 min. power freq. withstand voltage
Dry (kVrms) 630 - - -
Dry and Wet (kVrms) - 460 275 70
10 1.2/50 microsec Lightning Impulse withstand voltage (BIL)
External (kVp) ±1550 ±1050 ±650 ±170
Internal (kVp) ±1300 ±950 ±550 -
11 250/2500 microsec switching surge impulse withstand voltage (kVp)
1050 - - -
12 Minimum Clearance in Air for Switchyard Equipment
Phase to Phase (Condr-Condr / Rod-Condr) (mm)
4000 / 4200 2100 1300 320
Phase to Earth (mm) 3500 2100 1300 320
Sectional Clearance (mm) 6500 5000 4000 3000
13 Corona Extinction Voltage (kV)
320 156 105 -
14 System X/R Ratio 30 - - -
52 VOL-II/SEC-1(B): Technical Particulars of GIS
15 Max. Radio Interference Voltage between 0.5MHz & 2.0MHz (Microvolt)
1000 at 266kVrms
1000 at 156kVrms
500 at 92kV -
16 External Creepage distance(mm/kV)
31
1.1 TECHNICAL PARTICULARS 400 kV, 220,132kV and 33kV CIRCUIT BREAKER:
S.No. PARAMETERS FOR 400kV FOR 220kV FOR 132kV FOR 33kV
a) Rated voltage kV (rms) 420 245 145 36
b) Rated frequency 50Hz
c) No. of poles 3
d) Type of circuit breaker SF6 insulated
e) Rated continuous current (A) at an ambient temperature of 40oC
Refer SLD’s
f) Rated short circuit current
50 kA 50 kA
31.5kA 25kA
g) Rated short circuit making current kAp
125 kA 100 kA 78.75 kA 62.5 kA
h) Short time current carrying capability for one second kA (rms)
50 kA 50 kA 31.5kA 25kA
i) Rated line charging interrupting current at 90 deg. Leading power factor angle (A rms)
As per IEC (The breaker shall be able to interrupt the rated line charging current with test voltage immediately before opening equal to the product of U/√3 and 1.4 as per IEC-62271-100)
j) First pole to clear factor 1.3 --
k) Rated break time as IEC (ms)
40 60 60 100
l) Total break time (ms) < 45 < 65 < 60 < 105
m) Total closing time (ms) Not more than 150 Not more than 200
Not more than 200 Not more than 200
n) Rated operating duty cycle
O-0.3s-CO-3 min-CO
o) Reclosing auto reclosing
Single phase &Three phase auto reclosing.
Single phase/Three phase
Three phase
p) Rated insulation levels
Full wave impulse with stand voltage (1.2x50 micro sec.)
- between line terminals ±1550 kVp ±1050 kVp ±650 kVp ±170 kVp
53 VOL-II/SEC-1(B): Technical Particulars of GIS
and ground
q) One minute power frequency withstand voltage
- between line terminals and ground
630 kV rms. 460 kV rms. 275 kV rms. 70 kV rms.
r) Max. radio interference voltage for frequency between 0.5 MHz and 2 MHz
1000 at 266kVrms 1000 at 156kVrms
500 at 92kVrms --
s) Max. difference in the instants of closing / opening of contacts (ms) between poles
As per IEC
t) Trip coil and closing coil voltage this Section
220 V DC with variation
u) Auxiliary Contacts Auxiliary switch shall also comply with requirements as given. independent single pole reversible contacts (from NO to NC & vice versa)
Each circuit breaker pole shall be provided with an auxiliary switch with 20% of spare – NO and 20% spare NC contact for use in future.
Each circuit breaker pole shall be provided with an auxiliary switch with 20% of spare – NO and 20% spare NC contact for use in future.
Each circuit breaker pole shall be provided with an auxiliary switch with 20% of spare – NO and 20% spare NC contact for use in future.
v) Rating of Auxiliary contacts
10A at 220 V DC 10A at 220 V DC
w) Breaking capacity of Aux. Contacts less than 20 ms.
Transformer protection shall be a multifunctional numerical relay providing following
minimum protections: -
A) Differential Protection (87 ST)
Differential protection relays shall be of high speed and high sensitivity – type suitable
for two winding transformers. Triple pole high speed, second harmonic restraint dual
slope, % biased differential relay shall be of 10 to 50% of rated current in steps of
10%. The relay shall ensure its stability for through faults when one CT saturates
and on magnetising inrush without sacrificing its speed of operation for in zone
faults. The relays shall have magnetizing inrush restraint & over-excitation/
overfluxing restraint. The operating time of the relay shall be less than 30-35ms at
2 times the set range. It shall also be able to clear terminal faults instantaneously.
For this purpose, an instantaneous high set overcurrent unit shall be provided. Suitable
interposing CTs of adequate rating shall be supplied if necessary. The relay shall be
numerical micro-processor based with HMI and communication facilities.
B) Back-up Overcurrent Protection (50/51)
Numerical over-current relay with instantaneous high set element having high reset
factor shall be provided for this purpose. The element shall have a programmable
current setting range and time setting range.
C) Back-up Earth fault Protection (51 STN)
Earth fault protection of the inverse time type with a programmable characteristic and
programmable current and time settings shall be provided for this purpose
D) Restricted Earth Fault Protection (64 REF ST)
A high speed circulating current differential protection with a programmable setting
range shall be provided. The relay shall be tuned to 50 Hz frequency and shall not
operate on any harmonic input.
E) Overload Protection (51OL)
One single pole time over current protection with programmable current setting range
and time setting ranges shall be provided for alarm, for monitoring loading on LV
winding of station transformer.
F) Over-flux Protection(99A)
Volume-II: Section-A(C&P, SAS)
71
The over-fluxing protection shall operate on the voltage/frequency ratio which shall
be continuously adjustable between 1.5 to 3.0 V/Hz. The nominal value under rated
voltage and frequency condition is 2.2. The protection shall have one highest trip
setting with a definite delay feature. The time delay shall be adjustable in the range
(0.5 to 5.0 sec.).
Another low set with adjustable inverse time characteristics set to trip the station
transformer shall also be provided. Over-fluxing protection shall be provided
separately (on LV) meeting the above requirement.
G) The following relays shall also be provided for power transformer:
a) Trip relay coil supervision
b) Wipe out timers as applicable
c) Breaker contact multiplying relays
d) PT breaker failure protection relay (50Z)
e) PT breaker trip coil supervision relay
f) Master trip relays. Two independent sets
H) 33 kV feeder Relay Panel for LT Transformer: (Rating of transformer shall be
finalized during detail engineering)
The supply and installation of auxiliary transformer should be complete with necessary
control and protection which shall not be limited to the following:
i) Non-directional triple pole IDMT over current and earth fault relays with instantaneous
(high set) element – 2 nos. (2 O/C + 1 E/F). This can be a 3 element relay also in one
casing.
ii) Electrical reset master trip relay for tripping commands for all protections – 2 nos.
iii) Trip circuit supervision relay- 2Nos
iv) Trip relay supervision relay- 2Nos
v) D.C supervision relay-2Nos.
I) 132kV/ 33 kV Capacitor Bank Relay Panel
i) Capacitor bank unbalance relay
Volume-II: Section-A(C&P, SAS)
72
ii) A two pole IDMT over current relay & single pole IDMT earth fault relay shall be provided
iii) Over voltage relay
iv) High speed tripping relay-2Nos.
v) 2-Trip circuit supervision relay for pre and post closing supervision of trip coil.
vi) Suitable size cable gland.
vii) Trip relay supervision relay- 2 Nos
viii) D.C supervision relay-2Nos.
J) Auxiliary Relays
Separate voltage operated, hand/electrical-reset auxiliary relays for trip and non-trip
functions on account of the following:
a) Buchholz (main)
b) Oil level
c) Winding temperature
d) Oil temperature
e) PRD
f) Cooler system trouble
g) Fire protection
h) OLTC Buchholz
These relays shall be provided with required number of contacts.
K) PLCC and SDH both systems are available for protection and standby and these should
be taken into account by the contractor for control and protection.
19.0 FAULT RECORDER
19.1 The fault recorder shall be provided for transmission line and the fault recorder in-built
feature of line distance relay is also acceptable provided the requirements of following
clauses are met
19.2 Fault recorder shall be microprocessor based and shall be used to record the graphic
form of instantaneous values of voltage and current in all three phases, open delta
Volume-II: Section-A(C&P, SAS)
73
voltage & neutral current, open or closed position of relay contacts and breakers during
the system disturbances.
19.3 The Fault recorder shall consist of individual acquisition units, one for each feeder and
an Evaluation unit which is common for the entire Substation. Whenever, more than
one acquisition units are connected to an Evaluation unit, necessary hardware and
software shall also be supplied for on line transfer of data from all acquisition units to
Evaluation unit. The acquisition unit is connected with evaluation unit being supplied
as described in section sub-station automation through bus conforming to IEC 61850.
In case of extension sub-station, one set of evaluation software shall be supplied and
loaded in existing fault recorder evaluation unit. Automatic uploading of disturbance
files from acquisition unit to evaluation unit shall be done through existing station bus
only conforming to IEC 61850. Necessary configuration/updation shall be in the scope
of the contractor.
19.4 Fault recorder shall have atleast 8 analogue and 16 digital channels for each feeder.
19.5 Acquisition units shall acquire the Disturbance data for the pre fault and post fault
period and transfer them to Evaluation unit automatically to store in the hard disk. The
acquisition units shall be located in the protection panels of the respective feeders.
19.6 The acquisition unit shall be suitable for inputs from current transformers with 1A rated
secondary and capacitive voltage transformers with 63.5V (phase to neutral voltage)
rated secondary. Any device required for processing of input signals in order to make
the signals compatible to the Fault recorder equipment shall form an integral part of it.
However, such processing of input signals shall in no way distort its waveform.
19.7 The equipment shall be carefully screened, shielded, earthed and protected as may be
required for its safe functioning. Also, the Fault recorder shall have stable software,
reliable hardware, simplicity of maintenance and immunity from the effects of the
hostile environment of EHV switchyard which are prone to various interference signals
typically from large switching transients.
19.8 The evaluation unit hardware shall be as described in clause no. 4.0 of section
substation automation.
19.9 Necessary software for transferring the data automatically from local evaluation unit to
a remote station and receiving the same at the remote station through
PLCC/VSAT/LEASED LINE shall be provided.
Volume-II: Section-A(C&P, SAS)
74
19.10 Evaluation software shall be provided for the analysis and evaluation of the recorded
data made available in the PC under DOS/WINDOWS environment. The Software
features shall include repositioning of analog and digital signals, selection and
amplification of time and amplitude scales of each analog and digital channel,
calculation of MAX/MIN frequency, phase difference values, recording of MAX/MIN
values etc. of analog channel, group of signal to be drawn on the same axis etc, listing
and numbering of all analog and digital channels and current, voltage, frequency and
phase difference values at the time of fault/tripping. Also, the software should be
capable of carrying out Fourier /Harmonic analysis of the current and voltage wave
forms. The Disturbance records shall also be available in COMTRADE format ( IEEE
standard- Common Format for Transient data Exchange for Power System )
19.11 The Evaluation unit shall be connected to the printer to obtain the graphic form of
disturbances whenever desired by the operator.
19.12 Fault recorder acquisition units shall be suitable to operate from 220V DC or 110V DC
as available at sub-station Evaluation unit along with the printer shall normally be
connected to 230V, single phase AC supply. In case of failure of AC supply,
Evaluation unit and printer shall be switched automatically to the station DC through
Inverter of adequate capacity which shall form a part of Distance recorder system. The
inverter of adequate capacity shall be provided to cater the requirement specified in
section sub-station automation clause no. 8.0 and DR evaluation unit.
