CBIP-Substation-Manual-2006 (1).pdf

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SUBSJATION LAYOUT Publication No. 299

Editors G.N. Mathur R.S. Chadha

ISO 9001 :2000

Central Board of Irrigation and Power New Delhi

MANUAL ON

SUBSTATION LAYOUT

Publication No. 299

Editors

G.N. Mathur R.S. Chadha

• CENTRAL BOARD OF IRRIGATION AND POWER Malcha Marg, Chanakyapuri, New Delhi 110 021

•

2006 ISBN No. 81-7336-306-4

"Reproduction of articles in publication in any form is permissible subject to proper acknowledgement and intimation to the publishers. The publishers have taken utmost care to avoid errors in che publication. However, the publishers arc in no way responsible for the authenticity of data or information given by the contributors." (ii)

EXPERTS COMMITIEE Chairman

Shri S.C. Misra Director (Projects) (Reul.) Power Grid Corporation of India Ltd. Members Shri J.B. Shah Chief Engineer (Transmission)

Shri Raj Kumar General Manager

Gujarat Electricity Board Sardar Patel Vidyut Bhawan Race Course, Vadodara-390 007

National Hydroelectric Power Corp.Ltd. Sector 33 NHPC Office Complex Faridabad (Haryana)

Shri P.B. Mehta Deputy Engineer (Transmission Deptt.) Gujarat Electricity Board Sardar Patel Vidyut Bhawan Race Course, Vadodara-390 007

Sbri M.H. Kshatriya Executive En3ineer (Transmission Depll.) Gujarat Electricity Board Sardar Patel Vidyut Bhawan Race Course, Vadodara-390 007

Sh ri M. Gopala Rao Chief Engineer (Constmclion) AP Transmission Corporation Limited Vidyut Soudha, Hyderabad-500 082

Shri H.G. Chabra Director /P&D (TS) Bhakra Beas Management Board 66 kV Sub Stn., industrial Arca l Sector 28, Chandigarh, Punjab

Shri S.K. Roy Mohapatra Deputy Direczor (SE& TD) Central Electricity Authority Scwa Bbawan, R.K. Puram New Dclhi-llO 066

Shri Vikas Sakscna General Manager Power Grid Corporation of India Ltd Sector 29, Plot 2, Saudamini Near IFFCO Chowk Gurgaon, Haryana

Shri M.M. Goswami Deputy General Manager (Engg. SIS) Power Grid Corporation of India Ltd Sector 29, Plot 2, Saudamini Near IFFCO Chowk Gurgaon, Haryana

Shri B.N. Saini S11perie111ending Engineer (400 kV Design) Rajasthan Rajya Vidyut Prasaran Nigam Ltd Vidyut Bhawan, Janpalh Jaipur

Shri K.S. Kattigchallimatt Chief Engineer (Reul.) Kamataka Power Transmission Corpn Ltd

Shri R. P. Lal

Shri M.K. Chowdhury Superientending Engineer (E) CP & ED

Executive Director (O&M) National Hydroelectric Power Corp.Ltd. Sector 33, NHPC Office Complex Faridabad (Haryana)

West Bengal State Electricity Board Vidyut Bhawan, Bidhannagar Block - DJ, Sector 11 Kolkata-700 091 (iti)

Shri P.R. Ganage Chief Engineer (Transmission Pla1111ing) Maharashtra State Electricity Board S"' floor, Prakashganga, E Block Plot No. C 19, Kurla Complex Bandra (E}, Mumbai-400 OS 1 Shri K.K. Shah (Alternate) Executive Engineer Design Maharashtra State Electricity Board Maharashtra State Electricity Board S"' Floor, Prakashganga, E Block Plot No. C 19, Kurla Complex Bandrn (E), Mumbai-400 OS I Shri S.K. Jain Deputy Director (T&S - If) Punjab State Electricity Board Patiala-147 001 Shri S. Ayyadurai Chief Engineer (Personnel) Tamil Nadu Electricity Board 800, Anna Salai, Chcnnai-600 002

Late Shri A.K. Kapur Fonner Executive Director Power Grid, Corporation of India Ltd. A - SS, East of Kai lash New Delhi -110 06S Shri Salish Nayar Addi. General Manager (TBEM) Integrated Office Complex Bharat Heavy Electricals Limited Lodi Road, New Dclhi-110 003 Shri Raman Gulathi Group Manager (Engg.) Alstom T&D Systems Limited A 21-24, Sector 16 Noida Shri E.V. Rao Head (Engg.) KEC International Limited B 190, MIDC Industrial Area Butibori - 441 .l08 Nagpur District

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Foreword India is on the thres'lold of high economic growth and the country's initiatives in the infrastructure sector particularly the power sector are moving fast towards a higher growth trajectory. Substations are vital links in the power systems and their improved availability based on well thought of design parameters / lay out, etc., play major role in power delivery system. The primary requirements of a good substation lay out are flexibility, reliability, ease of operation and maintenance and safety of operating personnel and equipment. Keeping in view the importance of the subject and to disseminate the practices being adopted by the various utilities for substation layout and to enable them to decide the best layout suitable to their set conditions the Central Board of Irrigation and Power Published a Manual on Layout of Sub StaticM for the first time in 1967. The Publication was revised four times from 1967 to 1996. In view of very fast technological developments in power sector it was felt desirable to comprehensively review and revise the manual once again taking into consideration the latest developments and technologies on the sub station equipment etc. The revised edition covers the basic requirements and for the sake of illustration contains typical layout for various types of bus-bar systems. This Manual includes brief discussion on the various components of auxiliary facilities required in a substation to the extent these affect station layout. It also covers other aspectS such as minimum clearances and requirements of inspection and maintenance also. I am sure that the present pubhcation will prove to be a very useful guide for the Power Utilities, Manufacturers, and concerned engineers. I appreciate the efforts. made by Expert committee in bringing out this comprehensive document. I congratulate CBIP, for their initiative and also commend the invaluable contribution of the authors, members of the Expert Group & Central Board of Irrigation and Power.

(RAKESH NATH)

New Delhi November, 2006

(v)

PREFACE The country's transmission perspective plan for Tenth & Eleventh Plan focuses on the cre~tion of the National Grid so that present Generation capacity as. well as future addition are optimally utilized. For this purpose, the massive transmission system comprising of several EHV substations and transmission Jines is being planned in the years ahead. Keeping this in view, all out efforts are required to be mad_e by the planners, designers/ engineers in the country to ensure that these substations perform in the best possible manner with minimum down time. B~side this aspect, the economic considerations and parameters relating to the safety of;lhe working personnel have to be ensured. To achieve this goal, the latest technological developments/ requirements have to be kept in view while designing these vital installations/ substations.

J

One of the objective of existence of Central Board of Irrigation.& Power is to work as a platform for the experts in the field to prepare vital technical publications in Power & Water Resources sectors for reference of practicing engineers and other users. The First Manual on Substation Layout was published by the CBT&P in the year 1967. The publication was revised four times during the period 1967 - 1996. Since last edition was published about a decade back, a feed back was received that this publication is required to be comprehensively reviewed and revised taking in to consideration the developments in the technologies on the sub station equipment and utilizing experience of the professional engineers in_volved in planning, design, development, operation and maintenance of the EHV sub stations. Accordingly a committee of experts from state utilities and PSU's was constituted under the chairmanship of Shri S.C. Misra, the then Director (Projects) POWERGRID for preparation of this revised "Manual on Substation Layout". In this publication, a serious attempt has been made to cover the basic requirements and illustrations containing typical layout for various bus-bar systems beside brief discussion on the various components of auxiliary facilities required for a modern EHV substation including other aspects such as minimum required clearances with respect to safety, inspection and maintenance of the substation. This manual is out come of ceaseless efforts made during last three years by all members of the expert group. The Central Board of Irrigation & Power wishes to acknowledge its • of this manual for their valuable contribution. I acknowledge grateful thanks to the authors with thanks the tremendous contribution made by late Shri A.K. Kapur, Retd. Executive Director (POWERGRID) beside the contribution by other members of the Expert group representing CEA, NHPC, A.P. TRANSCO., GEB, BBMB, RRVPNL, KPTCL, WBSEB, MSEB, PSEB, TNEB, BHEL, ALSTOM & KEC in finalizing the manual. Special thanks (vii)

arc due to Shri S.C. Misra, Chairman of the expert group for his tremendous input and directions given. I would like to add that but for the untiring efforts of Shri V.B. Prasad, Executive Director (Retd), NHPC, Shri R.S. Chadha, the then Director (IT) CBIP, Shri M.M. Goswami, POWERGRID, Sbri S.K. Mohapatra (CEA) and Sbri R.K. Gupta (POWERGRID) it would not have been possible to bring out this updated manual in this form. I hope that the publication will be Qf immense use and shall have excellent reference value to the practicing engineers and other professionals of power utilities, manufacturers, researchers, testing stations, faculty members and students of engineering Institutes in India and abroad.

G.N. Mathur Secretary Central 1.Joard of Irrigation & Power

New Delhi November 2006

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CONTENTS Preface

(v)

Foreword

(vii)

Chapter 1 Introduction

1

Chapter 2 Substation Equipment

7

Chapter 3 Substation Auxiliary Facilities

17

Chapter 4 Bus-Bar Schemes

37

Chapter 5 Safety Clearances

41

Chapter 6 Gas-Insulated Switchgear

47

Chapter 7 Physical Layout

51

•

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Chapter 1

INTRODUCTION Substations form an important element of transmission and distribution network of electric power system. Basically, these provide points for controlling the supply of power on different routes by means of various equipment such as transformers, compensating equipment, circuit breakers, isolators etc. The various circuits are joined together through these components to bus-bar systems at the substations. While the bus-bar systems have followed certain definite patterns, thus limiting scope for variation, there is practically no standardisation regarding the physical arrangement of the various components in the layout. For the same type of bus-bar system, different layouts have been used in different countries, and, in fact, in India there are variations in this regard among the various Power utilities and State Electricity Boards etc. Although standardisation to a great extent is feasible, some variations in layout are inevitable in view of varying climatic and other conditions in various parts of the country. This Manual gives the basic requirement, and, for the sake of illustration, contains typical layouts for various types of bus-bar systems up to 400 kV system voltage. One of the primary requirements of a good substation layout is that it should be as economical as possible, which is particularly important in view of the paucity of land and rising cost of land, material and labour. To meet the large programme for expansion of transmission and distribution facilities, the layout should ensure the desired degree of flexibility,- reliability, ease of operation and maintenance, and safety of the operation and maintenance personnel. Besides, the layout should not lead to breakdowns in power supply due to faults within the substation, as such faults are more severe than those occurring on the lines away from the substations. This Manual includes brief details about the various components of auxiliary facilities required in substation to the extent they relate to substation layout. It also covers minimum clearances and other related aspects. The Bureau of Indian Standards are periodically publishing Indian standards, Codes of Practice and Guides. It is essential that the equipment actually used and the practices followed conform to these standards. For the convenience of users, a list of the relevant latest Indian Standards, Codes, Guides etc. is enclosed as Appendix 1.1, and the list of relevant IEC Standard enclosed as Appendix 1.2 .

•

2 Appendix 1.1 List of Indian Standards, Guides, Codes etc. required for Reference

"'

IS:325

Three-phase induction motors

IS:398(Pt-1 )

Aluminium conductors for ovemead transmission purposes; Pt 1- Aluminium stranded conductors

IS: 398(Pt-2)

Aluminium conductors for overhead transmission purposes : Pt.2- Aluminium conductors, galvanized steel reinforced

IS: 398(Pt·5)

Aluminium conductors - galvanized steel reinforced for extra high voltage (400 kV and above)

IS: 692

Paper insulated lead .sheathed cables for rated voltage upto and including 33 kV - specification

IS: 694

PVC insulated cables for worl
IS: 731

Porcelain insulators for overhead power lines with a nominal voltage greater than 1ooo volts

IS: 802

Use of structural steel in overhead transmission line towers - Code of practices.