19.13 The acquisition unit shall have the following features
(a) Facility shall exist to alarm operator in case of any internal faults in the acquisition
units such as power supply fail, processor / memory fail etc and same shall be wired to
annunciation system.
(b) The frequency response shall be 5 Hz on lower side and 250 Hz or better on upper side.
(c) Scan rate shall be 1000 Hz/channel or better.
(d) Pre-fault time shall not be less than 100 milliseconds and the post fault time shall not
be less than 2 seconds (adjustable). If another system fault occurs during one post-fault
run time, the recorder shall also be able to record the same. However, the total memory
of acquisition unit shall not be less than 5.0 seconds
(e) The open delta voltage and neutral current shall be derived either through software or
externally by providing necessary auxiliary transformers.
Volume-II: Section-A(C&P, SAS)
75
(f) The acquisition unit shall be typically used to record the following digital channels:
1 Main CB R phase open
2 Main CB Y phase open
3 Main CB B phase open
4 Main-1 carrier received
5 Main-1 protection operated
6 Main/Tie /TBC Auto reclosed operated
7 Over Voltage -Stage-1 /2 operated
8 Reactor / Stub/TEE-1/2/UF protection operated
9 Direct Trip received
10 Main-2 carrier received
11 Main- 2/ Back Up protection operated
12 Bus bar protection operated
13 LBB operated of main /tie/TBC circuit breaker
14 Tie/TBC CB R phase open
15 Tie/TBC CB Y phase open
16 Tie/TBC CB B phase open
(g) In case the Fault recorder is in-built part of line distance protection, above digital
channels may be interfaced either externally or internally.
(h) Any digital signal can be programmed to act as trigger for the acquisition unit. Analog
channels should have programmable threshold levels for triggers and selection for over
or under levels should be possible.
19.14 The printer shall be compatible with the desktop PC and shall use Plain paper. The
print out shall contain the Feeder identity, Date and time (in hour, minute and second
up to 100th of a second), identity of trigger source and Graphic form of analogue and
digital signals of all the channels. Two packets of paper (500 sheets in each packet)
suitable forprinter shall be supplied.
Volume-II: Section-A(C&P, SAS)
76
19.15 Each Fault recorder shall have its own time generator and the clock of the time
generator shall be such that the drift is limited to ±0.5 seconds/day, if allowed to run
without synchronization. Further, Fault recorder shall have facility to synchronize its
time generator from Time Synchronization Equipment having output of following types
• Voltage signal : (0-5V continuously settable, with 50m Sec. minimum pulse duration)
• Potential free contact (Minimum pulse duration of 50 m Sec.)
• IRIG-B
• RS232C
The recorder shall give annunciation in case of absence of synchronizing within a specified time.
19.16 Substations where Time Synchronization Equipment is not available, time generator of
any one of the Fault recorders can be taken as master and time generators of other Fault
recorders and Event loggers in that station shall be synchronized to follow the master.
20.0 DISTURBANCE RECORDING
Numerical disturbance recording function shall be provided. The following requirements shall
be met:
20.1 The disturbance recorder shall record the analogue values form of the instantaneous values of
voltage and current in all three phases, the open delta voltage and the neutral current. The open
or closed position of relay contacts and circuit breakers during system disturbances shall also be
recorded.
20.2 The disturbance recorder shall comprise distributed individual acquisition units, one for each
feeder and an evaluation unit which is common for the entire substation. The acquisition units
shall acquire the disturbance data for the pre-fault, fault and post-fault periods and transfer
them to the evaluation unit automatically for storage on a mass storage device. The acquisition
unit shall be suitable for inputs from current transformers with 1 A rated secondaries and
capacitive voltage transformers with 63.5 V (phase-to neutral voltage) rated secondaries.
20.3 The acquisition units shall have the following features:
(a) A facility to alert the operator in the case of any internal faults (such as power supply fail,
processor/memory fail etc.) in any of the acquisition units and this alarm shall be wired to the
station annunciation system.
Volume-II: Section-A(C&P, SAS)
77
(b) The pre-fault time shall not be less than 200 milliseconds and the post fault time shall not be
less than 2 seconds (adjustable). If another system disturbance occurs during a post-fault run
time, the recorder shall also be able to record this subsequent disturbance. The scan rate should
be selectable in the range from 1000 Hz to 5000 Hz.
(c) The open delta voltage and neutral current shall be derived either through software or externally
by providing necessary auxiliary transformers.
(d) The acquisition unit shall be typically used to record the following digital channels:
1. Main circuit-breaker R-phase open
2. Main circuit-breaker Y-phase open
3. Main circuit-breaker B-phase open
4. Main 1 carrier received
5. Main 1 protection operated
6. Main/Tie auto-reclose operated
7. Overvoltage stage 1/2 operated
8. Reactor/Stub-1/2 protection operated
9. Direct trip received
10. Main 2 carrier received
11. Main 2 protection operated
12. Busbar protection operated
13. Breaker failure protection of main/tie circuit-breaker operated
14. Tie circuit-breaker R-phase open
15. Tie circuit-breaker Y-phase open
16. Tie circuit-breaker B-phase open
20.4 The necessary hardware and software shall also be supplied for the on-line transfer of data from
all acquisition units to the evaluation unit. The disturbance recording system shall be capable of
handling the full complement of feeders in the substation.
20.5 The disturbance recording equipment shall be screened, shielded, earthed and protected as may
be required for its safe and proper functioning. Also, the disturbance recorder shall have stable
Volume-II: Section-A(C&P, SAS)
78
software, reliable hardware, simplicity of maintenance and immunity from the effects of the
hostile environment of a 765 kV EHV switchyard which is prone to numerous interference
signals such as large switching transients.
20.6 The evaluation unit shall comprise all the necessary hardware and software for the proper
evaluation of disturbances. The hardware would typically consist of a desktop personal
computer (including a large high resolution colour monitor, mouse and keyboard) and a high-
speed colour printer. The desktop PC shall have Pentium P4 processor or better and shall have a
clock speed of 1600 MHz or better. The mass storage capacity of PC shall not be less than 32
GB and the RAM capacity shall not be less than 1 GB. The evaluation software required for the
analysis and evaluation of the recorded data shall run on the PC under Microsoft Windows
environment. The software features shall provide:
• clear and unambiguous display of all channels;
• the ability to reposition the analog and digital traces;
• recording of maximum/minimum values etc. of the analog channels;
• calculation of maximum/minimum frequency and phase difference values;
• grouping of signals for drawing on the same axis;
• listing and identification of all analog and digital channels as well as and current, voltage,
frequency and phase difference values at the time of fault/tripping;
• the capability of carrying out Fourier/Harmonic analysis of the current and voltage waveforms;
and,
• the availability of the disturbance records in COMTRADE format.
20.7 The evaluation unit shall be permanently connected to the printer so as to obtain the graphic
display of disturbances whenever desired by the operator. The printer shall be compatible with
the desktop PC and shall use plain paper. The print out shall contain the feeder identity, date
and time (in hour, minute and second up to 100th of a second), identity of the trigger source and
graphic representation of the analog and digital signals of all the channels.
20.8 The disturbance recorder acquisition units shall be suitable to operate from the station DC. The
evaluation unit along and the printer shall normally be connected to the 230 V, single phase AC
supply. In the case of a failure of the AC supply, the evaluation unit and printer shall be
automatically switched to the station DC through an inverter of adequate capacity and which
shall form part of disturbance recording system.
Volume-II: Section-A(C&P, SAS)
79
20.9 The disturbance recorder shall be capable of being triggered by the following user specified
quantities:
(a) external start, both software and hardware
(b) cross triggering of groups of channels, either software or hardware or both
(c) binary channel (NO and NC contacts)
(d) overvoltage and undervoltage
(e) overcurrent
(f) negative sequence voltage
(g) zero sequence voltage
(h) rate of change, voltage or current
(i) overfrequency or underfrequency
(j) logical or Boolean expressions, programmable
(k) power swing
(l) rate of change of active or reactive power
20.10 The disturbance recorder shall have its own time generator and the clock of the time generator
shall be such that the drift is limited to less than ± 0.5 seconds per day, if allowed to run
without synchronization. Further, the disturbance recorder shall have the facility to synchronize
its time generator from the station Time Synchronization Equipment using IRIG-B. The
recorder shall give an alarm in the case of the absence of the synchronizing pulse for a pre-
determined time.
21.0 DISTANCE TO FAULT LOCATOR
a) be electronic or microprocessor based type.
b) be 'On-line' type
c) be suitable for breaker operating time of 2 cycles
d) have built-in display unit
e) the display shall be directly in percent of line length or kilometres without requiring any further
calculations
Volume-II: Section-A(C&P, SAS)
80
f) have an accuracy of 3% or better for the typical conditions defined for operating timings
measurement of distance relays .
g) The above accuracy should not be impaired under the following conditions:
• presence of remote end infeed
• predominant D.C. component in fault current
• high fault arc resistance
• severe CVT transients
h) shall have mutual zero sequence compensation unit if fault locator is to be used on double
circuit transmission line.
i) built in feature of line distance relay is acceptable provided the requirements of above clauses
are met.
22.0 TIME SYNCHRONISATION EQUPMENT
22.1 The Time synchronisation equipment shall receive the co-ordinated Universal Time (UTC)
transmitted through Geo Positioning Satellite System (GPS) and synchronise equipments to the
Indian Standard Time in a substation.
22.2 Time synchronisation equipment shall include antenna, all special cables and processing
equipment etc.
22.3 It shall be compatible for synchronisation of Event Loggers, Disturbance recorders and
SCADA at a substation through individual port or through Ethernet realised through optic fibre
bus.
22.4 Equipment shall operate up to the ambient temperature of 50 degree centigrade and 80%
humidity.
22.5 The synchronisation equipment shall have 2 micro second accuracy. Equipment shall give real
time corresponding to IST (taking into consideration all factors like voltage, & temperature
variations, propagation & processing delays etc).
22.6 Equipment shall meet the requirement of IEC 60255 for storage & operation.
22.7 The system shall be able to track the satellites to ensure no interruption of synchronisation
signal.
Volume-II: Section-A(C&P, SAS)
81
22.8 The output signal from each port shall be programmable at site for either one hour, half hour,
minute or second pulse, as per requirement.
22.9 The equipment offered shall have six (6) output ports. Various combinations of output ports
shall be selected by the customer, during detailed engineering, from the following :
• Potential free contact (Minimum pulse duration of 50 milli Seconds.)
• IRIG-B
• RS232C
• SNTP Port
22.10 The equipment shall have a periodic time correction facility of one second periodicity.
22.11 Time synchronisation equipment shall be suitable to operate from 220V DC or 110V DC as
available at Substation.
22.12 Equipment shall have real time digital display in hour, minute, second (24 hour mode) & have a
separate time display unit to be mounted on the top of control panels having display size of
approx. 100 mm height.
23.0 RELAY TEST KIT
23.1 One relay test kit shall comprise of the following equipment as detailed here under
3 sets Relay tools kits.
2 nos. Test plugs
1 no. Special type test plugs for using with modular type cases (if applicable)
24.0 TYPE TESTS
24.1 The reports for following type tests shall be submitted by the contractor for the Protective
relays, Fault locator and Disturbance recorder
a) Insulation tests as per IEC 60255-5
b) High frequency disturbance test as per IEC 60255-4 (Appendix -E) 61000-4 –Class IV (Not
applicable for electromechanical relays)
c) Fast transient test as per IEC 1000-4, Level IV (Not applicable for electromechanical relays)
d) Relay characteristics, performance and accuracy test as per IEC 60255
• Steady state Characteristics and operating time
Volume-II: Section-A(C&P, SAS)
82
• Dynamic Characteristics and operating time for distance protection relays and current
differential protection relays
• For Disturbance recorder, only performance tests are intended under this item.
• Conformance test as per IEC 61850-10.
e) Tests for thermal and mechanical requirements as per IEC 60255-6
f) Tests for rated burden as per IEC 60255-6
g) Contact performance test as per IEC 60255-0-20 (not applicable for Distance to fault locator
and Disturbance recorder)
In case there is a change either in version or in model (Except firmware) of the relay, the
contractor has to submit the type test reports for the offered revision/model.
24.2 Steady state & Dynamic characteristics test reports on the distance protection relays, as type
test, shall be based on test programme specified in Appendix A on simulator/network
analyser/PTL. Alternatively, the files generated using Electromagnetic transient Programme
(EMTP) can also be used for carrying out the above tests. Single source dynamic tests on
transformer differential relay shall be/ should have been conducted based on general guidelines
specified in CIGRE committee 34 report on Evaluation of characteristics and performance of
Power system protection relays and protective systems.
1.3 33kV FEEDERS DETAIL AS BELOW:
A. LINE FEEDER BAY
Feeder bay will have following protection:
(a) Directional O/C IDMT with high set element.
(b) Directional E/F IDMT with high set element.
(c) Local breaker back-up.
(d) High speed trip relay-2nos.
(e) 2-Trip circuit supervision relay for pre and post closing supervision of trip coil.
(f) Trip relay supervision relay- 2 Nos.
(g) D.C supervision relay-2Nos.
B.TRANSFORMER BAY
Transformer bay will have following protection:
Volume-II: Section-A(C&P, SAS)
83
(a) Directional O/C IDMT with high set element.
(b) Directional E/F IDMT with high set element.
(c) Local breaker back-up.
(d) High speed trip relay-2nos.
(e) 2-Trip circuit supervision relay for pre and post closing supervision of trip coil.
(f) Trip relay supervision relay- 2 Nos.
(g) D.C supervision relay-2 Nos.
25.0 CONFIGURATION OF RELAY AND PROTECTION PANELS
The following is the general criteria for the selection of the equipments to be provided in each type of panel.
However contractor can optimise the requirement of panels by suitably clubbing the feeder protection and CB
relay panels. But the Main-I and Main-I protection cannot be provided in single panel.
The Line Protection panel for transmission lines shall consist of following protection features/schemes
S.NO.
DESCRIPTION 400kV 220 kV 132 kV
1. Main-1 Numerical Distance protection scheme
1 Set 1 Set 1 Set
2. Main-2 Numerical Distance protection scheme
1 Set 1 Set NIL
3. Over Voltage Protection Scheme 1 Set 1 Set NIL 4. Fault Recorder 1 Set 1 Set NIL 5. Disturbance Recorder 1 Set 1 Set 1 Set 6. Distance to fault Locator 1 Set 1 Set 1 Set 7. 3 phase Trip Relays Lot Lot Lot 8. Flag relays , carrier receive relays,
aux. Relays timers etc as per scheme requirements
2 Nos. 2 Nos. 1 Nos.
9. Under Voltage protection relay for isolator/earth switch
2 Nos. 2 Nos. 2 Nos.
10. Cutout, wiring and energy meter with TTB
1 Set 1 Set 1 Set
11. Directional back up Over current and E/F protection scheme
NIL NIL 1 Set
In a substation where 400kV and 220 KV lines are under the scope of the contract , contractor is required to give identical Main 1 and main 2 distance protection scheme for both voltage levels
TRANSFORMER PROTECTION PANEL The protection panel for Auto transformer/Transformer shall consists of the following features/schemes.
Volume-II: Section-A(C&P, SAS)
84
BREAKER RELAY PANEL The breaker relay panel shall comprise of the following
S.NO. Description With A/R With out A/R 1. Breaker failure Protection Scheme 1 No. 1 No. 2. DC supply Supervision relay 2 No. 2 No. 3. Trip Circuit supervision relays# 6 No. 6 No. 4. Autoreclose scheme with check synchronizing and
dead line charging relay 1 No. NIL
5. Flag relays, aux. relays, timers, trip relays as per scheme requirements
Lot Lot
# Trip supervision relays shall be 2 numbers for each 132KV and 33KV Circuit breaker.
Note: Equipment/relays to be provided for CB relay panel may be accommodated in the panels to be provided for Transmission Line/Transformer as applicable.
Any additional items required for successful operation and running of the system shall be provided by the
contractor without any price implication.
Relay and control panel’s quantities shall be defined during detail engineering and owner approvals shall be
3. Directional back up O/C and E/F relay with non directional high set feature 1 Set 1 set
4. Over Fluxing Protection scheme 1 Nos. 1 Nos.$
$ applicable only for 400/220kV X’former & 765/400 Transformer5. Overload protection scheme 1 Nos.
6. Three phase trip relays 2 Nos. 2 Nos.
7. CVT selection relays as per scheme requirement Lot Lot
8. Cutout and wiring with TTB for energy meter 1 Set 1 set
9. Transformer Neutral Current relay for 765/400 KV transformer. 1 Set 1 set
Volume-II: Section-A(C&P, SAS)
85
taken.
26.0 ERECTION AND MAINTENANCE TOOL EQUIPMENTS
All special testing equipment required for the installation and maintenance of the apparatus instruments
devices shall be furnished in relevant schedule
27.0 TROPICALISATION
Control room will be normally air-cooled/air- conditioned. All equipments shall however be suitable for
installation in a tropical monsoon area having hot, humid climate and dry and dusty seasons with
ambient conditions specified in the specification. All control wiring, equipment and accessories shall be
protected against fungus growth, condensation, vermin and other harmful effects due to tropical
environment.
28.0 MONITORING, CONTROL & PROTECTION FOR AUXILIARY TRANSFORMER:
Suitable monitoring, control (operation of associated circuit breaker & isolator) and protection for
630/800/1000KVA transformer, connected to tertiary winding of auto transformer for the purpose of
auxiliary supply shall be provided by the contractor. Over current and open delta protection is required
to be provided for the auxiliary transformer. These protection and control shall be also be acceptable as
built in feature either in the bay controller to be provided for the auxiliary system or in the control &
protection IEDs to be provided for autotransformer.
1.4 Energy Meters
Energy Metering System (ABT-Compliant Energy Meters)
Energy Metering System for the 400/220/132/33kV with Energy Meters, Metering Masterm Station, Meter Reading Instrument, networking accessories and software, including panels for the following Bays at each of seven substations if ordered:
ABT-Compliant Energy Meters for 1. 400/220/132/33kV Line Bays 2. Transformer Bays Energy meter at all voltage levels should be provided as per the CEA Regulations.
1.5 Constructional Features (CRP)
1. CONSTRUCTIONAL FEATURES
Volume-II: Section-A(C&P, SAS)
86
1.1. Simplex panel shall consist of a vertical front panel with equipment mounted thereon
and having wiring access from front for relay panels. Doors shall have handles with
either built in locking facility or will be provided with pad-lock.
1.2. Relay panels shall be of simplex type design as indicated. It is the responsibility of the
Contractor to ensure that the equipment specified and such unspecified complementary
equipment required for completeness of the protective/control schemes is properly
accommodated in the panels without congestion and if necessary, provide panels with
larger dimensions. No price increase at a later date on this account shall be allowed.
However, the width of panels that are being offered to be placed in existing switchyard
control rooms, should be in conformity with the space availability in the control room.
1.3. Panels shall be completely metal enclosed and shall be dust, moisture and vermin
proof. The enclosure shall provide a degree of protection not less than IP-31 in
accordance with IS:2147.
1.4. Panels shall be free standing, floor mounting type and shall comprise structural frames
completely enclosed with specially selected smooth finished, cold rolled sheet steel of
thickness not less than 3 mm for weight bearing members of the panels such as base
frame, front sheet and door frames, and 2.0mm for sides, door, top and bottom portions.
There shall be sufficient reinforcement to provide level transportation and installation.
1.5. All doors, removable covers and panels shall be gasketed all around with synthetic
rubber gaskets Neoprene/EPDM generally conforming with provision of IS 11149.
However, XLPE gaskets can also be used for fixing protective glass doors. Ventilating
louvers, if provided shall have screens and filters. The screens shall be made of either
brass or GI wire mesh
1.6. Design, materials selection and workmanship shall be such as to result in neat
appearance, inside and outside with no welds, rivets or bolt head apparent from outside,
with all exterior surfaces tune and smooth.
1.7. Panels shall have base frame with smooth bearing surface, which shall be fixed on the
embedded foundation channels/insert plates. Anti vibration strips made of shock
absorbing materials which shall be supplied by the contractor, shall be placed between
panel & base frame.
Volume-II: Section-A(C&P, SAS)
87
1.8. Cable entries to the panels shall be from the bottom. Cable gland plate fitted on the
bottom of the panel shall be connected to earthing of the panel/station through a
flexible braided copper conductor rigidly.
1.9. Relay panels of modern modular construction would also be acceptable.
2.1. MOUNTING
2.1. All equipment on and in panels shall be mounted and completely wired to the terminal
blocks ready for external connections. The equipment on front of panel shall be
mounted flush. No equipment shall be mounted on the doors. Equipment mounting on
rear side of panel shall not be acceptable.
2.2. Equipment shall be mounted such that removal and replacement can be accomplished
individually without interruption of service to adjacent devices and are readily
accessible without use of special tools. Terminal marking on the equipment shall be
clearly visible.
2.3. The Contractor shall carry out cut out, mounting and wiring of the free issue items
supplied by others which are to be mounted in his panel in accordance with the
corresponding equipment manufacturer's drawings. Cut outs if any, provided for future
mounting of equipment shall be properly blanked off with blanking plate.
2.4. The centre lines of switches, push buttons and indicating lamps shall be not less than
750mm from the bottom of the panel. The centre lines of relays, meters and recorders
shall be not less than 450mm from the bottom of the panel
2.5. The centre lines of switches, push buttons and indicating lamps shall be matched to
give a neat and uniform appearance. Likewise the top lines of all meters, relays and
recorders etc. shall be matched.
2.6. No equipment shall be mounted on the doors.
2.7. At existing station, panels shall be matched with other panels in the control room in
respect of dimensions, colour, appearance and arrangement of equipment (centre lines of
switches, push buttons and other equipment) on the front of the panel.
(a) Shall have removable gland plates with glands made of brass and suitable for
armoured cables
(b) It is the responsibility of the contractor to ensure that the equipment specified and such
unspecified complementary equipment required for completeness of the
Volume-II: Section-A(C&P, SAS)
88
protective/control schemes is properly accommodated in the panels without
congestion and if necessary, provide panels with larger dimensions. No price increase
at a later date on this account shall be allowed. However, the width of panels that are
being offered to be placed in existing switchyard control rooms, should be in
conformity with the space availability in the control room.
(c) Shall be provided with necessary arrangements for receiving, distributing,
isolating and fusing of AC & DC supplies for various circuits for control,
signaling, lighting, interlocking, etc. Selection of main and sub-circuit fuse rating
shall ensure selective clearance of the sub-circuit faults.
(d) Voltage circuits for protection and metering shall be protected by fuses. Suitable
fuse failure relays shall be provided to give an alarm for voltage circuits of
protection/metering. Voltage selection scheme based on relays shall be provided for
meters wherever possible. Operation of fuse failure relays should block all voltage
based protections.