IS: 875 (Pt 1-5)

Code of practice for design loads (other than earthquake) for buildings and structures

IS:933

Portable chemical fire extinguisher, foam type

IS:934

Portable chemical lire extinguisher, soda acid type

IS: 1180

Three-phase distribulion lranslormers uplo and including 100 kVA, 11 kV, outdoor type

IS:1248

Direct acting indicating analogue electrical measuring instruments and their accessories

IS: 1255

Code of practice for installation and maintenance of paper insulated power cables (Upto and including 33 kV)

IS: 1554 (Pt-1 )

PVC insulated (heavy duty) electric cables Part-1 , for working voltages upto and including 1100 volts

IS: 1554 (Pt-2)

Specification for PVC insulated (heavy duty) electric cables Part-2, for working voltages from 3.3 kV upto and including 11 kV

IS: 1646

Code of practice for lire safety of buildings (General) electrical installation

IS: 1651

Stationary cells and batteries - Lead acid type (with tubular positive plates)

IS: 1652

Plante positive plate stationery cell lead acid batteries

IS: 1866

Code of practice for maintenance and supervision of mineral insulating oil in equipment

IS: 2026

Power transformer

IS: 2062

Steel for general structural purposes - Specification

IS: 2099

Bushings for alternating voltages above 1000 volts

3 IS: 2121

Conductors and earth wire accessories for overhead power lines

IS: 2165

Insulation coordination

IS: 2190

Code of practice for selection, Installation and maintenance of portable first· aid fire extinguishers

IS: 2309

Code of practice for protection of buildings and allied structure against lightning

IS: 2486

Insulator fittings for overhead power lines with nominal voltage greater than 1000

IS: 2544

Porcelain post insulators for systems with nominal voltages greater than 1000 volts

IS: 2629

Recommended practice for hot-dip galvanizing of iron and steel

IS: 2633

Methods for testing uniformity of coating of zinc coated articles

IS: 2705

Current transformers

IS: 3034

Code of practice for fire safety of industrial building , electrical generating and distributing stations

IS: 3043

Code of practice for earthing

IS: 3070 (Pt.1)

Lightning arresters for alternating current systems non-linear resistor type lightning arrester

IS: 3070 (Pt.2)

Metal oxide surge arresters without gaps for alternating current systems

IS:3151

Earthing transformers

IS: 3156

Voltage transformers

IS: 3646 (Pt.1,2)

Principles for good lighting and aspects of designs, code of practice

IS: 3646 (Pt.3)

Code of practice for interior illumination

IS: 3716

Application guide for insulation coordination

IS: 4004

Application guide for non-linear resister type surge arrestors without series gap for AC system

IS: 4146

AppliCation guide for voltage transformers

IS: 4201

Application guide for current transformers

IS: 4691

Degrees of protection provided by enclosure for rotating electrical machineiy

IS: 5082

Wrought aluminium and aluminium alloy bars, rods, tubes and sections for electrical purposes

IS: 5216 (Pt. 1&2)

Guide for safety procedures and practices in electrical work

IS: 5547

Application guide for capacitor voltage transformers

IS: 5553 (Pt.1 &2)

Shunt reactors

IS:5561

Specifications for electrical power connectors

IS: 5578

Guide for marking of insulated conductors

IS: 6005

Code of practice for phosphating of iron and steel

v

4

--

IS: 7098 (Pt-1)

Cross linked polyethylene insulated PVC sheathed cables: Part 1 For working voltage upto and including 1 100 V

IS: 7098 (Pt-2)

Cross linked polyethylene insulated PVC sheathed cables: Part 2 For working voltages from 3.3 kV upto and including 33 kV

IS: 7098 (Pt-3)

Cross-linked polyethylene Insulated thermoplastic sheathed cables: Part 3 for working voltages from 66 kV upto and including 220 kV

IS:e437(Pl.1&2)

Guide on effects of currents passing through human body

- IS

992 1

Alternating current disconnections (isolators) for voltages above 1000 volt

IS: 10028 (Pt· 1, Pt 2&3)

Code of practice for selection, installation and maintenance of transformers

IS: 10118

Code of practice for selection, installation and maintenance of switchgear and control gear

IS: 10136

Code of practice for selection of disc insulator fittings for highest system 1101tages of 72.5 kV and above

IS:10162

Spacers and spacer dampers for twin horizontal bundle conductors.

IS: 10561-IS: 12032 (Pt·2)

Application guide for power transformers

.

Graphical symbols used in electro-technology : conductors and connecting devices

•

IS: 12032 (Pt-4)

Graphical symbols used in electro-technology : Passive components

IS: 12032 (Pt-6)

Graphical symbols used in electro-technology : Production and Conversion of electrical energy

IS: 12032 (Pt·7)

Graphical symbols used in eleciro-technology : Sw~chgear, control gear and protective devices

1s· 12350

Voltage bands for eleclrical installations including preferred voltages and frequency

IS: 12063

Classification of degrees of protection provided by enclosures of elecirical equipment

IS: 13134

Guide for selection of Insulators In respect of pollution conditions.

IS: 13118

Specification for high voltage AC circuits breakers

'---

IS 13516

Methods of synthetic testing of high voltage AC circuit breakers

IS: 13947 (Pt.1 to 5)

LV switchgear and control gear

ANSl/IEEE:BO

IEEE guide for safety in AC substation grounding

5 Appendix 1.2 List of IEC Standards IEC-60034 (Pl to P19:)

Rotating electrical machines

IEC-60044-1

Current transformers.

IEC-60044-2

Voltage Transformers

IEC-60044-4

Instrument Transformers: Measurement of Partial Discharges

IEC-60051 : (Pl to P9)

Recommendations for Direct Acting indicating .analogue electrical measuring instruments and their accessories

IEC-60076 (Part 1 to Part 5)

Power Transformers

IEC-60076-10

Determination of Transformer and Reactor Sound Levels

IEC-61095

Electromechanical Contactors for household and similar purposes

IEC-60099·4 25

Metal oxide surge arrestors without gaps

IEC·60129

Alternating Current Disconnectors (Isolators) and Earthing switches

IEC-1129

Alternating Current Earthing Switches Induced Current switchi119

IEC-60137

Insulated bushings for alternating voltages above 1000 V.

IEC-60168

Tests on indoor and outdoor post insulators of ceramic material or glass for Systems with Nominal Voltages Greater than 1000 V

IEC-60183

Guide to the Selection of High Voltage Cables

IEC-601 89 (Pl to P7)

Low frequency .cables and wires with PVC il)sulation and PVC sheath

IEC-60214

On-Load Tap-Changers

IEC-60233

Tests on Hollow Insulators for use in electrical e(luipment.

IEC-60255 (Part 1 to part 23)

Electrical relays

IEC-60265 (Part 1 & Part 2)

High Voltage switches

IEC-60273

Characteristics of indoor and outdoor post insulators for systems with nominal voltages greater than 1OOOV

IEC-60289

Reactors

IEC IEC-60297 (Pl to P4)

Dimensions of mechanical structures of the 482.6mm (19 inches) series

IEC ·60376

Specification and Acceptance of New Sulphur Hexafloride

IEC-60437

Radio Interference Test on High Voltage Insulators

IEC-60507

Artificial Pollution Tests on High Voltage Insulators to be used on AC Systems

IEC -60694

Common Specification for High Voltage Switchgear & Control gear Standards

IEC -60815

Guide for the Selection of Insulators in respect of Polluted Conditions

IEC -60865 (Pl & P2)

Short Circuit Curren! • Calculation of effects

IEC ·60354

Loading Guide for Oil - Immersed power transformers

tEC-62271 -100

High Voltage Alternating Current Circuit Breakers

IEC -60427

Synthetic Testing of High Voltage alternating current circuit Breakers

'

.

6

....

IEC-61264

Pressurized Hollow Column Insulators

IEC-60358

Coupling capacitors and capacitor dividers

IEC-60481

Coupling Devices for power Line Carrier Systems

IEC-60529

Degree of Protection provided by enclosures

IEC-60947-4- 1

Low voltage switchgear and control gear

IEC-60439 (Pl & 2)

Low Voltage Switchgear and control gear assemblies

IEC-60353

Line traps for A.C. power systems

IEC-60481

Coupling Devices for power line carrier systems

IEC-60495

Single sideboard power line carrier terminals

IEC-60683

Planning of (single Side-Band) power line carrier systems

IEC-60359

Expression of the performance of electrical & electronic measuring equipment -·

IEC-60387

Symbols for Alternating-Current Electricity meters

IEC-60447

Man machine interface (MMI) -Actuating principles

IEC-60521

Class 0.5, 1 and 2 alternating current watt hour metres

IEC-60547

Modular plug-in Unit and standard 19-inch rack mounting unit based on NIM Standard (for electronic nuclear instruments)

IEC-60305

Insulators for overhead lines with nominal voltage above 1000 Vceramic or glass insulator units for a.c. systems Characteristics of String Insulator Units of the cap and pintype

IEC-60372 (1984)

Locking devices for ball and socket couplings of string insulator units: dimensions and tests.

IEC-60383 (Pl and P2)

Insulators for overhead lines with a nominal voltage above 1000 V .

IEC-60433

Characteristics of string insulator units of the long rod type

IEC-60471

Dimensions of Clevis and tongue couplings of string insulator units

IEC-60227 (Pl to P7)

Polyvinyl Chloride insulated cables o f rated voltages up to and including 450n5ov

IEC-60228

Conductors of insulated cables

IEC-60230

Impulse tests on cables and their accessories

IEC-60287 (Pl to P3)

Calculation of the continuous current rating of cables (100% load factor)

IEC-60304

Standard colours for insulation for low-frequency cables and wires

IEC-60331

Fire resisting characteristics of Electric cables

IEC-60332 (Pl to P3)

Tests on electric cables under fire conditions

IEC-60502

Extruded solid dielectric insulated power cables for rated voltages from 1 kV upto to 30 kV

IEC-754 (P 1 and P2l

Tests on oases evolved durina combustion of electric cables

Chapter 2

SUBSTATION EQUIPMENT 2.1 The substation layout is influenced to a great extent by the dimensions of the various equipment and their accessories within the substation. ·A detailed specification for various equipment is outside the scope of this Manual. However, in this chapter only the brief details of the various equipment to the extent they relate to the Substation layout, have been included. 2.2

BUS-BARS

Substations include bus-bars and are divided into bays. 2.2.1 Types of Bus-bars 2.2.1.1 The outdoor bus-bars are either of the rigid type or the strain I flexible type. 2.2.1.2 In the rigid type, pipes are used for bus-bars and also for making connections to the various equipment wherever required. The bus-bars and the connections are supported on pedestal mounted insulators. This leads to a low level type of switchyard, wherein equipment as well as the bus-bars are spread out. Since the bus-bars are rigid, the clearances remain constant. However as the bus-bars and connections are not very high from the ground, the maintenance is easy. Due to large diameter of the pipes, the corona loss is also substantially less. It is also claimed that this system is more reliable than the strain I flexible bus. In case of a rigid type bus, special care has to be taken in respect of aeolian vibration. 2.2.1.3 The the strain I flexible type of bus bars is on overhead system conductors strung between supporting structures and strain I tension type insulators. The stringing tension may be in the range of 500-900 kg per conductor I sub-conductor (of a bundle conductor) for installations upto 132 kV. For 220 kV and 400 kV installations, stringing tension may be in the range of 1000 - 2000 kg per conductor I sub-conductor (of a bundle conductor) depending upon span. The conductor tension, which strongly influences the design and weight of structure has to be specified carefully with reference to span, ambient temperature, wind velocity and relevant site conditions. 2.2.1 .4 The design of structures can be economised by suitably locating spacers in bundle conductor bus bars for 245 kV and higher voltage substations. 2.2.2 Bus-bar Material 2.2.2.1 For the rigid bus bar arrangement, aluminium pipes of Grade 63401 WP conforming to IS:.5082 are commonly used. The commonly used sizes of pipes are given in Table 2.1.

- .- -

... ... .... .. ..

... ······ ·- - ··· .. .