(e) The DC supplies at the individual relay and protection panels shall be monitored
by suitable relays and failure of DC supplies shall be annunciated.
B) Earthing
(a) The panels shall be equipped with an earth bus of at least 50x6 mm galvanised steel
flat or equivalent copper.
(b) Earth buses of adjoining panels shall be connected for continuity. The continuous
earth bus so formed shall be connected to main earth grid at both ends.
(c) All metallic cases of the mounted equipment shall be connected to the earthbus by
2.5 sq. mm. copper wire.
(d) One breach in such earthing shall not cause loss of earthing of any equipment.
CT/CVT neutral secondary shall only be earthed at the terminal block of the panel
through links, such that earthing of one group may be removed without disturbing
others.
(e) Looping of earth connections which would result in loss of earth connection to other
devices when the loop is broken,shall not be permitted.earthing may be done in such
a manner that no circulating current shall flow in the panel.
Volume-II: Section-A(C&P, SAS)
89
(f) An electrostatic discharge point shall be provided in each panel connected to earth
bus via 1 Mega Ohm resistor.
C) Wiring
(a) Internal wiring to be connected to external equipment shall terminate on
terminal blocks.
(b) The terminal blocks for CTs and VTs shall be provided with test links and
isolating facilities. The CT terminal blocks shall be provided with short circuiting
and earthing facilities.
(c) Shall have 20% terminals as spare terminals in each panel.
(d) All equipment mounted on front and inside of the panels shall have individual
nameplates with equipment designation engraved. Each panel shall also have
circuit/feeder designation name plate.
(e) All wiring shall be with 660V grade, single core, PVC insulated stranded
copper conductor.
(f) Wires shall be vermin proof. Minimum size of conductor shall be 1.5 sq.mm. in
general, but for CT & VT circuits it shall be 2.5 sq.mm. Minimum number of
strands shall be three.
(g) Supplier shall be solely responsible for completeness and correctness of all
the wiring, and for proper functioning of the connected equipment.
D) Colour Mimic
Colour mimic diagram showing the exact representation of the system shall be
provided in front of the control panel. Mimic colour shall be decided by the Employer
at a later date.
E) Auxiliary Equipment
All control and instrumentation switches shall be rotary operated type with escutcheon
plate showing the operating position and circuit designation. All switches shall be
flush mounted. Handles of different shapes shall be provided as approved by Owner.
Control switches for breaker or disconnecting switch shall be of spring return to
neutral type, while all other shall be stay-put type all the synchronizing switches shall
have a removable common handle, removable only in off-position. Lockable type
switches shall be provided for same application as specified by the Owner. The contact
Volume-II: Section-A(C&P, SAS)
90
combination and their operation shall ensure completeness of the scheme function and
interlock requirements. Contact ratings of the switches shall be as per relevant standards.
Contacts shall be spring assisted and contact faces shall be made pure silver.
F) Indicating Instruments
(a) Shall conform to IS: 1248
(b) Shall be suitable for the instrument transformers as indicated in the drawings
enclosed and shall be calibrated to read directly the primary quantities.
(c) Shall be calibrated and adjusted at works and shall also be tested and calibrated at
site before commissioning. All these instruments shall be flush mounted.
(d) Shall be transducer operated, having 240 deg. scale and a dial of 96x96 mm, have
an accuracy of 1.5 class and resolution of at least 50% of accuracy class
(e) Current coils shall be 120% of rated current and 10 times for 5 sec. without
loosing accuracy.
G) Energy Meters
(a) Shall be conforming to IEC: 60687/IEC 62052-11/IEC 62053-22/IS 14697.
(b) Shall carry out measurement of active energy (both import and export) and reactive energy
(both import and export) by 3 phase, 4 wire principle suitable for balanced/ unbalanced 3 phase
load.
(c) Shall have accuracy of energy measurement of 0.2 for active energy and 0.5 for reactive
energy.
(d) The active and reactive energy shall be directly computed in CT & CVT/PT primary ratings
and stored in four different registers of memory of the meter as MWH(E), MWH(I),
MVARH(E) and MVARH(I) alongwith a plus sign for export and minus sign for import.
The VARH shall be computed and stored in four separate registers corresponding to
various system voltage conditions, and these conditions shall be finalized during detailed
engineering.
(e) Shall compute the energy sent out of the station busbars during each successive 15 minute
block and store in the respective register.
(f) Shall display on demand the energy sent out during previous 15- minute block.
(g) Shall continuously integrate the energy readings of each register upto the previous 15-min.
Volume-II: Section-A(C&P, SAS)
91
block. All these readings shall be displayed on demand.
(h) Cumulative reading of each register shall be stored in a separate non-volatile memory and
displayed on line.
(i) The reading shall be stored for a period of 40 days before being erased.
(j) Shall have a built in clock and calendar having an accuracy of atleast one minute per
month or better without assistance of external time synchronizing pulse.
(k) Date/time shall be displayed on demand. The clock shall be synchronized by GPS time
synchronization equipment being provided.
(l) Each meter shall have a unique identification code provided by the contractor and shall be
marked permanently on the front and also in the non-volatile memory.
(m) The voltage monitoring of all the three voltages shall be provided. The meter shall normally
operate with power drawn from the CVT supplies.
(n) The power supply to the meter shall be healthy even with a single- phase CVT/PT supply. An
automatic backup, in the event of non availability of voltage in all the phases, shall be
provided by a built in long life battery and shall not need replacement for at least 10 years
with a continuous VT interruption of atleast 2 years. Date and time of VT interruption and
restoration shall be automatically stored in a non-volatile memory.
(o) Shall have an optical port on the front of the meter for data collection. Also the stored
data shall be continuously transferred through necessary serial/parallel ports to a local IBM
compatible PC to be supplied by the supplier. Necessary hardware and software shall be
provided for downloading data on the local PC for display and printing.
(p) The necessary software shall be provided to accept the data on line and store in memory and
on a floppy diskette and also to print the same. The data format for printing shall be finalized
during detailed engineering.
(q) The meter shall have means to test MWH accuracy and calibration at site and test terminal
blocks shall be provided for the same.
H) Recording Instruments
(a) Shall be provided for voltage, frequency, MVAR and MW.
(b) Shall be draw out type and suitable for back connection.
Volume-II: Section-A(C&P, SAS)
92
(c) Provision for automatic shorting of CT leads shall be provided when recorder is
drawn out.
(d) Shall be dual pen employing potentiometric servo principle.
(e) Shall record continuously on a calibrated 100mm(min) wide plain paper chart.
(f) The accuracy of the recording shall be 0.5 % span. Full span response time shall not
be less than 2 sec.
(g) Shall include an inverter for operating on AC supply in case of DC supply failure.
Switching shall be automatic.
I) TRANSDUCERS (If applicable)
(a) Shall conform to IEC: 688-1.
(b) The output of the transducers shall be 4-20mA/0-10mA/10-0-10mA dc as necessary
for the instruments.
(c) Accuracy class shall be 0.5 or better except for frequency transducer, which
shall have an accuracy of 0.2.
(d) Summation transducer shall be suitable for taking multiple inputs from individual
MW/MVAR transducers.
(e) Shall have dual output. One output shall be used for the indicating
instrument/recorder provided and other shall be wired upto terminal block of
the panel for Owner's use in future.
(f) Energy transducers shall be suitable for 3 phase, 4 wire connection.
1.6 Sub-station Automation System (SAS)
1.6.1 Scope
a) Individual Bay controller for each bay. The relay of each bay & BCU will
communicate with redundant ring bus.
b) The analog input should have 16 bit resolution.
c) Redundant managed switched Ethernet Local Area Network communication
infrastructure on IEC 61850 protocol with hot standby.
d) The bay shall be able to store its own disturbance records, power quality records, fault
location and sequence of events in order to tolerate the momentary loss of the
Volume-II: Section-A(C&P, SAS)
93
communication to the central part. Around 2000 event shall be stored in Bay
Controller
e) Should be suitable for Operating Temperature: 2degC to +55deg C
f) SCADA IO cabinets for receiving discrete IO if required
g) SCADA marshalling panel.
h) Gateway for remote supervisory control Centre. All the data available in BCU will be
transmitted using this gateway. The communication protocol for interfacing with RSCC
will be informed during detailed engineering.
i) The SCADA system (Sub-station Automation System) shall comprise full station and bay
control, monitoring and communication functions. It shall enable local station control
by means of a human machine interface (HMI) and control software package, which
shall contain an extensive range of system control and data acquisition (SCADA)
functions.
j) The detailed design of the SCADA to meet the requirements of this
Specification is within the manufacturer’s responsibility but subject to approval by
the Owner.
k) All software functionally complete to cater to all control Operation / Communication with
relays / Data acquisition of the electrical system.
1.6.2 System architecture
The SAS shall be based on a decentralized architecture and on a concept of bay
oriented, distributed intelligence. The typical SAS architecture shall be structured in
two levels, i.e. in a station and a bay level.
At bay level, the IED shall provide all bay functions regarding control, monitoring and
protection, inputs for status indication and output for commands. The IED should be
directly connected to the switchgear without any need for additional interposition or
transducers.
Each bay control IED shall be independent from each other and its functioning shall not
be affected by any fault occurring in any of the other bay control units of the station..
The data exchange between the devices on bay and station level shall take place via the
communication infrastructure. This shall be realized using fiber optic cables, thereby
guaranteeing disturbance free communication.
Volume-II: Section-A(C&P, SAS)
94
At station level, the entire station shall be controlled and supervised from the station
HMI. It shall also be possible to control and monitor the bay from the bay level
equipment at all times. The station level contains the station oriented functions, which
cannot be realized at bay level, e.g. alarm list or event list related to the entire station.
1.7 Communication protocol
The communication protocol for gateway to control centre must be open protocol and shall
support IEC 61850 for all levels of communication for substation automation such as bay to
station HMI, gateway to remote station etc.
1.7.2 Communication interface
The substation Automation system shall have the capability to support simultaneous
communications with multiple independent remote master stations. RHSL will supply
communication channels between the SAS and the remote control centre. The channels
will consist either of power line carrier, microwave, optical fiber, VSAT or leased line,
the details of which shall be provided during detailed engineering. The contractor shall
provide interface equipment for communicating between SAS and remote control
centre.
1.7.3 General
This SCADA shall be suitable for operation and maintenance of the complete
systems including future extensions. . The 400, 220, 132 & 33 KV controls shall be
housed in a Control Room. All control & relay panels along with SAS equipment shall
be housed in the controlled room. The control & relay panels of each bay will house its
BCU and Protection Relays.
KEMA Certification should be given for communication protocol.
1.8 System Design
General system design
The system shall be designed so that personnel without any background in microprocessor-
based technology can operate the system easily after they have been provided with some basic
training. The substation automation system shall be suitable for operation and monitoring of the
complete substation including future extensions.
The system shall be of the state of the art suitable for operation under electrical environment
present in extra high voltage substations, follow the latest engineering practice, and ensure long
Volume-II: Section-A(C&P, SAS)
95
term compatibility requirements and continuity of equipment supply and safety of the operating
staff.
System control via HMI viz Key board, Track ball / mouse operated and the following
functions shall also be provided in the HMI:
Acquisition and plausibility check of switchyard equipment status
Control of switchyard equipment
Remote checking of device parameters and optional activation of alternative parameter
sets
Display of actual measured values
Display of Integrated values (MWhr, MVARhr) of both export and import.
Display of events
Display of alarms
Display of trends
Display of trends, alarms, events etc. from cooler control panels of power transformers.
Sequence control functions
Disturbance records and fault location
System self-supervision
Hard copy printing
Transformer Tap change control and monitoring (For Power transformer only )
Maintenance, modification or extension of components shall not cause a shut-off of the whole
SCADA system.
Self-monitoring of single components, modules and communication shall be incorporated to
increase the availability and the reliability of the equipment and minimize maintenance. All
the modules shall be hot swappable.
The entire system shall be controlled and supervised from HMI. Clear control priorities shall
prevent the operation of a single equipment which can be initiated at the same time from
more than one of the various control levels, The priority shall always be on the lowest
enabled control level.
Volume-II: Section-A(C&P, SAS)
96
Inputs/outputs requirement shall be finalized during detail engineering.
Flexibility and scalability
The offered SCADA system concept shall be adaptable to various system requirements
depending on the actual switchyard configurations, depending on size, voltage levels, and
importance and configuration complexity.
1.9 Software structure
The software package shall be structured according to the Switchyard Automation architecture
system and strictly divided into various levels. An extension of the station shall be possible
with lowest possible efforts. Maintenance, modification or an extension of components of any
feeder may not force a shutdown of the parts of the system that are not affected by the system
adaptation.
Human-machine interface (HMI)
The base HMI software package for the operator and Engineering station shall include the
main SCADA functions and it shall be independent of project specific hardware version
and operating system. It shall further include tools for picture editing, engineering and system
configuration. The system shall be easy to use, to maintain, and to adapt according to
specific user requirements. Systems shall contain a library with standard functions and
applications.
System software
The system software shall be structured in various levels. This software shall be placed in a
non-volatile memory. The lowest level shall assure system performance and contain basic
functions which shall not be accessible by the application & maintenance engineer. In case of
restoration of links after failure, the software along with hardware shall be capable of
automatically synchronizing with the remaining system without any manual interface. The main
part of the application software shall consist of standard software modules built as functional
block elements.
Network management system
The contractor shall provide network management system software for following functions:-
(a) Maintain performance, resource usage, and error statistics for all managed links and
devices and present this information via displays, periodic reports and on demand reports.
Volume-II: Section-A(C&P, SAS)
97
(b) Maintain a graphical display of SAS connectivity and device status.
(c) Issue alarms when an error condition occurs.
(d) Provide facility to add and delete addresses and links.
System testing
The Supplier shall submit a test specification for factory acceptance test (FAT) and
commissioning tests of the SCADA system for approval.
If the complete system consists of parts from various suppliers or some parts are already
installed on site, the FAT shall be limited to sub-system tests. In such a case, the complete
system test shall be performed on site together with the site acceptance test (SAT).
Apart from this integrated system tests shall verify the stability of the hardware and the
software.
Field tests shall completely verify all the features of SAS hardware and software.
2.0 System Functions
Any additional items required for successful operation and running of the system
shall be provided by the contractor without any price implication.
2.1 Control
The different high voltage equipment within the station (Breakers, Isolators) shall either
be operated manually by the operator or automatically by programmed switching sequences.
The control function shall comprise:
Commands from different operator places, e.g. from Main control room HMI,
switchyard control room HMI, mimic control panel according to the principles.
Select-before execute commands
Operation from only one operator place at a time
Operation depending on conditions from other functions, such as interlocking,
synchro-check, operator mode, or external status conditions.
The control function shall also include:
Prevention of double operation
Command supervision
Volume-II: Section-A(C&P, SAS)
98
Selection of operator place
Block / de-block of operation
Block / de-block of updating of position indications
Manual setting of position indications
Overriding key of the interlocking function
Switchyard equipment run time supervision
Transformer tap changer control
Display of interlocking and blocking
Breaker position indication per phase
Alarm annunciation
Measurement display
Operation counters for circuit breakers
2.2 Control mode selection
(a) Bay level operation:-operation performed by bay IED.
(b) Emergency operation:-Possible to close or open the selected breaker with on/off push
button even during the outage of bay IED.
(c) Remote operation:-Operation performed by remotely only.
2.3 Status Supervision
The position of each circuit breaker, isolator, earthing switch, transformer tap changer etc.,
shall permanently be supervised. Every detected change of position shall be immediately
visible on the screen in the single-line diagram, recorded in the event list, and a hard copy
printout shall be produced. Alarms shall be initiated in cases when spontaneous position
changes have taken place.
Each position of an apparatus shall be indicated by two binary auxiliary switches, which are
opposite each other in normally closed (NC) and normally open (NO) position. An alarm
shall be initiated if these position indications are inconsistent or indicate an excessive
running time of the operating mechanism to change position.
Status of all the breakers, isolators, earth switches shall be supervised. All protective relay
Volume-II: Section-A(C&P, SAS)
99
alarm and trip signal shall be monitored.
2.4 Interlocking
The interlocking function prevents unsafe operation of apparatuses such as isolators and
earthing switches within a bay or station wide. Software interlocking is to be provided to ensure
that inadvertent incorrect operation of switchgear causing damage and accidents in case of false
operation does not take place for software interlocking the contractor shall describe the scenario
while an IED of another bay is switched off or fails.
An override function shall be provided, which can be enabled to by-pass the interlocking
function via a key/password, in cases of maintenance or emergency situations.
2.5 Measurements
Analog inputs for voltage and current measurements shall be connected directly from the
voltage transformers (CVT) and the current transformers (CT) without intermediate
transducers. The correlated values of active power (W), reactive power (VAr), frequency (Hz),
and the rms values for voltage (U) and current (I), power factor shall be calculated.
The integrated values of active power (MWHR) and reactive power (MVARH) for both export and
import shall also be calculated.
A high accuracy of the measurement inputs shall be possible (≤ 0.25% of full scale for U and
I). To get total optimal accuracy, the measuring channels shall be connected to the measuring
coil of the CVTs and CTs. The measured values shall be displayed locally (bay level), on the
station HMI, and in the remote control centre. Threshold limit values shall be selectable for
alarm indications.
The signals for metering shall be as per protection Diagram.
2.6 Event and alarm handling
Events and alarms shall be generated either by the switchyard equipment, by the control
devices, and by the station level unit. They shall be recorded in an event list in the station
HMI. Alarms shall be recorded in a separate alarm list and appear on the screen. All or a freely
selectable group of events and alarms shall also be printed out on an event printer. The
alarms and events shall be time tagged with a time resolution of 1 ms.
2.7 Time synchronization
The time within the SCADA shall be set from an external GPS clock synchronization
unit. The time shall then be distributed to the control / protection devices via the optical bus.
Volume-II: Section-A(C&P, SAS)
100
The time synchronization shall be performed either via the bus or via a separate wiring for
the minute pulse. An accuracy of ±1 ms within the station is required. It shall be compatible for
synchronization of event loggers, disturbance recorders and SCADA. Equipment shall meet the
requirement of IEC 60255 for storage & operation. The system shall be able to track the
satellites to ensure no interruption of synchronization signal. Equipment shall have real time
digital display.
3.0 Bay control unit
The bay unit shall use industrial grade components. The bay level unit based on microprocessor
technology, shall use numerical techniques for the calculation and evaluation of externally
input analogue signals. Unit shall incorporate select before operate control principles. Unit shall
perform all bay related functions, such as control commands, bay interlocking, data acquisition,
data storage, event recording and shall provide inputs for status indication and outputs for
commands. It will be directly connected to switchgear. The bay unit shall acquire and process
all data for the bay and transmit these to the other devices in substation system. In addition this
shall receive the operation commands from station HMI and control centre. Failure of any
single component within the equipments shall neither cause unwanted operation nor lead to a
complete system breakdown. The I/O modules shall form a part of the bay control unit and
shall provide coupling to the substation equipment. The digital inputs shall be acquired by
exception with 1 ms resolution. Contact bouncing in digital inputs shall not be assumed as
change of state.
4.0 HMI functions
Presentation and dialogues
Following standard pictures shall be available from the HMI:
Single line diagram showing the switching status and measured values
Control dialogues
Measurement dialogues
Blocking dialogues
Alarm list, station / bay oriented
Event list, station / bay oriented
System status
Volume-II: Section-A(C&P, SAS)
101
Checking of parameter setting
HMI design principles
Consistent design principles shall be provided with the HMI concerning labels, colours,
dialogues and fonts. Non-valid selections shall be dimmed out.
Object status shall be indicated using different status colours for:
Selected object under command
Selected on the screen
Not updated, obsolete value, not in use or not sampled
Alarm or faulty state
Warning or blocked
Update blocked or manually updated
Control blocked
Normal state
Process status displays and command procedures
The process status of the switchyard in terms of actual values of currents, voltages, frequency,
active and reactive powers as well as the positions of circuit breakers, isolators and
transformer tap changers are displayed in the station single line diagram.
In order to ensure a high degree of security against unwanted operation, a "select-before-
execute" command procedure shall be provided. After the "selection" of a switch, the operator
shall be able to recognize the selected device on the screen and all other switchgear shall be
blocked. After the “execution” of the command the operated switch symbol shall blink until
the switch has reached its final new position.
The operator shall only be in the position to execute a command if the switch is not blocked
and if no interlocking condition is going to be violated The interlocking statements shall be
checked by the interlocking scheme which is implemented on bay level.
After command execution the operator shall receive a confirmation that the new switching
position is reached or an indication that the switching procedure was unsuccessful with the
indication of the reason for non- functioning.
System supervision display
Volume-II: Section-A(C&P, SAS)
102
The SCADA system shall be comprehensively self-monitored that faults shall be
immediately indicated to the operator possibly before they develop into serious situations.
Such faults are recorded as faulty status in a system supervision display. This display shall
cover the status of the entire switchyard including all switchgear, IEDs, communication links,
and printers at the station level etc.
Reports
The reports shall provide time related follow-ups of measured values and calculated values.
The report shall be able to be printed out on request and automatically at pre-selected times.
Reports in specified formats will be handed over to successful contractor.
Trend display (historical data)
A trend is a time-related follow-up of process data. All types of process objects - input and
output data, binary and analogue data - shall be able to be illustrated as trends. The trends
shall be displayed in graphical form as column and curve diagrams 10 trends per screen as
maximum.
Event list
The event list shall contain events, which are important for the control and monitoring of the
switchyard. The time with 1 ms resolution hasto be displayed for each event.
The operator shall be able to call up the chronological event list on the monitor at any time
for the whole switchyard or sections of it. A printout of each display shall be possible on the
hard copy printer.
The events shall be registered in a chronological event list in which the type of event and its
time of occurrence are specified. It shall be possible to store all events in the computer. The
information shall be obtainable also from printed event log.
The event list shall contain:-
(a) Position changes of circuit breakers, isolators and earthing devices.
(b) Indication of protective relay operations
(c) Fault signals from the switchgear
(d) Indication when analogue measured values exceed upper and lower limits.
(e) Loss of communication
Filters for selection of a certain type or group of events shall be available. The filters shall be
Volume-II: Section-A(C&P, SAS)
103
designed to enable viewing of events grouped per:
(a) Date and time.
(b) Bay
(c) Device
(d) Function
(e) Alarm class
Alarm list
Faults and errors occurring in the switchyard shall be listed in an alarm list and shall be
immediately transmitted to the control centre. The alarm list shall substitute a conventional
alarm table, and shall constitute an evaluation of all station alarms. It shall contain
unacknowledged alarms and persisting faults. Date and time of occurrence shall be indicated
for 1 ms resolution.
The operator shall be able to acknowledge alarms, which shall be either audible or only
displayed on the monitor. Acknowledged alarms shall be marked at the list.