8 Table 2.1 : Commonly Used Size of Pipes Nominal diameter

System voltage (kV) 72.5 145

External (mm) 42 60 60 89 89 101.6 101.6 114.3 114.3 114.3 114.3 127 127

245

400

Internal (mm) 35 52 49.25 78 74 90.1 85.4 102.3 97.2 102.3 97.2 114.5 109

2.2.2.2 The material commonly used for bus-bars and connections of the strain I flexible type bus-bars are ACSRJAAC. The following sizes are commonly used either · as single conductors or as bundles (Table 2.2) : Table 2.2 : Commonly Used Size of Conductors System voltaQe (kV) 72.5 145 245

Type ACSA AAC ACSR AAC ACSR

AAC

. 400

ACSR

Stranding (Al I St.) I Dia (mm) 3017/2.79 19/./3.53 3017/3.00 19/./4.22 5417/3.18 3017/4.27 541713.35 19/·/5.36 37/-/5.23 5417/3.53

Diameter of complete conductor (mm) 19.53 17.65 21.00 21 .1 0 28.62 29.89 30.15 26.80 36.61 31.77

2.2.2.3 Since aluminium oxidises rapidly, great care is necessary in making connections. In case of long spans, expansion joints should be provided to avoid strain on the supporting insulators due to thermal expansion or contraction of pipes. 2.2.2.4 The bus-bar sizes should meet the electrical and mechanical requirements of the specific application for which these are chosen. 2.3

CIRCUIT BREAK ERS

2.3.1 Circuit breaker is a mechanical switching device capable of making, carrying and breaking currents under normal circuit conditions and also making, carrying for a specified time and breaking currents under specified abnormal circuit conditions. Circuit Breakers of the types indicated below have been used in India.

36 kV 72.5 kV

Minimum oil. Bulk oil, Vacuum, SF6 Minimum oil. Bulk oil, SF6

9 145 kV 245 kV 420kV

Minimum oil. Bulk oil, SF6 Minimum oil. Bulk oil, Air Blast, SF6 Minimum oil. Bulk oil, Air Blast, SF6

However, minimum oil, bulk oil and air blast circuit breakers are being phased out due to advancement in technology. SF6 circuit breakers are generally the pre"sent day choice at transmission voltages. The circuit breakers may be of live tank or dead tank design. The circuit breakers of the "live tank" type for outdoor substations have the interrupters housed in porcelain weather-shields on ~he top of an insulated support column. The circuit breakers of the "dead tank" type have interrupters housed in an earthed me.ta! container with their connections taken out through porcelain bushings and the bushings may be used to house the current transformers. 2.3.2 The circuit breakers are normally mounted on individual structures. 2.3.3 245 kV and higher voltage outdoor circuit breakers, generally necessitate the provision of approach roads for breaker maintenance. 2.3.4 . The commonly used operating mechanisms are pneumatic, spring, hydraulic or their combinations. 2.4

DISCONNECTORS AND EARTHING SWITCHES

2.4.1 A disconnector is a mechanical switching device, which provides in the open position, an isolating dista·nce meeting the specified req uirements. A disconnector can open and close a circuit when either a negligible current has to be broken or made or when no significant change in voltage across the terminals of each pole of the disconnector occurs. It can also carry current under normal circuit conditions and carry for a specified time the short circuit currents. Disconnectors are used for transfer of load from one bus to ~mother and also to isolate equipment for maintenance. Although a variety of disconnectors are available, the factor which has the maximum influence on the station layout is whether the disconnecter is of the vertical break type, pantograph or horizontal break type. Horizontal break type normally occupies more space than the vertical break type. Out of the horizontal centre break and horizontal double break type, the former requires a greater phase to phase clearance. 2.4.2 The location of disconnecting switches in substations affects not only the substation layouts but maintenance of the disconnectors contacts also. In some substations, the disconnects are mounted at higher positions either vertically or horizontally. Although such substations occupy smaller space, the maintenance of disconnecting switches in such substations is more difficult and time consuming.

IO 2.4.3 Earthing switch is a mechanical switching device for earthing parts of a circuit, capable of withstanding for a specified time short-circuit currents, but not requi red to carry normal rated currents of the circuit. 2.4.4 It is usual for disconnectors to be motorized. Earthing switches may be motorized or operated manually. 2.4.5 In case of double circuit lines the earthing switches shall be capable of switching inductive current (electromagnetically induced} and capacitive currents (electrostatically induced) as per the values specified in IEC 62271-102 when parallel circuit is energized. The disconnecter must also be capable of interrupting and making parallel circuits when transferring load between main and reserve bus bars according to IEC requirements 2.5

INSTRUMENT TRANSFORMERS

2.5.1 Instrument transformers are devices used to transform the values of current and voltage in the primary systef(l IO values suitable for the measuring instruments, meters, protective relays, etc. These also serve the purpose of isolating the primary system from the secondary system. 2.5.2 Current Transformers (CT) may be either of the bushing type or wound type. The bushing types are normally accommodated within the- transformer bushings and the wound types are invariably separately mounted. The location of the current transformer with respect to associated circuit breaker has an important bearing upon the protection scheme as well as layout of substation. So far, the wound type current transformers with dead tank construction have been used. However, current transformers with live-tank construction also are being used. 2.5.3 Voltage Transformer (VT) may•be .either of the electro-magnetic type or the capaciior type. The electro-magnetic type VTs are more costly than the capacitor type and are commonly used where higher accuracy is required as in the case of revenue metering. Capacitor type is preferred particularly at high voltages due to lower cost and it serves the purpose of a coupling capacitor also for the carrier equipment. For ground fault relaying, an additional core or a winding is requi red in the VTs which can be connected in open delta. The voltage transformers are connected on the feeder side of the circuit breaker. However, another set of voltage transformer is normally required on the bus-bars for synchronisation. 2.5.4 The tank of the instrument transformers may preferably be galvanized as this . would req uire least millntenance.

... - · · ·· · ·-·

·- ·--······ "'· ·- ·········· ··· . ................. . ....

. ... ..... ......

-····· ·

-

--

11

Compact Air-Insulated Substation (CAIS) I Intelligent Air-Insulated Substation (IAIS) 2.6.1 Compact Air-Insulated Substation (CAIS) I Intelligent Air-Insulated Substation (IAIS) based on modular concept has been developed by various manufacturers offering advantages in compactness, easy in installation, lower maintenance requirement etc. A single module can include breaker, disconnecter, DOIT (Digital Optical Instrument Transformer- current and voltage transformer, i.e., DOCT, DOVT) for metering and protection, surge arrester, and earthing switch. In some modules, with a trolley mounted Circuit Breaker (CB), i.e., drawout type, disconnecter function is achieved by the movement of the complete breaker unit. Composite modules are pre-manufactured, pre-tested and then integrated to replace the functions of number of conventional compommts. In a compact design, all primary and secondary functions required for a line or transformer bay in one pre-manufactured and pretested switching module (for all voltage levels) can be integrated. The concept also allows to build, upgrade or extend substation more efficiently. 2.6

2.6.2 Hybrid type switchgear could also be considered for reducing space and ·trom reliability consideration 2.7

TRANSFORMERS

2.7.1 Transformer is the largest piece of equipment in a substation and it is, therefore, important from the point of view of station layout. For instance, on account of large dimensions, it is generally not possible to accommodate two transformers in adjacent bays. One of the problems is the installation of radiators, which makes the width of the transformer much more than bay width. In order to reduce the risk of spread of fire, large transformers are provided with stone pebble filled soaking pits and oil collecting pit. In addition to above provision, separation walls are provided inbetween the transformers and also between the transformer and the control room building, if required road-cum-rail tracks is also provided for movement of transformer. Relevant, sections of CBIP Manual on Transformers may be referred to in this context. 2.7.2 One of the important factors governing the layout of the substation is whether the transformer is a three-phase unit or a bank of 3 single-phase transformers. The space requirements with single - phase banks are much larger than those with three-phase transformers. Besides, in the case of single-phase banks, it is usual to provide one spare single-phase transformer, and used in case of a fault or maintenance of one of the single phase units. The spare unit may be permanently installed in the switchyard ready to replace the unit, which is out of service. 2.8

REACTIVE COMPENSATION EQUIPMENT

2.8.1 -Reactive compensation may be of switched or non-switched type as indicated by system studies of the network in which the substations are located.

I

·· ········ ················- -- .. --···-· ·· - .

12 The non-switched type compensation usually comprises shunt reactors permanently connected to transmission line or to bus bars at the substations as per the requirements. Next to the transformer, shunt reactors constitute large pieces of equipment. These also can be in the form of single-phase units or three phase units. Often another reactor called neutral grounding reactor, which is connected between the neutral bushing of the line shunt reactor and earth, is provided to facilitate single pole auto-reclosing. However in case of bus reactor neutral is solidly grounded. Since these equipment also contain oil, the provisions valid for transformers apply to shunt reactors too. . The switched compensation can comprise switched reactors, switched capacitors or thyristor controlled reactors and thyristor switched capacitors known as Static Var Compensations (SVC). These are selected according to the system requirements and connected directly to their own discrete transformers. 2.8.2 Flexible AC Transmission Systems (FACTS) Flexible AC Transmission Systems (FACTS) technology is an evolving technology based solution for enhancing the power transmission capability of existing transmission system. FACTS is defined as "Alternating Current Transmission systems incorporating power electronics based and other static controllers to ~nhance controllability and increase power transfer capability." Thus, FACTS increases the flexibility of power systems, make them more controllable and allow . increased utilization of existing network closer to its thermal loading capacity without jeopardizing the stability. FACTS technology can boost power transfer capability in stability limited system by about 20 to 30%. By the process not only capacity is increased but also design and installation cost is saved. Several types of FACTS controller I devices e.g. Static VAR Compensator (SVC), Static Compensator (STATCOM), Thyristor Controlled Series Compensation (TCSC), Unified Power Flow Controller (UPFC), Inter-line Power Flow Controller (IPFC) etc. can be adopted to achieve the goal. 2.8.2.1 Static Var Systems The following are the basic types of reactive power control elements, which make up all or part of any Static VAR system : •

Saturated Reactor (SR)

•

Controlled Shunt Reactor (CSR)

•

Thyristor-switched Capacitor (TSC)

•

Thyristor-switched Reactor (TSR)

Static VAR Compensators (SVCs) are shunt connected static reactive power generators and/or absorbers whose output are varied so as to control specific parameters of the electric power systems.

13 2.8.3 Series Compensation Series capacitors are connected in series with the line conductors to compensate for the inductive reactance of the line. They reduce the transfer reactance between the buses of which the line is connected, increase maximum power that can be transmitted and reduce the effective reactive power losses. The series compensation can be variable type with control by Thyristor (also called as Thyristor Controlled Series Compensation - TCSC). Depending upon system requirement, a line can be compensated with fixed series compensation or fixed series compensation and TCSC. · 2.8.4 The substation lay out should be such as can accommodate the required compensation equipments. Many-a-time only some of these may be required in the initial stage and may undergo alteration as the system develops. Typical layout space requirement series compensation equipment is given in Chapter-7. 2.9

LIGHTNING PROTECTION

2.9.1 A substation has to be shielded against direct lightning strokes either by provision of overhead shield wire/earthwire or spikes (masts). The methodology followed for systems upto 145 kV is by suitable placement of earthwires/masts so as to provide coverage to the entire station equipment. Generally, an angle of shield of 60° for zones covered by two or more wires/masts and 45° for single wire/mast is considered adequate. For 245 kV installations and above, normally use of electromagnetic methods is resorted to. The most used method for determining shielded zones are the Mousa Method and Razevig Method. The detailed design of shielding system is outside the sc;;ope of this publication. 2.9.2 Besides direct strokes, the substation equipment has also to be protected against travelling waves due to lightning strokes on the lines entering the substation. The apparatus most commonly used for this purpose is the Surge arrester. Advances in material technology has resulted in the development of metal 9xide gapless type surge arrestors, which are being most widely used because of better protection level, higher energy handling I discharge capability and low power loss under normal operating conditions. The most important and costly equipment in a substation is the transformer and the normal practice is to install Surge arresters as near the transformer as far as possible. The fixing up of insulation level for various equipments within a substation requires a detailed study of insulation coordination with lightning arrester as the focal point for providing protection to the equipment from power frequency over-voltage exceeding the rating of the arrester. In the EHV range, there is also the problem of switching over-voltages and the life of the arrester may be considerably reduced due to frequent operations because of such overvoltages. Sometimes it is not possible to

. .... -..... ·-.

..... ....-

.. .

...

.. .. ... ... . .

.

"

. . .. . . ..