Faults that appear and disappear without being acknowledged shall be specially presented in a separate
list for fleeting alarms.
Filters for selection of a certain type or group of alarms shall be available as for events.
Object picture
When selecting an object such as a circuit breaker or isolator in the single line diagram, first
the associated bay picture shall be presented. In the selected object picture, all attributes like
Type of blocking,
Authority
Local / Remote control
RSCC / SAS
Errors, etc. shall be displayed.
Control dialogues
The operator shall give commands to the system by means of soft keys located on the
single line diagram. The keyboard shall also be possible to be used for soft key activation.
Volume-II: Section-A(C&P, SAS)
104
Data entry is performed with the keyboard.
User-authority levels
The activation of the process pictures of each object (bays, apparatus...) shall be able to be
restricted to belong to a certain user authorization group. Each user shall then be given
access-rights to each group of objects, e.g.:
Display only
Normal operation (e.g. open/close apparatus)
Restricted operation (e.g. by-passed interlock)
System administrator
For maintenance and engineering purposes of the station HMI, the following
authorization levels shall be available
No engineering allowed
Engineering/confirmation allowed
Entire system managing allowed
The access rights shall be defined by passwords assigned during the log-in procedure. Only the
system administrator shall be able to add/remove users and change access rights.
4.1 System performance
The updating times on the operator station under normal and calm conditions in the
switchyard shall be:
Function Typical values
Exchange of display (first reaction) < 1 s
Presentation of a binary change in the process display < 0.5 s
Presentation of an analogue change in the process display
< 1 sFrom order to process output < 0.5 s
From order to update of display < 1.5 s
4.2 System reliability
The SCADA system shall be designed to satisfy the very high demands for reliability and
Volume-II: Section-A(C&P, SAS)
105
availability concerning:
Solid mechanical and electrical design
Security against electrical interference (EMI)
High quality components and boards
Modular, well-tested hardware
Thoroughly developed and tested modular software
Easy-to-understand programming language for application programming
Detailed graphical documentation, IEC 1131-3, of the application software
Built-in supervision and diagnostic functions
After sales service
Security
-Experience of security requirements
-Process know-how
-Select before execute at operation
-Process status representation as double indications
Distributed solution
Independent units connected to the local area network
Back-up functions
Panel design appropriate to the harsh electrical environment and ambient conditions
Panel grounding immune against transient ground potential rise
4.3 Configuration tools
The configuration of the station HMI shall be made using the operator station in the
Windows NT environment. The various functionality shall be customized by easy to use
interactive configuration tools. Configuration shall include the visual presentation of the
object, adaptations needed in process database, and adaptations of the communication
configuration data.
4.4 Documentation
Volume-II: Section-A(C&P, SAS)
106
The following documentation to be provided for the system in the course of the project shall
be consistent, CAD supported, and of similar look/feel:
List of Drawings
Control Room Lay-out
Assembly Drawing
Single Line Diagram
SCADA I/O List
Block Diagram
Schematic/ Circuit Diagram
List of Apparatus
List of Labels
Functional Design Specification (FDS)
Test Specification for Factory Acceptance Test (FAT)
Logic Diagram
List of Signals
Operator’s Manual
Product Manuals
Calculation for uninterrupted power supply (UPS) dimensioning
Test specification for site acceptance test (SAT)
Relay setting calculation
Substation automation system architecture
Guaranteed technical parameters
Complete documentation of implemented protocols between various elements
Listing of software and loadable in CD ROM
Other documents as may be required during detailed engineering
4.5 Equipment Monitoring
Volume-II: Section-A(C&P, SAS)
107
It is envisaged that monitoring shall generally be applied not only to specific and
individual pieces of equipments but also as a complete GIS monitoring systems. This
Power System Monitoring (PSM) approach shall become integral part of SCADA and
the results shall support the accomplishment of greater benefit from using a value based, risk
management logic to select such monitoring which is appropriate for the specific
circumstances and are based on sound engineering and economic judgment.
One important aspect is that the wealth of data available from bay controller and
numerical protection devices shall be used for monitoring the condition of circuit breakers,
transformers, tap changers etc. by means of a cost effective data sharing approach. Equipment
monitoring should also be done via intranet.
4.6 Access via the control centre
Remote access to the equipment data shall be enabled via the control centers upon request.
From there all information which is related to the condition of high voltage apparatus may
be had by the respective Owners in the utility organization.
The Supplier shall envisage all the required redundant Fibre optic / Modbus interface
module on the SCADA side and the necessary OPC / Modbus Client and Server software in
his scope of supply.
4.7 Sequence of events (SOE) recording/Disturbance recording System
All required contacts /signals shall be provided in the main Plant SCADA for SOE system.
SOE inputs shall be digital inputs from each phase of line breakers, generator
transformer, station transformer, isolators, earth switches, each protection and alarm relay
(for each phase wherever applicable) position of stay put control switch position, close
and open commands from each breaker and isolator control switch etc.
4.8 Disturbance analysis
Each BCU has to support disturbance record file transfer on COMTRADE format. DR files
extracted from the Numerical Distance Protection relay has to be transferred to HMI or to
master control through Gateway.
4.9 Terminal parameter setting
It shall be possible to access all protection and control devices for reading the terminal
parameters (settings). The setting of parameters or activation of parameter sets shall be
restricted by password to the protection engineer.
Volume-II: Section-A(C&P, SAS)
108
4.10 RTU (If applicable)
A SCADA marshalling panel and SCADA I/O cabinet (RTU) shall be provided for the
Input/ Output signals (not covered by the serial links). The mode of communication between
RTU & LDC shall be agreed upon with the Owner later. Serial Communication links with the
following systems shall be provided.
5.0 System hardware
Operator Work station (OWS) & Operating cum Engineering Station (OES)
The operator stations and OES shall have independent electronics with Industrial grade
TFT Monitor and preferably using Windows NT/2000 operating system, high-resolution
full-graphics screen. Peripheral units, such as printers, shall be connected to the Bus as
specified. The Operator Cum Engineering Station shall be provided with CD R/W drive in
addition to Floppy drive.
All the Operator Stations shall have interface for Monitoring and Operation of the Switch
yard, with the help of various graphics and displays, also generate various Logs, Reports,
Alarms and Annunciation for effective operation of the Switch yard.
TFT (Thin Film Transistor) Monitor
21” Industrial grade LCD flat-panel Colour Monitor suitable for continuous operation with
Key Board, Mouse/Track ball shall be provided. Resolution shall be minimum of 1280 X
1024 pixels. The total number of character shall be minimum of 256 graphic characters +
ASCII. Minimum seven colours shall be provided. Anti reflection feature shall be provided.
The TFT shall be Desktop or console mounted. The TFTs shall be fully assignable and
functionally interchangeable.
Key Board
Membrane type keyboard shall be provided for Operator Interface with Process for
Switchyard control and display functions to access data in conjunction with control TFTs.
Printers
It shall be robust & suitable for operation with a minimum of 132 characters per line.The
printing operation shall be quiet with a noise level of less than 45 dB suitable for control room.
Events shall be printed out spontaneously in these printers as they arrive.
Each event shall be reported on one line that shall contain:
Volume-II: Section-A(C&P, SAS)
109
The event date and time
The name of the event object
A descriptive text
The state or value of the object
The information fields above shall be structured in columns for maximum readability.
All reports and graphics prints shall be printed on laser printer. One dot matrix printer shall be
exclusively used for hourly log printing. All printer shall be continuously online.
Cables
All the Instrumentation and Control cables used in this system shall have the following size:
0.8 Sq mm –Stranded FRLS Instrumentation cable.
1.5 Sq mm – Stranded FRLS control cables.
Necessary Fibre optic cables shall be included in the Contractor scope.
Uninterrupted Power Supply for SCADA
Uninterrupted power supply scheme for the SCADA system shall be envisaged as follows.
Static Inverters shall form the part of SCADA UPS system. The output of the static
Inverter shall be 110V AC single phase. The Supplier shall provide an UPS power supply
distribution board for further distribution of UPS power supply to various SCADA system
equipment. All cables from UPS system panels to UPS distribution board and further
cables from UPS DB to various SCADA system equipment are included in Supplier’s
scope.
All Power supply modules / Power packs catering to SCADA system at all levels shall be
dual redundant.
5.1 Following type test as per applicable IEC standard are to be included for a
controller/RTU/BCU to be utilized in Substation control system:
Type Test Name Type Test ConditionsInsulation Resistance IEC 60255-5 100 MΩ at 500 Vdc (CM & DM)
Dielectric Withstand IEC60255-5
IEEE C37.90
50 Hz, 1mn, 2kV (CM), 1kV (DM)
50 Hz, 1mn, 1kV (CM)
G 1.4 & 1.5 500V CM G 6 :1,5 kV CM
Volume-II: Section-A(C&P, SAS)
110
Type Test Name Type Test ConditionsHigh Voltage Impulse Test IEC 60255-5 5kV (CM), 3kV (DM)
2kV (CM)
Groups 1 to 6 :5 kV CM & 3 kV DM(1)
Not on 1.4 & 1.5 : 5 kV CM & 3 kV DM(1)
Free Fall Test
Free Fall Packaging Test
IEC 60068-2-31
IEC 60068-2-32
Test Ec : 2 falls from 5cm
Test Ed : 2 falls from 0,5m
2 falls of 5 cm (Computer not powered)
25 falls of 50 cm (1) (2) (Packaging computer)
Vibration Response– Powered On
IEC 60255-21-1 Class 2 :
1g from 2 to 150Hz
Class 2 :
Acceleration : 1g from 10 (1) to 150HzVibration Response – Not Powered On
IEC 60255-21-1 Class 2 :
2g from 2 to 500HzClass 2 :
Acceleration : 2g from 10 (1) to 500Hz
Vibration Endurance – Not Powered On
IEC 80068-2-6 Class 2 :
1g from 10 to 150Hz
Class 2 :
Acceleration : 1g from 10 (1) to 500Hz Shocks – Not Powered On IEC 60255-21-2 Class 1 :
15g, 11 msShocks – Powered On IEC 60255-21-2 Class 2 :
10g, 11 ms Bump Test – Not Powered
O
IEC 60255-21-2 Class 1 :
10g, 16ms, 2000/axis
Seismic Test – Powered On
IEC 60255-21-3 Class 1 :
Axis H : 3,5mm – 2g
Class 2 : Acceleration : 2g
Displacement : 7,5mm selon axe H Acceleration : 1g
i l l
Volume-II: Section-A(C&P, SAS)
111
Type Test Name Type Test ConditionsDamp Heat Test–
Operating
IEC 60068-2-3 Test Ca :
+40°C / 10 days / 93% RH Cold Test - Operating IEC 60068-2-1 Test Ab :
-10°C / 96hTest Ab : - 25°c / 96 H
Cold Test – Storage IEC60068-2-1 Test Ad :
-40°C / 96h
Powered On at –25°C (for information) Powered On at –40°C (for information)
Dry Heat Test – Operating IEC 60068-2-2 Test Bd :
55°C / 96h70°C / 2h
70°c / 24 H
Dry Heat Test – Storage IEC 60068-2-1 Test Bd :
+70°C / 96h
Enclosure Protection IEC 60529 Front : IP=52
Rear : IP=30 Inrush current
(start-up)
T < 1,5 ms / I < 20 A T < 150 ms / I < 10 A
T > 500 ms / I < 1,2 In
Supply variation IEC 60255-6 Vn ± 20%
Vn+30% & Vn-25% for information Overvoltage
(peak withstand)
IEC 60255-6 1,32 Vn max
2 Vn during 10 ms (for information) Supply interruption IEC 60255-11 From 2,5 ms to 1 s at 0,8 Vn
50 ms at Vn, no malfunction (for information)
40 s interruption IEC 60255-11
Ripple (frequency fluctuations)
IEC 60255-11 12% Vn at f=100Hz or 120Hz
12% Vn at f=200Hz for information
Supply variations IEC 60255-6 Vn ± 20%
AC Voltage dips & short interruptions
EN 61000-4-11 2ms to 20ms & 50ms to 1s
50 ms at Vn, no malfunction (for information
Volume-II: Section-A(C&P, SAS)
112
Type Test Name Type Test ConditionsFrequency fluctuations IEC 60255-6 50 Hz : from 47 to 54 Hz
60 Hz : from 57 to 63 HzVoltage withstand 2 Vn during 10 ms (for information)
High Frequency
Disturbance
IEC 60255-22-1
IEC 61000-4-12
Class 3 : 2.5kV (CM) / 1kV (DM)
Class 2 : 1kV (CM)
Electrostatic discharge IEC 60255-22-2
IEC 61000-4-2
Class 4 :
8kV contact / 15 kV air Radiated Immunity IEC 60255-22-3
IEC 61000-4-3
Class 3 :
10 V/m – 80 to 1000 MHz
& t t tIEEE C37.90.2 35 V/m – 25 to 1000 MHz
Fast Transient Burst IEC 60255-22-4
IEC 61000-4-4
IEEE C37.90.1
Class 4 :
4kV – 2.5kHz (CM & DM) Class 3
2 kV - 2,5 kHz MC Class 3 :
2kV – 5kHz (CM)Surge immunity IEC 61000-4-5 Class 4 :
4kV (CM) – 2kV (DM) Class 3 :
2kV (CM) on shield
Class 4 :
Class 3 :
1 kV MC High frequency conducted immunity
IEC 61000-4-6 Class 3 :
10 V, 0.15 – 80 MHzHarmonics Immunity IEC 61000-4-7 5% & 10% de H2 à H17
Power Frequency Magnetic
Field Immunity
IEC 61000-4-8 Class 4 :
50 Hz – 30 A/m permanent – 300 A/m short time
Class 5 :
100A/m for 1mn
Power Frequency IEC 61000-4-16 CM 500 V / DM 250 V via 0.1 microF
Volume-II: Section-A(C&P, SAS)
113
Type Test Name Type Test ConditionsConducted emission EN 55022 Gr. I, class A and B : from 0.15 to 30
MHzRadiated emission EN 55022 Gr. I, class A and B : from 30 to 1000
MHz, 10m
Note: 2 Nos. NMS is to be provided for substation automation and 2 Nos. of control centre in hot and
standby mode could be at Indirapuram (400/220/33kV) Substation, and could be at Hapur
(765/400/220kV) substation.