14 locate the lightning arrester very near the transformer. However, there is no problem so long as the transforme r is within the protective distance from the Surge arrester. Besides protecting the transformers, the lightning arresters also provide protection to the equipment on the bus side located within certain distance. In the case of very large substations where the Surge arrester for the transformer does not provide adequate protection to the other equipment, additional Surge arresters either on the bus or on various lines have to be provided. For determination of number of Surge arresters and their locations, each case has to be studied taking the size and importance of the substation, isoceraunic level, anticipated overvoltages etc. into consideration. 2.10 INSULATORS 2.10.1 Provision of adequate insulation in a substation is of primary importance from the point of view of reliability of supply and safety of personnel. However, the station design should be so evolved that the quantity of insulators required is minimum commensurate with the expected security of supply. An important consideration in determining the insulation in a substation, particularly if it is located near sea or a thermal power generating station or an industrial plant is the level of pollution. As a first step to combat this problem, special insulators with higher creepage distance should be used. In case this does not suffice, washing the insulators by using live line equipment has to be resorted to and this aspect has to be kept in mind while deciding the layout of the substation. Another method, which has proved to be successful in other countries, involves the application of suitable type of greases or Room Temperature Vulcanization (RTV) compounds on the · surface of the insulators. This, however, also requires cleaning of insulation, the frequency depending upon the degree and the type of pollution. 2.10.2 The creepage distances for the different pollution levels are provided according to Table 2.3. Table 2.3 : Creepage Distance for Different Pollution Levels Pollution level Lioht Medium Heaw Very heaw

Creepage distance (mm/kV of hiahest svstem voltaae) 16

20 25 31

For determining the creepage distance requirement, the highest line-to-line voltage of the system forms the basis. 2.10.3 The following types of insulators are normally used: (A)

Bus Support Insulators (i)

Cap and Pin type

15

(B)

(ii)

Solidcore type

(iii)

Polycone type

Strain Insulators (i)

Disc insulators

(ii)

Long rod porcelain insulators

(iii)

Polymer insulators

2.1 1 STRUCTURES 2.11.1 The cost of structures also is a major consideration while deciding the layout of a substation. For instance, in the case of the strain I flexible bus-bar arrangement, cost of structures is much higher than in the case of rigid bus type. Similarly the form of structures also plays an important part and the choice is usually between using a few heavy structures or a large number of smaller structures. While finalizing the design, size, and single line diagram of structures, safety clearance requirements should be ensured. 2.11.2 Steel is the most commonly used material in India for substation structures. Normally the steel structures are hot-dip galvanised so as to protect them against corrosion. However, galvanising sometimes has not proved effective, particularly in substations located in coastal or industrial areas and in such cases painting also becomes essential. In other countries special paints have been developed which are applied within the shop and these paints have proved quite effective. 2.12 POWER LINE CARRIER EQUIPMENT 2.12.1 The carrier equipment required for communication, relaying and telemetering is connected to line through high frequency cable, coupling capacitor and wave trap. The wave trap is installed at the line entrance. The coupling capacitors are installed on the line side of the wave trap and are normally base mounted. The wave traps for voltage levels upto 145 kV can be mounted on the gantry structure on which the line is terminated at the substation or mounted on top of the capacitor voltage transformer. However, the wave traps for voltage levels of 245 kV and above generally require separate supporting insulator stacks mounted on structures of appropriate heights.

I

Chapter 3

SUBSTATION AUXILIARY FACILITIES 3.1 Besides the main equipment discussed in Chapter 2 a number of auxiliary facilities such as earthing, cabling, oil handling system, illumination system, fire fighting, crane and other unloading facilities, oil filtration, AC/ DC auxiliary system etc., have to be provided within a substation. These requirements have been briefly discussed in this chapter to the extent these relate to the substation layout. 3.2

EARTHING

·3.2.1 Provision of adequate earthing system in a substation is extremely important for safety of the operating personnel as well as for proper system operation and performance of the protection devices. The primary requirement of a good earthing system in a substation are: (a)

The impedance to ground should be as low as possible. In general it should not exceed 1 ohm for substations with high fault levels (EHV substation) and 5 ohms for substations with low fault levels (Distribution substation).

(b)

The step and touch potentials should be within safe limits.

3.2.2 To meet these requirements, an earthing system comprising an earthing mat buried at a suitable depth below ground, supplemented with ground rods at suitable points is provided in the substations. All the non-current carrying metal parts of the equipment in the substation are connected to the earthing mat so as to ensure that under fault conditions, none of these parts is at a potential higher than that of the earthing mat. Under normal condition, the ground rods make little contribution in lowering the earth resistance. These are, however, helpful in maintaining low value of resistance under all weather conditions which is particularly important for installations with high system earth fault currents. 3.2.3 All substations should have provision for earthing the following:

I

(a)

The neutral points of equipment in each separate system. There should be independent earth for the different systems. Each of these earthed points should be intercon nected with the station earthing mat by two different diagonally opposite connectors to avoid common mode failure.

(b)

Equipment framework and other non-current carrying metal parts.

(c)

All extraneous metal frameworks not associated with equipment.

(d}

Lightning arresters: These should h'!ve independent earthing which should in turn be connected to the station grounding grid or earthmat.

'•

.. ... " ··-· .. .. -·· . ·- .. -·· .. - - .. .. .. .. ... .. .

18 3.2.4 The earthing of substation fence has to be considered from the viewpoint of touch and step potentials in the peripheral area outside the fence. Normally the earth mat has to be extended by 1m to 1.5m beyond the fence so as to ensure that the area in the vicinity of the substation fe nce is safe. Where the fenced area is large and mat area is small, in that case fence earthing should be isolated from the main earth mat so that person touching the fence is protected from danger due to transfer voltage. 3.2.5 Earthing in a substation must conform to the req uirements of the Indian Electricity Rules and the provisions of the relevant sections of latest IS: 3043 and IEEE Std - 80. The earthing system should be designed to have low overall impedance, and a current carrying capacity consistent with the fau lt current magnitude. The major parameters which influence design of earth mat are: (a)

Magnitude of fault current:

(b)

Duration of fau lt:

(c)

Soil resistivity:

(d)

Resistivity of surface material:

(e)

Shock duration:

{f)

Material of earth conductor, and

(g)

Earth mat grid geometry

3.2.6 Bare stranded copper conductor or copper strip used to find extensive application in the construction of earth mat in the past. However, on account of high cost of copper and the need to economise in the use of copper, current practice in the country is based on the use of steel conductor for earth mat. In view of fast deterioration of GI pipe electrode, cast iron pipe electrode is preferred for earthing. The minimum distance between the electrodes shall be twice the length of electrode. 3.2.7 Design Procedure For detailed design of earth mat reference may be made to the latest edition of IEEE-80, CBIP Technical Report No. 5 on 'Steel Grounding Systems where Grounding Mat is not needed' and CBIP Publication No. 223. 3.3

CABLING

3.3.1 Trenches and cable ducts are normally laid for cable runs. In very large substations, particularly those associated with power plants, tunnels have also been

19 used. Except where cables enter and take off from trench, directly buried cables are generally avoided to facilitate locating faults and rapidly restoring the supply. 3.3.2 The substation area should be properly graded so that the rainwater is drained away form the cables trenches. For draining off any water that may enter the trenches, these should be sloped in their run to drain freely and necessary arrangements made to remove the accumulated water as and when required. Cable trenches should be provided with strong and effective covers. Cables should not be laid directly in the trench floor. A typical cable trench is shown in Fig. 1. At points of entry into indoor areas, termination chambers etc., waterproof and fireproof sealing arrangements should be made. Cable trenches should not run through oil rooms. 3.3.3 Conduits should have the minimum number of bends in their run. Pull boxes to facilitate cable pulling should be provided at suitable locations. Conduits should be sloped and drained at low points. Care must be exercised to se·e that water does not accumulate within the conduits or drain into the equipment at the end. 3.3.4 In indoor areas, cable may be laid in racks supported on walls, ceiling or floor, floor trenches or clamped to walls or ceiling. Wherever a large number of cables are involved and conditions so permit, a system of racks is preferable as it gives quick access. Particular care should be taken in substation design to permit easy entry of cable in to switchgear with convenience of handling even afterwards. 3.3.5 Cable laying should be done in accordance with systematically prepared cable schedules. In major substation thousands of separate cables will be involved and quick tracing of defects will depend very much on the orderliness exercised while laying. All cable ends should be suitably labeled to facilitate easy identification. 3.3.6 Power cables and control cables should be segregated by running in separate trenches or on separate racks so that in the event of a fire, the control cables are not affected. Segregation of AC and DC control cables to the extent possible is also useful. Separate cables should be used for each CT and PT. In the case of 400 kV substations and substations having numerical/digital relays, shielded cables should be used for CT and PT circuits and armoured cables for other circuits. These should not be included in the cores of other multicore control cables. While arranging cable runs it should be kept in mind that the arrangement should be such that a fire at any point will not lead to complete shutdown of the whole substation for a long time. Flexible conduits should be used at terminal connections to motors, pumps, etc. The main trenches should be formed such that heavy current carrying conductors do not run parallel to the control cables. The cable ducts should be laid away from lightning arresters to minimize the effect of high discharge current flow.

I

- .... -·· .... .. ..... .. ..

.. ..

- .. .... ...... .

20 In main trenches a heavy current carrying conductor should not be run parallel to control cables. This conductor should be clamped at suitable intervals to the support angles earthed to rod electrodes at every 20/25-meter intervals. This shield conductor drain all induced current and minimizes induction of high voltage in the control cables. Power cables are placed in the top rack. Lower racks contain con trol cables. If unarmoured cables are used these should find place in the bottom most rack. 3.3.7 XLPE/PVC insulated cables conforming to the Indian Standards listed in Appendix 1.1 in Chapter 1 should be used up to 11 kV. 3.3.8 Multicore control cables should also be PVC I XLPE insulated and colour coded. Adequate number of spare cores should be included in all control cables. Wherever fiber optic cable are used they should be armoured type. 3.3.9 Wherever insulated cables are used reference should be made to latest IS: 1554 and IS: 694. Earthing of cables sheaths, provision of earth continuity conductors etc., should be as per latest IS: 1255. "Code of Practice for Installation and Maintenance.of Paper Insulated Cables" (upto and including 33 kV) and latest IS: 3043 Code of Practice on Earthing. 3.3.10 Wherever·application demands, FRLS cables and fittings should be used. For mechanical protection, armoured cables are used in case these are laid on ladder type trays. For 400 kV switchyards, irrespective of the type of cable trays, armoured cable should be used. Armoured cables can be buried directly. However the unarmoured cables can be laid in conduits. 3.4

OIL HANDLING SYSTEM

3.4.1 The oil handling system is required for treatment of insulating oil in transformers, reactors etc. Details regarding handling and treatment of oil are given in latest IS: 1866 - "Code of Practice for Maintenance and Supervision of Insulating Oils in service.

3.4.2 Oil may be stored in clean drums. The drums should be stored horizontally with caps below oil level. It should be tested periodically for dielectric strength and kept in good condition. 3.4.3 Portable oil filtration set of adequate capacity mounted on trucks may be provided to cater to the requirements of group of substations. A typical layout of oil handling system for a centrally located or a large substation is shown in Fig. 2 .

....

21 3.5

ILLUMINATION SYSTEM

3.5.1 Good· Gghting in a substation is necessary to facilitate normal operation and maintenance· activities and at the same time to ensure safety of the working personnel. As per latest IS: 3646 (Pt. II) "Schedule for values of illumination and Glare Index" recommends values of intensity of illumination. Table 3.1 contains the recomme nded values for different parts of substations. Table 3.1 : Recommended llluminator Values SI. No. 1.

2. 3. 4. 5. 6. 7.

8. 9. 10 11 12 13 14 15 16 17

Particulars Control rooms: Vertical control panels Rear of conlrol panels Control desks Switch houses Batterv room Carrier room Offices and receotion Cloak rooms Workshon!Reoair bav Test room Outdoor switchvard Stairs Corridors Annroach roads Pathways Car oarks Conference room Store room Cable aallerv/floor AC plant/DG set room

Average illumination level 'Lux' 200 to 300 150 300 150 100 300 300 100 300 450 20 100 70 20 20 20 300 100 70 150

Limiting Glare Index 19 19 19 25

. .

19

25 19

. -

16

-

19

-

-

-

Out door switchyard average illumination level shall be 50 tux on main equipment and 20 tux on balance area of switchyard. In the out door switchyard, the area covered by transformer/reactor should have 50 lux. 3.5.2 The lighting system of a particular area whether outdoor or indoor should be designed in such a way that uniform illumination is achieved. As far as possible any dark spots should be avoided. This requires careful placing of the luminaries, selection of proper mounting heights and provision of sockets in the marshalling kiosks and mechanism boxes of circuit breakers/disconnect switches for providing supplementary lighting wherever required. In outdoor switchyards, only the equipment/bus bar areas are illuminated. In outdoor area, luminaries should be directed as far as possible towards transformers, circuit breakers/disconnect switches, their mechanism boxes etc., where some operations may be necessary during emergency at night

I

.,

22 3.5.3 There are several classifications of the types of lighting such as direct, indirect, semi-indirect, diffusion, etc., The types of lighting or the combinations should be so chosen as would provide adequate level of glare-free illumination without creating undesirable shadows. 3.5.4 Direct lighting system is the most commonly used and it employs open dispersive reflectors, silver glass reflectors and angle reflectors. The simplest form of general diffusion fitting is the plain sphere of opal glass. The spherical form may be modified and any form, which the designer can think of may be used. The efficiency of the general diffusion fitting depends partly on shape but much more on the properties of the diffusing material used. 3.5.5 The typical indirect fitting is and opaque bowl with lamp suspended in it at such a depth that all the direct light from the lamp as well as form the bowl is emitted in the upper hemisphere. The semi direct fittings lie in between the indirect and the general diffusion fittings. 3.5.6 Flood light fittings are in essence, projectors with parabolic reflectors. There are two types of floodlights: the wide beam type and the narrow beam type. Wide beam type is suitable where accurate control is not necessary and the light is projected only over a short distance. The narrow beam type is used where light is required to be projected over longer distances. 3.5.7 The choice of lamps, i.e., incandescent, fluorescent, mercury vapour, sodium vapour halogen etc., depends mainly on the nature of work, the number of hour of utilization annually, the cost of energy and the power available for illumination. Table 3.2 gives different types of lamps and fitti ngs that may be used in different area of a substation. 3.5.8 The foremost criterion in the design of illumination system of indoor area such as control room, workshop, repair bay, offices, etc., is that illumination at the working height throughout the area should be as uniform as possible so as to avoid eye fatigue. In practice, complete uniformity of illumination is difficult to achieve and a ratio of the minimum intensity to the maximum equal to about 70 percent is usually considered acceptable. · 3.5.9 Energy conservation requirement has to be kept in view while selecting type of lamp and type of fitting. While designing the lux level requirement Utilization coefficient factor. may be considered to take care effect of dust, pollution etc. on reflectors used in the lighting fixtures. The night time lighting of exterior areas is necessitated by operational requirement, security or decorative purposes or a combination of these. It is used for illuminating outdoor switchyards transformer yards, approach roads to substations, etc., Use of flood lights has been in practice for illumination of switchyards. However, floor lights generally cause glare, if not properly positioned and mounted at proper heights. As the lumen output of mercury/sodium vapour lamps is quite appreciable as compared

23 to incandescent lamps, flood light units having mercury/sodium vapour lamps with medium and wide angle coverage, mounted at suitable heights are preferred. If the floor light is mounted at a height of 6 to 1Om it would be away from the normal vision angle (8°) of a man approaching it and therefore, there would be no problem of glare. If the design of the flood lighting is followed in an orderly fashion, it is easy to obtain uniform illumination in the outdoor switchyard. The spillover light from flood lights provided in the switchyard is generally sufficient for fence lighting. Separate fence lighting is provided only in exceptional cases. Light fittings in the switchyards are mounted on substation structure/lighting masts. Typical lamps and fittings generally provided in some identified areas are given in Table 3.2 Table 3.2 : Typical Lamps & Fittings in Some Identified Areas

6.

Particulars of area Unloadino-cum-reoair bav Store rooms, workshoos Control room, offices carrier room Batterv room Comoressor room etc., External lighting on building

7.

Outdoor switchyard

SI. No.

1.

2. 3. 4. 5.

Tvne of lamas Mercurv vanour sodium Fluorescent Fluorescent

Tvoe of fittinas Hiah bav Industrial Decorative

Fluorescent Fluorescent Mercury vapour vaoour Mercury vapour

sodium

Acid oroof, Industrial Industrial Water tight flood light

sodium

Water tight flood light

vapour

sodium

vapour

sodium

Po st type water tight, flood linht Post type water tight street liaht fittinas

v~nou r

8.

Fence lighting

9.

Roads

Mercury vanour Mercury vaoour

3.5.10 The purpose of street lighting in substations is to promote safety and convenience on the approach roads, service roads and side walls inside switchyard, etc., The aim should be to provide conditions of visibility adequate for accurate, · certain and comfortable seeing. 3.5.11 Emergency lighting is called for in case of AC supply failure in substations. In indoor installations such as a control room, switchgear rooms, etc., DC lamps connected to the DC supply system should be provided at suitable locations. These are brought into service in case of AC supply failure. These are normally wired through automatic changeover contactor at the DC distribution board. In workshops/ repair shops and machine hall, where mercury/sodium vapour lamps are employed, provision should be made for one incandescent lamp fitting of suitable power for a group of 4 to 6 mercury/sodium vapour lamps. This would avoid an extended total blackout in the event of a voltage dip or momentary interruption of AC supply, as the discharge lamps take a few minutes to give full light output again. 3.6

COMPRESSED AIR SYSTEM

3.6.1 Compressed aif system in substation may be required for the operation of air blast circuit breaker and pneumatically operated circuit breakers and disconnect

I

.

- - ·-· ..... . ... , .

-·· .. ... . ,.... . . ... .. ---

.

J 24 switches. A reliable source of supply of compressed air is very essential for successful operation of the equipment. 3.6.2 Compressed air requirement of a substation can be met by either a central compressor system or a unit compressor receiver system. 3.6.2.1 Central Compressor System 3.6.2.1.1 This arrangement is generally provided in substation, where the number of circuit breakers to be served is large. The central compressor normally works at a high pressure and through reducing valves, the pressure is reduced at local receiver of each circuit breaker to a working level. The values of high or low pressure vary from manufacturer to manufacturer. However, generally the rated pressure of the central air receiver is kept about twice the rated pressure for breaker operation. The advantages of choosing higher pressure for the central receiver are: (i)

Ensured availability of working pressure in the circuit breaker received immediately after one specified duty operation.

(ii)

Elimination of moisture in the compressed air, as expansion takes place from high pressure in the central receiver to working pressure in the circuit breaker receiver.

(iii)

Reduction in storage volume.

3.6.2.1.2 The central compressor system should comprise at least two compressors, each capable of charging the central air receiver to its rated pressure within prescribed time. The capacity of the local receiver should be adequate for the breaker to perform one standard duty cycle. The capacity of the air receiver should be adequate for the total number of breakers likely to perform one standard duty cycle simultaneously. The capacity of the air compressor should be adequate so that the time required for the first charging or charging under normal running conditions or charging after one standard duty cycle whichever is more critical, does not exceed the specified limits. 3.6.2.2 Unit Compressor Receiver System 3.6.2.2.1 This system may be provided in the substations, where the number of circuit breakers to be served is small. In this arrangement, each circuit breaker shall have its own compressor and receiver. A single compressor is used but a connector is provided to allow a portable compressor to be coupled for maintenance purposes or in emergency. In such an arrangement, the storage capacity of the local receiver should be sufficient for two or three operations without recharging. The usual

25 practice is that the time to restore 95 percent pressure following a break operation is 3-5 minutes or even less. 3.6.3 Compressed air always contains moisture to some extent which must be eliminated so as to ensure the safety of operation. 3.6.4 The pipe from the air supply system to the circuit breaker should be normally of ring main or double bus type to ensure continuity of supply. Formerly, solid drawn copper piping was used for compressed air but, in view of the acute shortage of copper, it is not economical to use copper piping. Instead black steel or galvanized iron piping may be used. Screwed malleable iron fittings should be used for low pressure (7atm. and lower). Where high pressures are encountered, flanged forged black steel fittings may be used. 3.6.5 A typical central compre~sor arrangement for a substation using air blast circuit breakers is shown in Fig. 3. 3.7

CRANE FACILITIES

3.7.1 Large substation sometimes has the facilities of repair bay along with a crane of adequate capacity for handling the heaviest equipment which is usually the transformer. In view of heavy cost and infrequent use, however, this facility is not provided in all substations. In the case of substations near the generating stations, the service bay and crane facilities normally available at the generating station are utilized. In the case of substations, which are not near a generating stations, crane and service bay facilities may be provided at one centrally located substation to serve a group of nearby substations connected by road or rail. 3.7.2 Provision of a rail track should be made for movement of transformer from switchyard to the repair bay. Point for jacking pad should be provided at the transformer foundation, to facilitate 90° turn on the rail track for changing the direction of wheels. 3.8

FIRE PROTECTION FACILITIES

3.8.1 In view of a large number of oil-filled equipments in a substation, it is very important that proper attention is given to isolation, limitation and extinguishing of fire so as to avoid damage to costly equipment, reduce chances of serious dislocation of power supply and ensure safety of personnel. The first step in this direction is inherent in the design and layout of the substation itself, which should be such that if fire occurs in any equipment it should be limited and isolated so. that it does not spread to other equipments. For this purpose the following are the general guidelines:

I

········ ·· .. ..... ··· ·-· ..

26 (i)

The spacing of the equipment should be considered. Extra space is not usually provided for fire isolation, but the space available is taken into account in deciding other isolation measures.

(ii)

Fire isolation walls should · be provided between large oil-filled equipments such as two or more transformers placed adjacent to each other. These should be of adequate strength and of such size that the adjacent equipment is reasonably safe from fire risk due to burning oil flying from the equipment on fire.

(iii)

In indoor areas automatic fireproof doors should be provided for rooms which house major oil-filled equipment. The rooms should also be constructed with a view to isolating the fire.

(iv)

Soak pits or drain pits should be provided below large oil-filled equipment to drain off the burning oil falling below the equipment.

(v)

Minor items of oil-filled equipment should be placed in beds of gravel or pebbles which wfll quench and prevent the spread of burning oil.

(vi)

Care should be exercised that any prospective fire can be easily approached for quenching. In closed spaces and buildings attention should also be given to evacuation of personnel (Refer IS: 1646).

(vii)

All oil pipes and cable trenches should be sectionalised by means of cross walls. ·

3.8.2 A well coordfnated system of fire protection should be provided to cover all areas of the substation and all types of likely fires. The details of fire protection have to be worked out on the basis of size, type and location of the substation, accessibility and degree of attendance. Care should be taken that any fire can be fought from more than one source and dependence is not placed on single equipment for this purpose: 3.8.3 The subject of fire safety involving electrical equipment is exhaustively covered in latest IS: 1646, IS: 3034 and CBIP Manual on Transformer. 3.8.4 Fire Fighting System 3.8.4.1 All substations should be equipped with fire fighting systems conforming to the requirements given in latest IS:1646 and Fire Protection Manual Part-I issued by Tariff Advisory Committee of Insurance Companies. 3.8.4.2 Trailer pumps where provided should draw their water supply from ground tanks of suitable sizes, the location and distribution of which shall be such that no item to be protected is more than about 90m away from any ground tank.

....

27 3.8.4.3 The more valuable equipment or areas forming concentrated fire risk should be covered by special fire protective systems. In this class are: (a)

Transformers, both indoor and outdoor:

(b)

Oil-filled reactors:

(c)

Oil-filled switchgear:

(d)

Oil tanks and oil pumps:

(e)

Oil, grease and paint stores: and

(f)

Synchronous condensers.

3.8.4.4 Although the substitution of bulk-oil and minimum oil circuit breakers by SF6 gas circuit breakers has reduced the risk of fires in electrical installations, considerable risk still exists on account of transformers, reactors, cables etc., ·which contain combustible insulating materials. Fires in live electrical equipment, motors, machinery etc. ·fall in class C according to the Tariff Advisory Committee Classification of Fires. It is necessary to provide efficient Fire Protection Systems in the Electrical li;istallations. Fire Protection System consists of the following: (i)

Fire Prevention

(ii)

Fire Detection and annunciation

(iii)

Fire Extinguishing.