Volume-II: Section-A(C&P, SAS)
114
Appendix‐1
Proposed strategy for Control & Protection, Automation and Communication systems
Systems
System 1 ‐Control & Protection
System 2 ‐Automation & SCADA
2.1 Automation & SCADA with in substation with suitable provision of data transfer to
remote hot & standby control centers.
2.2 SCADA systems (Hardware and software) for establishing remote hot & standby control centers to control, monitoring and event logging etc. of substations under AIS and GIS package.
System 3‐Communication
Possible scenarios
Following scenarios are possible: ‐
1. Both AIS & GIS package awarded to party `A’. In that eventuality following possibilities may
emerge:
a) All the three systems could be awarded to party `A’
b) System 1 and 2.1 could be awarded to party `A’ and system 2.2 and 3 to a neutral party `C’.
2. AIS Package to Party `A’, GIS package to party `B’. In that eventuality System‐1&2 .1 could be
awarded to party `A’ and `B’ for their respective packages and system 2.2 and 3 could be
awarded to either of the parties `A’/`B’ or to a neutral party `C’.
To facilitate award to party `C’ in scenario‐1 or A/B/C in scenarios‐2, following shall be taken care of : ‐
1. Communication and Substation SCADA shall be provided through standard protocols i.e. a) IEC-61850 with in substation(Local-system 1 and 2.1) b) IEC-104/101for remote SCADA operations and Communication (System 2.2 and 3).
2. Provide monitoring, controls & event logging etc to hot & standby master control centers (System 2.1 and 2.1)
3. To avoid conflicts SAS Commissioning shall be done by providing provision of data transfer to remote hot & standby control centers (System2.1).
4. Provide suitable gateway’s in local substation for communication to remote control center including hardware/software etc(System 2.1,2.2 and 3).
5. Provide engineering & technical support during integration with vendor's NMS.
115 Volume-II, Section-B (SDH & PLCC)
SECTION-B
TECHNICAL DETAILS OF SDH & PLCC
SDH
SDH: Synchronous Digital Hierarchy (SDH) Fiber Optic System is to be installed &
commissioned at all the 765/400kV sub-station by the contractor. The network architecture to be
implemented shall be of ring topology with adequate transmission and synchronization
protection scheme to achieve operational requirement.
The minimum configuration for OPGW equipment shall be as follows:-
SDH equipment shall be of STM-4 capacity with 63E-1(alternative 252E-1) channels.
a. Provision for extending SDH to 220kV system shall also be made by the contractor.
b. The SDH system shall be used for data transfer and standby protection.
PLCC
1.0 GENERAL
1.1 All the PLCC equipment covered under the package shall conform to the requirements of the
latest edition of the relevant IEC/IS Specifications or equivalent National Standards,
2.0 LOCATION OF EQUIPMENT
2.1 The PLCC Equipment and Line traps as specified shall be installed at the respective ends of the
transmission lines. The Contractor shall be responsible for coordinating the equipment supplied
by him with the already existing carrier equipment at the respective sub-stations. Contractor
shall also be responsible for collecting all the necessary information/data from the respective
substations/ concerned State Electricity Boards for the installation of the equipment.
3.0 GENERAL REQUIREMENT
a) In case of LILO Lines, PLCC cabinets from existing sub-station shall be shifted and
commissioned by contractor in one bay of LILO at new sub-station. Further 4 nos. digital PLCC
cabinets (Programmable to analogue as well as digital) alongwith associated equipments such as
wave trap, LMU, HF cable etc. shall be procured by contractor. Out of these 4 cabinets 2 nos.
digital PLCC cabinets shall be commissioned at existing sub-station and other 2 nos. in 2nd bay
of LILO line at new sub-station.
b) Both end digital PLCC cabinets alongwith associated equipments shall be procured and
commissioned by contractor.
c) PLCC cabinets on 220kV & below network shall be provided by UPPTCL (not in scope of this
package ). However, contractor has to provide the space for PLCC cabinets and associated
equipments in control room and switchyard respectively for the same.
116 Volume-II, Section-B (SDH & PLCC)
d) 2 digital channels will be required for Main-I and Main-II protection and IIIrd Channel for Data
Transfer and Speech.
e) For line details see Table I
4.0 FREQUENCY PLANNING
4.1 For planning frequency and output power of carrier terminals Contractor may plan for a
minimum receive signal to noise ratio of 25 dB for the speech channels without companders.
The noise power in 2.1 kHz band (300-2400 Hz) may be taken as -13 dBm referred to the
coupling point of the H.T. line. An additional minus two and a half dB may be assumed for
psophometric factor. As far as coupling loss (phase to phase) is concerned the Contractor may
assume the same as 6dB at one coupling end for evaluating SNR. For protection channels the
minimum SNR shall not be less than 15 dB under adverse weather. A safety margin of 9 dB
shall be taken over and above these SNR values in order to cater for variations in line attenuation
from the computed value as inhand reserve. Frequency and output power of PLC terminals for
protection shall be planned such that the protection signal is received with full reliability even
when one of the phase is earthed or is on open circuit on the line side causing an additional
minimum loss of 6 dB.
The Contractor shall indicate the noise power in the bandwidth used for protection signaling and
shall submit the SNR calculations for speech as well as protection channels on all the line
section given in at the proposed frequencies. Sample calculations for SNR requirement and
power allocation over different channels must be furnished alongwith the bid. Maximum
permissible line attenuation shall be clearly brought out in these calculations. Further, Contractor
shall submit details of frequency planning done (including computer studies carried out and
facilities available) for PLCC links on EHV lines in the past in the relevant schedule of DRS.
Contractor must enclose one copy of computer study result done in the past along with the Bid.
4.2 Successful Contractor shall be fully responsible for the coordination required with concerned
State Electricity Boards for finalising the frequency plan.
4.3 The frequency plan will be referred to wireless Adviser/DOP Department for clearance and in
case any change in the Contractor’s recommended carrier frequency and power output is
proposed by these authorities, the Contractor shall have to modify his proposal accordingly.
Change of power output shall, however, not involve repeater stations.
5.0 PROPOSED ARRANGEMENT
5.1 The power line carrier communication equipment required by the Owner is to provide primarily
efficient, secure and reliable information link for carrier aided distance protection and direct
117 Volume-II, Section-B (SDH & PLCC)
tripping of remote-end breaker and also for speech communication between 765/400/220 kV
sub-stations. It shall include separate carrier terminals of multipurpose type for speech and
protection purposes. All carrier terminals including those for protection shall be suitable for
point to point speech communication also.
5.2 For security reasons each 765/400kV transmission line shall be protected by
Main-I and Main-II protections as given below:
Main-I Numerical Distance protection with permissive inter-tripping.
Main-II Numerical protection of a different measuring technique than that of
relay under Main I.
5.3 The requirement of carrier information on each link covered under this specification is as below:
a) One protection channel for Main-I and another for Main-II distance protection schemes.
Further these channels will also be used as main and back-up channel for direct circuit
breaker inter-tripping for 765 & 400kV lines.
In case of 765/400kVlines, speech and data channel can also be used for protection
wherever possible.
b) One speech channel with a facility to superimpose data signals upto 1200Baud.
However, the number of channels for protection signaling, speech and data
communication for SAS and Load dispatch centre shall be as per the BOQ given in price
schedule.
5.4 The equipment for protection signals shall have high degree of reliability and speed. It shall be
guaranteed to function reliably in the presence of noise impulse caused by isolator or breaker
operation. The equipment shall be suitable for direct tripping of remote end breaker for fault in
unswitched 765kV&400 kV Shunt Reactor & Operation of Buchholz relays of reactor etc. It
shall also be possible to effect direct tripping of breaker at one end when the other end breaker
opens out either manually or by relays such as Bus fault relay etc.
5.5 The time intervals between receipt of a trip command on the transmit side, its transmission over
the carrier link, reception at the far end and giving command to the trip relays at the distant end
shall not exceed 20 ms. for permissive inter tripping and 30 m sec. for direct inter-tripping even
for the longest line section.
The above timings are inclusive of operating time for auxiliary relays and interposing relays, if
any, included in the PLCC equipment.
118 Volume-II, Section-B (SDH & PLCC)
5.6 The requirement of protection signaling channel is such that security against incorrect signals
being received shall be at least two to three orders higher than reliability against a signal not
being received.
5.7 For reasons of security and reliability, phase to phase coupling for 765kV S/C & 400 kV D/C
lines shall be employed. Inter-circuit coupling shall be used for 220 D/C lines. Double
differential coupling shall also be considered for double circuit lines. Contractor must furnish
detailed write-up on methods of coupling and recommend suitable coupling mode for double-
circuit lines along with the bids. Coupling mode shall, however, be fully confirmed by
Contractor after conducting detailed computer study taking into account the transpositions of
765kV & 400 kV lines for optimum coupling mode over these line sections.