3.8.5 Fire Prevention 3.8.5.1 Fire prevention is of utmost importance and should be given its due if risk of occurrence of fires has to be eliminated/minimized. The safety and preventive measures applicable for substations as recommended by the relevant authorities must be strictly followed while planning the substations. 3.8.5.2 All fire fighting equipment and systems should be properly maintained. Regular mock drills should be conducted and substation staff made aware of importance of fire prevention and imparted training in proper use of the fire fighting equipment provided in various parts of the substation, control room building etc. 3.8.6 Fire Detection and Annunciation

l.II

3.8.6.1 Fire detection if carried out at the incipient stage can help in timely containment and extinguishing of fire speedily. Detection can either be done visually by the personnel present in vicinity of the site of occurrence or automatically with the use of detectors operating on the principles of fixed temperature, resistance variation, differential thermal expansion, rate of rise of temperature, presence of smoke, gas, flame etc. Fire detectors of the following types are usually used:

28 (i)

Ionisation type

(ii)

Smoke type

(iii)

Photoelectric type

(iv)

Bimetal type

(v)

Linear heat detection type

3.8.6.2 Ionisation ·type detectors are used more commonly. However in areas like cable vaults, Ionisation smoke and linear heat detection type detectors are used. Smoke type detector is effective for invisible smoke, and photoelectric type for visible smoke. Smoke type detectors incorporate LEDs, which start glowing in the event of fire. 3.8.6.3 Detectors are located at strategic positions and arranged in zones to facilitate proper indication of fire location, transmission of Audio-visual signals to Fire control panels and actuation of the appropriate Fire Fighting Systems. In the rooms with false ceilings, these are provided above the ceiling as well as below it. For the detectors located above the false ceilings, remote response indicators should also be provided. 3.8.6.4 Detectors are provided at the rate Qf one for a maximum area of 80 m2 in the zones to be covered by the Fire Protection System 3.8.7 Fire Extinguishing 3.8.7.1 The Fire Extinguishing Systems used for fire protection of the various equipments/building in substations are the following: (i)

Hydrant system.

(ii)

High velocity water spray system.

(iii)

Portable fire extinguishers.

(iv)

Nitrogen injection fire prevention method for transformer only

These are described below briefly. 3.8.8 Hydrant System 3.8.8.1 Hydrant System is installed for the protection of the following areas from fire: (i)

Control room building

(ii)

LT. transformer area

(iii)

Diesel generator set building

... ·- --·····

.... - ···••"" ·---

-

29 (iv)

Fire water pump house

(v)

Suitable location in the switchyard.

3.8.8.2 Hydrants are the backbone of Fire Fighting System as these can help fighting fires of all intensities in all classes of fires and continue to be in service even if the affected buildings/structures have collapsed. These keep the adjoining properties/buildings cool and thereby save them from the serious effects of fire and minimize the risk of explosions. 3.8.8.3 The Hydrant System is supplied water from Fire Water Pump House. Fire Water Pump House is located by the side of Fire Water Storage Tanks constructed within the substation boundary limits. These tanks are made of RCC above ground such that these are easily accessible. Water from these tanks is pumped into the Fire Hydrant System with horizontal centrifugal pumps. 3.8.8.4 The Hydrant System essentially consists of a network of pipes, laid both above ground and underground, which feed water under pressure to a number of hydrant valves located at strategic locations throughout the substation. Pressure in the piping is maintained with the help of hydro-pneumatic tanks and jockey pumps. Jockey pumps compensate for minor leakages also. The hydro-pneumatic tanks are pressurized with compressed air supplied by two air-compressors of which one is working at a time and other acts as standby. Adjacent to the Hydrants, hosepipes, branch pipes and nozzles are kept in Hose Boxes. In case of fire, the hoses with nozzles are coupled to the respective hydrants and water jet is directed towards the seat of fire. 3.8.8.5 On drop of pressure in the piping network below a preset value, the Hydrant Pump starts automatically and continues to run till it is stopped manually after fire has been extinguished. 3.8.8.6 The quantity of water to be available for fire protection and the number of fire water pumps depend on the total number of hydrants which are provided as per guidelines of Tariff Advisory Committee Manual, according to which substations fall in "Light Fire Hazard" category. The parameters of Fire Water Pumps as per TAC guidelines are given below. 3

(a)

For the total number of hydrants upto twenty, one no pump of 96 m /hr capacity with a pressure of 5.6 kg/cm 2 (gauge)

(b)

For the total number of hydrants exceeding twenty u~to fifty five, one no. pump of 137 m3/hr capacity with a pressure of 7.0 kg/cm (gauge) .

(c)

For the total number of hydrants exceeding fi~ five, upto hundred, one no. pump of 171 m3/hr with a pressure of 7.0 kg/cm (gauge)

.....

. ...

. .. ······ .. .

••

30 3.8.8.7 As per TAC guidelines, the jockey pump should have a capacity of 10.8 m3/hr. and the hydro-pneumatic tank should have a capacity of 18 m3 . The effective capacity of the Fire Water Tank should be not less than one hour of aggregate pumping capacity, with a minimum of 135 m3 . 3.8.8.8 All components of the Hydrant System such as piping, valves, fittings, hoses, branch pipes, nozzles etc. should be of approved make acceptable to TAC. 3.8.9 High Velocity Water (HVW) Spray System 3.8.9.1 This type of Fire Protection System is provided for the following types of equipment: (i)

Power Transformer, both auto and multi-winding

(ii)

Shunt Reactors

This system is designed on the assumption that one reactor/transformer is on fire at a time. For this assumption, the largest piece of equipment forms the basis. 3.8.9.2 High Velocity Water Spray System consists of a network of projectors arranged around the equipment to be protected. Water under pressure is directed into the projector network through a deluge valve from a piping network exclusively laid for the Spray System. Water leaves the projectors in the form of conical spray of water droplets travelling at high velocity. 3.8.9.3 The high velocity droplets bombard the surface of oil and form an emulsion of oil and water which does not support combustion. This emulsion converts a flammable liquid into a non-inflammable one. However, this emulsion is not of a stable character and therefore shortly after the water is shut off, oil starts to separate out from water which can be drained away, leaving the oil behind unimpaired. 3.8.9.4 The rate of burning of a flammable liquid depends upon the rate at which it vaporizes and the supply of oxygen to support combustion. It is the maximum when the rate of burning of the flammable liquid is the maximum and the surface of the liquid is near boiling point. The .Qigh velocity water spray system while forming an emulsion, intersperses cold water.with the liquid, cools it and Jowers down the rate of vapourisation which prevents further escape of flammable vapours. During passage of water droplets through flames, some,._ of the water gets converted into steam, which dilutes oxygen in the air supporting the fire and creates a smoothering effect, which aids in extinguishing the fire. 3.8.9.5 An automatic deluge valve triggered by a separate system of quartzoid bulb detector heads mounted on a pipe work array charged with water, at HVW spray mains pressure, initiates the HVW Spray System operation. When a fire causes one or more of the quartzoid bulbs to operate, pressure in the detector pipe work falls

31 and this allows the deluge valve to open thereby permitting water to flow to all the projectors in the open pipe array covering the risk.

3.8.9.6 Water Supply to HVW Spray System (a)

Two pumps are provided for HVW Spray System. Of these, one is electric motor driven and the other diesel engine driven. The capacity and head of the pumps is selected to protect the biggest risk. It has been experienced that each pump having a capacity of 410 m3/hr is usually adequate for the biggest risk in substations.

(b}

These pumps are located in Fire Water Pump House. Suitable connection with the Hydrant System is provided so as to allow flow of water from Hydrant System to HVW Spray System but not in the reverse direction.

(c)

Standby diesel engine driven pump is a common standby facility for HVW spray as well as Hydrant System.

(d)

Th ese pumps are automatically started through pressure switches located sequentially in headers. However, stopping of the pumps is done manually after the fire gets extinguished.

(e)

The values of pressure of running water and discharge density given below are recommended for HVW Spray System : (i)

Minimum pressure of running at any projector at any instance.

=

3.5 Bar

(ii)

Maximum pressure of running water at any projector at any instance

=

5.0 Bar

(iii)

Discharge density on gro~nd surface

=

6.1 lpm/m2

(iv)

Discharge density on other surface

=

Not less than 10.2 1pm/rn2

3.8.10 Water Supplies 3.8.10.1 Water for fire fighting purposes should be supplied from the water storage tanks meant exclusively for the purpose. The aggregate storage capacity of these tan.ks should be equal to the sum of the following:

I

3

(i)

One-hour pumping capacity of Hydrant System or 135 m which over is more.

(ii)

Half-an-hour water requirement for single largest risk covered by HVW Spray System.

. . .... - ··· ······ .. .. . .. .. ..

..

. .. .. .. .. .

32 The water storage tank made of RCC construction over ground should be in two parts. 3.8.10.2 Fire Water pumps located in the Fire Water Pump House should have pumping head suitable to cover the facilities for future stages also. The piping system should be designed to permit extensions without disruption in the existing system. The material of piping is mild steel as per IS: 1239/IS: 3589 medium grade. The piping laid underground is coated and wrapped against corrosion as per IS: 10221 and the piping laid over ground consists of galvanised mild steel. 3.8.10.3 All equipment and accessories, constituting the HVW Spray System, such as flow control valve, heat detectors, projector nozzles, piping, valves, fittings, instrumentation etc., should be of approved makes acceptable to TAC. 3.8.11 Portable and Mobile Fire Extinguishers 3.8.11.1 Portable and Mobile Fire Extinguishers are provided at suitable locations for indoor/outdoor applications. These extinguishers are used during early stages of localised fires to prevent them from spreading. Following types of these extinguishers are usually provided. (i)

Pressurised Water Type

in 9.01 kg size

(ii)

Carbon Dioxide Type

in 4.5 kg size

(iii)

Dry Chemical Type

in 5.0 kg size

(iv)

Halon type

in 5.0 kg size

(v)

Mechanical foam Type

in 501trs, 901trs.

For the quantities of these types and their applications, the norms given in TAC manual should be followed. •

The make of these extinguishers should also be acceptable to TAC.

•

Halon type fire extinguishers are now getting phased out on account of their negative effect on the atmosphere.

•

The transformers shall be protected by automatic high velocity water spray system or by carbon dioxide or BCF (Bromochloro-difluromethane) or BTM (Bromotrifluromethane) fixed installation system or Nitrogen injection and drain method.

•

Nitrogen injection fire prevention method is being used by a few utilities at present.

. -

..

- . . .... - - ··· ... ..... .... .. .. .... ........ .

I

33 3.8.12 Instrumentation and Control 3.8.12.1 Fire Protection System should include suitable instrumentation and necessary controls to render the system efficient and reliable. There should be local control panels for each of the pumps individually as also for the operation of deluge valve of the HVW Spray System. There should be a common control panel for the Jockey Pump and Air Compressors. Main annunciation panel should be provided in the control room for the facilities provided in the control room and for repeating some annunciation from pump house. 3.8.12.2 The following Annunciation is usually provided in the Fire Water Pump House: (i)

Electric motor driven HVW spray pump running/fails to start

(ii)

Diesel engine driven HVW spray pump running/fails to start

(iii)

Hydrant pump running/fails -to start

(iv)

Jockey pump running/fails to start

(v)

Air compressor fails to start

(vi)

Hydro-pneumatic tank pressure low

(vii)

Hydro-pneumatic tank pressure high

(viii) System header pressure low (ix)

Fire in transformer/reactor.

(x)

Fire in smoke detection system

(xi)

Water storage tank water level low

(xii)

High speed diesel oil tank level low

3.8.1 2.3 The following Annunciations should be available in the control room also: (i)

Fire in transformer/reactor

(ii)

Hydrant pump/diesel engine operated HVW spray pump in operation

(iii)

Motor operated HVW spray pump in operation

(iv)

Fire/Fault in Zone 1

(v)

Fire/Fault in Zone 2

(vi)

Fire/Fault in Zone 3

(vii)

Fire/Fault in Zone 4(depending on the number of zones)

3.8.1 2.4 All fire protection equipment should be covered by a regular and strict maintenance and test routine. The hydrant systems should be checked every week

34 which may be possible during night shifts. Sprinkler systems should be checked at regular intervals. Portable equipment should be charged at specified intervals and checked regularly for loss of charge, damage, etc. Records of all tests and checks must be maintained. 3.8.12.5 Provision should be made to switch off the air conditioning equipment in case of fire. 3.8.12.6 Cable entry openings shall be sealed to prevent the spreading of fire. 3.8.13 Diagram of Fire Fighting System A flow diagram of a typical HVW Spray and Hydrant System is enclosed as Fig. 5. 3.9

DC AUXILARY SUPPLY

3.9.1 DC Auxiliary supply is required fo r relays, instrumentation, closing and tripping of circuit breakers, emergency lighting, control board indications, etc. During normal operation, battery charger (rec!lifier bridge with Silicon diodes and Silicon control rectifiers) provides the required DC supply. However, to take care of failure of the AC supply (rectifier), a storage battery of adequate capacity is provided to meet the DC requirement. Normally, the storage battery merely keeps floating on the direct current system and supplies current in case of failure of the rectifier in substation. It is desirable to provide duplicate rectifiers to meet the contingency of rectifier failure. An arrangement shall be made to supply an uninterrupted DC supply to load wherever the·batte_ry charger is facilitated with float/trickle/boost charging. 3.9.2 The voltage commonly used for the DC auxiliary supply is 110 or 220 volts batteries for substations and 48 volts for PLCC. Generally lead acid batteries are used. 3.9.3 Capacity of the battery should be adequate to supply. (a)

Momentary current requ ired for the operation of switchgear.