The coupling arrangement shall be fully optimized by the Contractor after conducting detailed
study of every line section individually, taking into account the temperature variations,
fittings, energy meters boards & flat DBs etc as per the requirements of various quarters,
recreation centres and transit camps. In addition to above complete earthing ( through separate
earth pit) and lightning protection for each type of quarters ,recreation centre and transit camp
shall be provided as per standard guidelines given in relevant Indian standards and code of
practices. The complete drawing for earthing and lightning protection shall be submitted to
owner for approval. The loop earthing inside the buildings shall be carried out with minimum
1Cx1.5 sqmm PVC stranded Copper wire . All materials required or earthing and lightning
protection of township buildings shall be in the scope of contractor.
The contractor shall quote lumpsum prices for each type of quarters, recreation centre and
transit camp separately, including entire scope pertaining to lighting system, earthing and
lightning protection. Any item not specifically outlined in the layouts and specifications
enclosed herein shall necessarily be included by the contractor as per applicable buildings
codes, statutory electricity rules and code of practices for the completion of scope.
3.0 DESCRIPTION OF ITEMS
3.1 DESCRIPTION OF ITEMS FOR SUBSTATION LIGHTING
The Contractor shall supply and install the following equipment and accessories in accordance
with the specification.
3.1.1 LIGHTING PANELS
172 Volume-II, Section- D (Illumination system)
i) OUTDOOR
415 AC lighting panel with 415V, 63A, 3 phase 4 wire bus and one no. 63A, TPN,
MCB with neutral unit as incomer and 20A, SP MCB as outgoing feeders, the details
are as follows.
Type Of Panel Description Detail Of Outgoing Feeders
ACP 2 Outdoor 6 nos- 20 A single pole MCB and 3 No. 32 A Triple pole MCB with Neutral and suitable timer and contactor for automatic switching.
ACP 3 Outdoor Street lighting Panel
3 nos.-32A Triple pole MCB with Neutral with suitable timer and contactor for automatic switching
Note: The number of outgoing feeders indicated above are the minimum.
ii) INDOOR
415 V indoor AC lighting panel ,63 A 3 phase 4 wire bus and one number 63 amp FP
MCB with 300ma 63 A FP RCCB. Flush mounted with per phase isolation and LED
indication lamps. The DB will be flush mounted and double door type.
Type Of Panel Description Detail Of Outgoing Feeders
ACP 1 Indoor 18 nos outgoing ,16 Amps SP MCB
220V DC indoor type change over board and 220V DC 32A two wire bus and one 32A
contractor backed up by 32A double pole MCB as incomer. The panel shall have local
push button controls. Following are the various types of panels required with control
timer.
Type Of Panel Description Detail Of Outgoing Feeders
DCP Indoor 6 nos outgoing ,16 Amps DP MCB
iii) Sub-Lighting Panels
Type Of Panel Description Detail Of Outgoing Feeders
173 Volume-II, Section- D (Illumination system)
SLP Outdoor 4 pole 32A Isolator suitable for 415V, 50 cycles AC supply, wlith LILO facility using 8 nos terminal blocks suitable for cable upto 16 mm sq cable Enclosure shall be suitable for outdoor use with IP-55 degree of protection as per IS:13947 (Part-1).
box covers, saddle terminal boxes, and all steel supporting work shall be supplied
by the Contractor. The conduit fittings shall be of the same material as conduits.
The contractor shall also supply 20 mm mm PVC conduit and accessories for
telephone wiring.
b) All unarmoured cables/wires shall run within the conduits from lighting panels to
lighting fixtures, receptacles. etc.
c) Size of conduit shall be suitably selected by the Contractor.
d) Conduit support shall be provided at an interval of 750 mm for horizontal runs
and 1000 mm for vertical runs.
e) Conduit supports shall be clamped on the approved type spacer plates or brackets
by saddles or U-bolts. The spacer plates or brackets in turn, shall be securely
fixed to the building steel by welding and to concrete or brick work by grouting
or by nylon rawl plugs. Wooden plug inserted in the masonary or concrete for
conduit support is not acceptable.
f) Where conduits are along with cable trays they shall be clamped to supporting
steel at an interval of 600 mm.
g) For directly embedding in soil, the conduits shall be coated with an asphalt-base
compound. Concrete pier or anchor shall be provided wherever necessary to
support the conduit rigidly and to hold it in place.
h) For long conduit run, pull boxes shall be provided at suitable intervals to
facilitate wiring.
186 Volume-II, Section- D (Illumination system)
i) Conduit shall be securely fastened to junction boxes or cabinets, each with a lock
nut inside and outside the box.
j) Conduits joints and connections shall be made through water-tight and rust proof
by application of a thread compound which insulates the joints. White lead is
suitable for application on embedded conduit and red lead for exposed conduit.
k) The entire metallic/PVC conduit system, shall be embedded, electrically
continuous and thoroughly grounded. Where slip joints are used, suitable
bounding shall be provided around the joint to ensure a continuous ground
circuit.
l) Conduits and fittings shall be properly protected during construction period
against mechanical injury. Conduit ends shall be plugged or capped to prevent
entry of foreign material.
iii) Wiring
a) Wiring shall be generally carried out by PVC insulated wires in conduits. All
wires in a conduit shall be drawn simultaneously. No subsequent drawings of
wires is permissible.
b) Wires shall not be pulled through more than two equivalent 90 deg. bends in a
single conduit run. Where required, suitable junction boxes shall be used.
c) Wiring shall be spliced only at junction boxes with approved type terminal strip.
d) For lighting fixtures, connection shall be teed off through suitable round conduit
or junction box, so that the connection can be attended without taking down the
fixture.
e) For vertical run of wires in conduit, wires shall be suitably supported by means
of wooden/hard rubber plugs at each pull/junction box.
f) Maximum two wires can be terminated to each way of terminal connections.
g) Separate neutral wires are to be provided for each circuit.
iv) Lighting Panels
a) The lighting panels shall be erected at the locations to be finalised during detailed
engineering.
b) Suitable foundations/supporting structures for all outdoor type lighting panels
shall be provided by the Contractor.
187 Volume-II, Section- D (Illumination system)
v) Foundation & civil works
a) Foundation for street lighting poles, panel foundation and transformer foundation
shall be done by the Contractor..
b) All final adjustment of foundation levels, chipping and dressing of foundation
surfaces, setting and grouting of anchor bolts, sills, inserts and flastening devices
shall be carried out by the Contractor including minor modification of civil works
as may be required for erection.
c) Any cutting of masonary / concrete work, which is necessary shall be done by the
Contractor at his own cost and shall be made good to match the original work.
ANNEXURE-1
S.No. Type of Lighting Fixture
Description Philips Catalogue No
CGL Catalogue No
Bajaj Catalogue No
1. F1 2x28W T5 type fluorescent lamps in industrial reflector type fixture, complete with accessories and suitable for pendent /surface mounting.
TMS 122/228 HF
T5GP228EB BTIR 228
2. FF 2x28 T5 energy efficient fluorescent lamps with low glare, mirror optics suitable for recess mounting type lighting fixture.
TBS 088/228 C5 HF
TSCQ12228EB
BTMRA 228 MATT
3. FL
2x28W T5 energy efficient fluorescent lamps with low glare mirror optics suitable for pendent/surface mounting with all accessories
TCS 398/228 D6 HF
--------------- BTSMU 228 MSS
188 Volume-II, Section- D (Illumination system)
4. TL Sleek and Functional electronic decobatten suitable for use with 1x'TLD'36W fluorescent lamp with dual tone end caps. Pre-phosphated & powder coated CRCA steel channel complete with all electrical accessories like electronic ballast, lamp holders all prewired up to a terminal block
TMS500/136 HF
DMLU14EB BC1R136WEB
5. IB 60/100w GLS lamp in Bulkhead fixtures with Cast Aluminium alloy body, suitable for column, wall,and ceiling mounting finished stove enameled silver grey outside
NXC101 IBH1110/BC BJDB100BC
6. BL Aesthetic wall/ceiling mounted luminaire suitable for 1x PL-C 13W OR 11W CFL. Low loss O.C. Copper ballast.Built in high gloss anodized reflector. Twin finish UV stabilised SAN diffuser for protection & elimination of lamp glare.
FMC21/113 TLN11 BJC111
7. SL Aesthetic ceiling mounted luminaire for Ecotone crystal/ Décor CFL of 2x9W or 1x18W. ABS housing pre-wired with porcelain lampholder. Prephospated plated CRCA gear tray.
FL343/118 CBHE29 -------------
8. BH Bulkhead luminaire suitable for use with PL-S 9W CFL. Single piece pressure diecast aluminium & cover retaining Frame. Opal acrylic cover along with a gasket made of E.P.R.
FXC 101/109 ICBH10 BJBE19
9. BLD 2X9 Or 1x18 watt CFL bollard light for landscape lighting having FRP/LLDPE housing
FGC202 /118 CFBL1229 BJBOL 03 29 CFL
10. DLR 2x18 watt CFL Downlighter with HF ballast suitable for recess mounting
FBH145/218L HF
DDLH218TG BJDR 65C 218 DL
11. DSM 1X13 WATT surface mounted CFL
FCS100/113 ----------------- BJDS110/113C WEB
12. IF Incandescent GLS lamp down light
DN622 DDLV10BC BJDR 100W
13. SF1 1 X 400W HPSV lamps in high flood lighting fixture with integral control gear
SWF 330/1X400
FAI40IH BJFL
400SV TS
14. SF2 2 X 400W HP sodium Vapour RVP302/2x400 FHD1424 BJENF 22
189 Volume-II, Section- D (Illumination system)
lamps in high flood lighting, non-integral control gear:
W
15. SF3 1 X 250W HPSV lamps in high flood lighting fixture with integral control gear:
SWF 330/1X250
FAI1125IH 250 SV TS
16. SF4 150W HP Metal halide MHNTD lamp in flood lighting fixture with integral control gear.
SWF230/150 MHN-TD
FAD1215IH/MH
BGEMF150MH DE
17. SF5 125 HP MV Lamp in weather proof post top lantern for mounting on pole top
HPC-101/125 HPF
MPT1112IL/BM/ES
BJDPTI 125 MV
18. SC 150W SON-T Tubular Sodium Vapour lamp in street lighting luminaire with toughned glass cover.
SRX-51/150 SSG2315IH. BGEST 150 SV
190 Volume-II, Section- E (Battery and Battery Charger)
SECTION-E
BATTERY & BATTERY CHARGER
1.1 GENERAL TECHNICAL REQUIREMENTS
1.1.1 All materials/components used in battery chargers and batteries shall be free from flaws
and defects and shall conform to the relevant Indian/IEC standards and good
engineering practice.
1.1.2 The DC System shall consist of two (2) float-cum-boost chargers and two (2) battery
sets for each of 220V and 48 V systems respectively.
1.1.4 Contractor shall select number of cells, float and Boost voltage to achieve following
system requirement:
System Voltage
Maximum Voltage during Float operation
Minimum voltage available when no charger working and battery fully discharged upto 1.85V per cell.
Minimum Nos of cell
220 Volt 242 Volt 198 Volt 107
48 Volt 52.8 Volt 43.2 Volt 23
Contractor shall furnish calculation in support of battery sizing, selection of number of
cells, float and Boost voltages during detailed engineering for Owners acceptance.
Battery sizing calculations shall be done as per IEEE- 485 on the basis of following
duty cycle:
220V
DC
System
Load Duration Type Of Loads
Continuous Load 3 hours Relays, IEDs, Station HMIs, spring charging, Isolator interlocking load, Miscellaneous permanently connected loads etc.