(b)

The continuous load of indicating lamps, holding coils for relays contactors, etc.,

(c)

Emergency lighting load.

3.9.4 Complete DC equipment for a, substation· may be divided into three parts i.e., storage battery and accessories, ch«:irgirig equipment and distribution board. 3.9.5 The charging equipment generally consists of float cl)arger and boost charger. In major substations, twin float chargers and twin boost·cl:largers or with float cum -boost charges with a suitable switching cubicle a·re generally used for rel iability.

35 3.9.6 The distribution board has an incoming circuit from the DC battery and a number of out going circuits for closing and tripping, alarm and indication for control and relay panels. A separate circuit is provided for the emergency load normally fed from AC supply but is automatically switched on to DC supply in the event of AC power failure. 3.10 AC AUXILIARY SUPPLY 3.10.1 AC supply both single and three-phase, are needed in a substation for internal use for several functions such as:

I

(a)

Illumination.

(b)

Battery charging

(c)

Transformer cooling system

(d)

Oil filtration plant

(e)

Transformer tap-changer drives

(I)

Air compressors

(g)

Power supplies for communication equipment

(h)

Crane

(i)

Breakers/disconnect switch motors

(j)

Fire protection system

(k)

Space heaters in cubicles and marshalling kiosks

(I)

Air-conditioning/ventilation equipment

3.10.2 Auxiliary Transformer The design of AC auxiliary supply system must be.such that it ensures continuity of supply under all conditions, as far as practicable, reliability being the basic requirement. In a substation, it is normally provided from a station transformer connected to the 11 kV or 33 kV station bus. Its -capacity should be adequate to meet the demands of all the essential connected loads. Generally, two such transformers are provided in all major substations. 3_ 10.3 In case of transformers where tertiary winding is available one auxiliary transformer can be connected to tertiary of transformer for station power supply with adequate insulation margin and protection to save the damage to main transformers from the Secondary system faults. 3.10.4 The station transformer is connected to the indoor AC distribution panel through duplicate cables. Duplicate feeds to important loads. are made from the AC distribution· panels through outlets, which are controlled, by switch fuses or circuit breakers. I

J

' 36 In the event of shutdown 'of the entire station, ensure availability of AC auxiliary supply for charging of protective equipments, DG set shall preferably be provided in major substations with Auto Main Fail (AMF) panel preferably. Change over scheme shall be provided in AC distribution panel, to feed important loads by DG set. 3.10.5 Incomer of AC distribution panel shall be provided with 4-pole breaker either it may be from auxiliary transformer or from DG set. 3.11 VENTILATION 3.11.1 Battery Room Ventilation Exhaust fans should be provided. Further it is necessary to ensure sufficient air inlet to the battery room by providing blowers, if necessary. Exhaust alone without air inlet, a negative pressure will be created in the battery room which will cause (a)

Evaporation of electrolyte even at the normal room temperature and the fine spray of electrolyte will settle on cells, stands etc., reducing the electrical insulation of the battery from the ground.

(b)

The hydrogen evolved from the battery may form an explosive mixture if the room pressure has reduced.

Chapter 4

BUS-BAR SCHEMES 4.1

TYPES OF BUS BAR SCHEMES

The various types of bus-bar schemes generally considered in this Manual are: (a)

Single bus-bar

(b)

Main and transfer bus-bar

(c)

Double bus-bar

(d)

Double main and transfer bus

(e)

Ring bus-bar and mesh bus-bar

(f)

One-and-half circuit breaker

(g)

Double-bus double-breaker scheme

4.2

SELECTION OF BUS-BAR SCHEME

4.2. 1 The selection of a bus-bar scheme and its possible extension is an important initial step in substation design. The aspects which influence this decision are operational flexibility, system safety, reliability, availability, ability to facilitate system control and cost. Fi~fure 6 (A to J) shows the various bus-bar arrangements and Fig. 6 (K) shows the graphic symbols for various equipment. An important factor in selection of bus-bar scheme is the degree of reliability of supply expected during maintenance or faults. Careful consideration has also to be given regarding the amount of redundancy to be provided so as to determine the equipment, which can be permitted out of use on account of maintenance or faults. Certain amount of sectionalisation has also to be provided in a substation so as to ensure that in the event of a fault, a large power source does not get disconnected. In the case of step-up substations associated with large generating stations a fault within the substation may have serious repercussions from the point of view of the system operating as a whole and, therefore, a very high degree of reliability is required in such cases as compared to step down or switching stations. Similarly, the exposure of a substatipn to atmospheric hazards such as lightning, marine and industrial pollution etc.; also plays an important part in deciding the type of the bus-bar system. Future expansion of the bus-bar system at least in a foreseable future may also be considered. 4.3

Single Bus-Bar Scheme

4.3.1 This is the simplest scheme, in which each circuit is provided with one circuit breaker (Fig. 6 (A)). This arrangement offers little security against bus bar isolator maintenance. The entire substation is lost in case of a fault on the bus bar or any

I

I

.,

-I

38 bus-bar isolator and also in case of maintenance thereof. Another disadvantage is that in case of maintenance of circuit breaker associated feeder has also to be shutdown. One of the methods for reducing the number of circuits lost in case of a bus fault is to sectionalise the bus as shown in Fig. 6 (B).

I

4.3.2 The arrangement in Fig. 6 (C) is a improvement over that shown in Fig. 6 (B), as additional by-pass isolators are provided to permit feeder circuit breakers to be taken out for maintenance without switching out the associated feeder. On occurrence of a fault on the feeder connected to bus bar through by-pass isolator, the other feeder on that bus section will also be lost. 4.4

MAIN AND TRANSFER BUS ARRANGEMENT (Fig. 6 (D))

This is technically a single bus bar arrangement with an additional bus bar called "Transfer bus" energised from main bus bars through a bus coupler circuit, i.e., for 'n' number of circuits it employs n+1 circuit breakers. The additional provision of transfer bays and bus coupler circuit facilitates taking out one circuit breaker at a time for routine overhaul and maintenance without de-energising the circuit controlled by that breaker as that circuit then gets energised through bus coupler breaker and transfer bus bar. Each circuit is connected to the main bus-bar through a circuit breaker with isolators on both side and through an isolator to the transfer bus-bar.

1

As in the case of single bus arrangement, this scheme also suffers from the disadvantage that in the event of a fault on the main bus bar or the associated isolator, there is a complete shutdown of the substation. Complete shut down can be avoided through sectionalizing the main bus with the provision of additional one single phase bus PT for synchronization in case of more than eight bays. This scheme has been used in India, USA and also in some of the European countries, particularly for step-down substations, as bus-bar faults are rare. 4.5

DOUBLE BUS-BAR SCHEME

4.5.1 In this scheme a double bus bar is provided and each circuit can be connected to either one of these bus-bar isolators as shown in Fig. 6 (E). Bus coupler breaker is also provided so that the circuits can be switched on from one bus to the other on-load. The scheme suffers from the disadvantage that when the circuit breaker is taken out for maintenance, the associated feeder has to be shutdown. This can be avoided by providing, a by-pass isolator across circuit breaker as shown in Fig. 6 (E). But under this condition all the circuits have to be transferred to one bus and protection of feeder has to be transferred to bus coupler. This scheme has the limitation that only one bus is available when any breaker has to be taken out for maintenance. The double bus-bar scheme with by-pass is available when any breaker has to be taken out of maintenance. The double bus-bar scheme with by-pass isolator across circuit breakers is very suitable for large generating stations as well as large grid substations forming part of a well inter-

l

39 connected system wherein a variety of grouping of circuits is required, Fig. 6 (F) shows another alternative of this scheme. In this alternative the by-pass isolators are connected to one of the main bus bars as shown. This scheme constitutes double bus-bar Scheme with main reserve and transfer bus-bars. In both these schemes, use of temporary earthing device is called for during breaker maintenance. As temporary earthing drives can result in serious. accidents, if not removed, it is preferable to provide the isolators on either sides of the circuit breakers across which bypass isolators are provided with integral earthing switcnes having mechanical interlocking features. 4..6

DOUBLE MAIN AND TRANSFER BUS-BAR SCHEME

The limitation of scheme Fig. 6 (F) can be overcome .bY using additional transfer bus, transfer bus breaker and isolators as shown in Fig. 6 (G). In this arrangement, the feeder, the breaker of which is to be maintained is transferred to the transfer bus with.out affecting the other circuits. This scheme has been widely used for the highly interconnected power networks where switching flexibility is important and multiple supply routes are available. This scheme i? also used for splitting networks, which are only connected in emergencies. 4.7

MESH BUS-BAR SCHEME (Fig. 6 (H))

4.7.1 Each circuit is controlled by two circuit breakers and therefore, any one, 9ircuit breaker can be taken out for maintenance without affecting the security of supply. A circuit fault also is cleared by opening of two breakers. In both cases the ring is broken and the bus-bar is reduced to sectionalised single bus-bar scheme. In the case of a feeder fault, the circuit isolator can be opened, the faulty feeder disconnected and both the breakers closed which would close the ring. This system has got a number of advantages such as maintenance of a circuit breaker without loss of supply and without providing by-pass facilities, loss of only the faulty feeder in case of a feeder fault, and loss of only two circuits in case of a circuit breaker fault. There are, however, some problems such as occurrence of a fault when a circuit breaker is being maintained resulting in a double break in the mesh and capacity limitation of the equipment to pass the maximum current that may flow round the mesh. If these are provided for, it adds to cost of the station. In view of these problems, it is considered desirable to limit the number of circuits on the mesh. 4.7.2 The mesh scheme is very suitable where the number of circuits is comparatively small and chances of future expansion are less such as substations associated with generating plants and also step-down substations operating at extra high voltages. This scheme has been used on many of our early installations. However, during the recent past there have not been many installations of this type as this scheme does not lend itself easily to further expansion. However, the mesh

I

JI

.,

1

40

I

arrangement has been widely used in UK for their 275 kV and 400 kV substations and also in USA for their high voltage installations operating at 230 kV and above. 4.8

I

ONE-AND-HALF BREAKER SCHEME (FIG. 6 (I & J))

4.8.1 In this scheme three circuit breakers are used for controlling two circuits as shown in Fig. 6 (I & J). Normally, both the bus-bars are in service . •

A fa ult on any bus is cleared by the opening of the associated circuit breakers without affecting continuity for supply. Similarly, any circuit breaker can be taken out for maintenance without causing interruption. All load transfer is done by the breakers and therefore, the operation is simple. However relaying is somewhat more involved as the third breaker has to be responsive to troubles on either feeder in the correct sequence. Besides, each breaker has to be suitable for carrying the currents of two circuits to meet the requ irements of various switching operations, which may in some cases increase the cost. The breaker and a half scheme is suitable for those substations which handle large amounts of power on each circuit. The scheme has been widely used in USA particularly for their EHV substations operating at 330 kV and above. This scheme has been applied widely in the 420 kV systems in this country also.

4.9

DOUBLE-BUS AND DOUBLE-BREAKER SCHEME

In this scheme two circuit breakers are used for controlling one circuit as shown in Fig. 6 (K). Normally both bus-bars are in service. Similar to breaker and half scheme, a fault on any bus is cleared by opening of the associated circuit breakers without affecting continuity of supply. Similarly any circuit breaker can be taken out of maintenance without causing interruption. All load transfer is done by breaker and therefore, the operation is simple and relaying is also simpler compared to breaker and half scheme. Because of increase in number of breakers per bay and higher cost, double bus double breaker scheme is suitable for those substations, which handle large amount of power.

:

;

••

Chapter 5

SAFETY CLEARANCES 5.1

OVER-VOLTAGE AND INSULATION LEVEL

5.1.1 All equipment installed in a substation are designed to take into account of the rated power frequency voltage of network; temporary over voltages at power frequency caused by e.g. sudden loss of load and I or earth faults; switching over voltages and lightning over voltages. Accordingly equipment is subject to following voltage tests. (a)

Lightning impulse withstand voltage (1 .2/50 micro sec.) .

(b)

Switching impulse withstand voltage (250/2500 micro sec.)

(c)

Short duration power frequency withstand voltage (50 Hz) (wet and I or dry)

(d)

Combined voltage test

Additionally an oscillating voltage or chopped wave test may be required. 5.1 .2 The set of test voltage values determines the insulation level. Standard insulating levels are defined in IEC: 60071-1, -2 or relevant IS. For equipment voltage upto 245 kV, IEC60071-1 specifies s"tandard rated short duration power frequency and lightning impulse withstand voltages. For equipment voltage beyond 245 kV, IEC60071-1 specifies standard rated switching and lightning impulse withstand voltages. The necessary insulation level depends on the insulation coordination, i.e., on the properties of different components of the network (mainly lines), the protection used against overvoltages (ZnO surge arrester are very effective), on altitude and also on the required reliability of the substation (permissible probability of flashover) and may vary in different parts of the same substation. 5.1.3 All EHV apparatus are generally protected against lightning as well as switching over voltage. The equipment used for protection are coordinated with protected apparatus to ensu.re safe operation as well as .to maintain the stability of the interconnected units of the power system. 5.2

SOME DEFINITIONS

5.2.1 Insulation Co-ordination The selection of the dielectric strength of equipment in relation to the voltages which can appear on the system for which the equipment is intended and taking into account the service environment and the characteristic of the available protective devices.

···--- ·- - ---·· ·--·- ··

42 Note : "Dielectric strength" of the equipment, is meant here its rated or its standard insulation level The primary objectives of insulation co-ordination are : • To establish the maximum steady state, temporary and transient over-voltage levels to which the various components of a system may be subjected in practice. • To select tl)e insulation strength and characteristics of equipment, including those for protective devices, used in order to ensure a safe, economic and reliable installation in the event of the above over-voltages. 5.2.2 Rated Insulation Level A set of standard withstand voltages which characterize the electric strength of the insulation. The selection of the rated insulation level consists of the selection of the most economical set of standard withstand voltages (Uw) of the insulation sufficient to prove that all the required .withstand voltages are met. 5.2.3 Standard Insulation Level A rated insulation level, the standard withstand voltages which are associated to highest v9ltage (Um) as recommended in IEC. 5.2.4 "Installation" means any composite electrical unit used for the purpose of generating, transforming, transmitting, converting, distribution or utilizing energy. 5.2.5 Safety Clearance Minimum clearance from any point on or about the permanent equipment where a man may be required to stand (measured 'from position of the feet) to the nearest unscreened live conductor in air. 5.2.6 "Earthed ' or "Connected with Earth": means connected with the general mass of earth in such manner as to ensure at all times an immediate discharge of energy without danger. 5.2.7 "Earthing system" means an electrical system in which all the conductors are earthed. 5.3

ELECTRICAL CLEARANCE

5..3.1 As per Indian Electricity Rules, all electric supply lines and apparatus shall be of sufficient rating for power, insulation and estimated fault current and of sufficient mechanical strength, for the duty which they may be required to perform under the environmental conditions of installation and shall be constructed, installed,

I

43 protected, worked and maintained in such manner as to ensure safety of human being, animal and property. 5.3.2 It is not possible to test the whole HV installation by corresponding test voltages. Steps are to be taken to avoid flashover occurring below the impulse withstand level. Therefore minimum clearance in air between live parts or between live and dead parts are stated, to obtain the required insulation level in arrangements which have not been tested. Smaller clearances are permissible if the particular arrangement has been tested by the prescribed insulation test (IEC:60071-1, -2 ) taking into account all relevant environmental condition e.g. rain, pollution. The specified electrical clearance must be maintained under all normal conditions. 5.3.3 The clearooces may also be lower, where it has been confirmed by operating experience that the over voltages are lower than those expected in the selection of the standard withstand voltages or that the gap configuration is more favourable than that assumed for the recommended clearances. 5.3.4 The various equipments and other facilities discussed in Chapters 2, 3 and 4 have to be so arranged within the substation that certain minimum clearances are always available from the point of view of the system reliability and safety of operating personnel. The following parameters are usually defined: (a)

Minimum height of live parts above the accessible surface.

(b)

Minimum height of lowest parts of insulators above the accessible surface.

(c)

Minimum horizontal distance between a live part and protective rails, fences, etc.

(d)

Minimum distance between a live part and human body (or conductive tools) during the work in the substation.

5.3.5 Clearances as per Indian Standard Code are provided for electrical apparatus so that sufficient space is available for easy operation and maintenance without any · hazard to operating and maintenance personnel working near the equipment and for ensuring adequate ventilation. These include the minimum clearances from live parts to earth, between live parts of adjacent phases and sectional clearances between live parts and work section required for maintenances of an equipment. Besides, it is also necessary that sufficient clearance to ground is also available within the substation so as to ensure safety of the personnel moving about within the switchyard. 5.3.6 The minimum air clearance to ground and between phases are function of switching, lightning impulse withstand voltage, environmental condition and gap factor which depends on electrode configuration. For voltage upto 245 kV, usually

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44 lightning over voltages are considered the governing factor whereas for 420 kV and higher voltage switching over voltage are considered the governing factor. 5.3.7 For determination of phase-to-ground air clearance, the "rod-structure" configuration is the worst electrode configuration normally encountered in practice; the "conductor-structure" configuration covers a large range of normally used configuration. But the necessary inter-phase clearance is more related to the "rodconductor" and "conductor- conductor" configuration. The unsymmetrical " rodconductor" configuration is the worst electrode configuration normally encountered in service. The "conductor-conductor" configuration covers all symmetrical configurations with similar electrode shapes on the two phases. 5.3.8 For voltage upto 245 kV, the air clearance phase-to-earth and phase-to-phase is determined from for the rated lightning impulse withstand voltage. For voltage greater than 245 kV, the phase-to-earth clearances is the higher value of the clearances determined for the rod -structure configuration for the standard lightning impulse and for the standard switching impulse withstand voltages. The phase-tophase clearance is the higher value of the clearance determined for the rodstructure configuration for the standard lightning impulse and for the standard switching impulse withstand voltage . .

5.3.9 Table 5.1 gives the recommended values of clearance required for substation up to 800 kV. Table 5.1 : Recommended Clearances Highest system voltage . CkVl

36 72.5 123 145 245 420 800

•

Lightning impulse voltage lkVnl

170 325 450 550 550 650 950 1050 1425 2100

Switching impulse voltage (kVp)

-

-

1050 (Ph·E) 1575 (Ph-Phl 1550 (Ph-E) 2550 (Ph-Ph)

Minimum clearances '

Between Phase and Earthlmm\ 320 630 900 1100 1100 1300 1900 2100 3400'

-

6400·

Safety clearances (mm)

Between Phases (mm) 320 630 900 1100 1100 1300 1900 2100

-

4200.. 9400..

2800 3100 3400 3700 3700 3800 4300 4600 6400 10300

Based on Rod-structure air gap. Based on Rod-Conductor air gap.

S

This value of air clearances are the minimum values dictated by electrical consideration and do not irclude any addition for construction tolerances, effect of short circuits, wind effects and safety of personnel, etc.

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45 Notes:

•

Safety clearances are based on the insulation height of 2.44 m which is the height of lowest point on the insulator where it meets the earthed Metal.

•

The distances indicated above are not applicable to equipment which has been subjected to impulse test since mandatory clearances might hamper the design of the equipment, increase its cost.

•

The values in Table refer to an attitude not exceeding 1000 m and take into account the most unfavourable conditions which may result from the atmospheric pressure variation, temperature and moisture. A correction factor of 1.25% per _100 m is to be applied for increasing the air clearance for altitudes more than 1000 m and upto 3000 m.

•

No safety clearance is required between the bus-bar isolator or the bus-bar insulators. However, safety clearance is necessary between the section isolator or the bus-bar itself and the circuit breaker.

•

For the purpose of computing the vertical clearance of an overhead strung conductor the maximum sag of any conductor shall be calculated on the basis ·of the maximum sag in still air and the maximum temperature as specified.

5.3.1 O. As an alternative to maintain safety clearances in some substation earthed

barriers are used to ensure safety of the maintenance personnel. The use of earthed barriers is quite common at lower voltages of 36 kV 72.5 kV. However, as the voltage increases, the saving in space decreases and at 420 kV level, normally earthed barriers are not provided. In case paucity of space if 2.44 m clearance is not available then localized earthed fencing with safety clearance can be considered by the designer.

Chapter 6

GAS-INSULATED SWITCHGEAR 6.1 SF5 gas-insulated switchgear (GIS) is now widely used for construction of compact substations. Some of the applications for which GIS is eminently suited are listed below:

(i)

Installations for which stringent demands regarding security must be met.

(ii)

Indoor substations to occupy the minimum space in densely populated urban areas.

(iii)

Installations in areas with high risk of pollution and corrosion from industrial plants or by marine and desert climates.

(iv)

Extension of conventional outdoor installations where space is at a premium.

(v)

Replacement of conventional switchgear by SF6 metal clad switchgear for a higher system voltage without increasing the space occupied.

(vi)

Applications involving use of metal clad switchgear with components of conventional design to minimize area requirement.

(vii)

Underground substations for pumped storage and other hydroelectric power stations.

(viii) Outdoor installation where surface is not easily available. (ix)

Installations in difficult site conditions (e.g., seismically active areas, high altitude areas etc.).

6.2

CONSTRUCTIONAL DETAILS

6.2.1 For any single line diagram, there are usually a number of possible physical arrangements. The shape of the site of installation and the nature of interconnections,. i.e., lines and/or cables are to be considered. Most GIS designs were developed initially for double bus, single breaker arrangement. This has been widely used and provides good reliability, simplicity in operation, easy protective relaying and excellent economy. 6.2.2 It is found economical to adopt 3-phase enclosure up to 145 kV system voltage. For system voltages above 145 kV, single-phase enclosure designs are preferred. Functior:ially, the performance does not differ between 3-phase enclosure and single-phase enclosure of GIS but, it could depend on users choices. 6.2.3 The GIS components like circuit breakers, load break switches, earthing switches, isolators, voltage transformers, current transformers, surge arresters and connectors are functionally separate modules of a standardized modular system .

·· - - -·- ·-············· ·· · ······ ·· ····· ·

48 6.2.4 The enclosure of GIS could be made of aluminium alloy or stainless steel. The selection of material largely depends on temperature rise considerations and permissible limits depending on emissivity (solar radiation) and/or temperature rise of conductor). 6.2.5 SF6 is five times as dense as air. It is used in GIS on pressures from 3.5 - 7 bars absolute. The pressure is so selected that gas will not condense into liquid at the lowest temperature, the equipment could experience. This gas is about 100 times better than air in terms of interrupting arcs. 6.2.6 Cone or disc shaped insulators moulded from high quality resin support to active parts in side the enclosures and seNe as barriers between adjacent gas-filled compartments. 6.2.7 Silver-plated plus contacts provide connections components and bolted flanges between the enclosures.

between

individual

6.2.8 The operating mechanism for circuit breaker could be electro-hydraulically (hydraulic spring drive) operated or spring-spring operated for least maintenance. 6.2.9 The load break switches and high speed earthing switches are operated by motor charged spring mechanism and the safety earthing switches and disconnects are operated by motor operated mechanism. 6.2.1O Manual operation of safety earthing switches is also possible as an alternative to motor operation. 6.2.11 Connectors enable straight line, 90 deg, 120 deg to 180 deg, four way and T-connections between the various elements. 6.;?.12 The modules include compensating units to permit lateral mounting, axial compensation, parallel compensation, tolerance compensation, vibration compensation etc. The lateral mounting units enable sections of switchgear to be removed and re-inserted without interfering with adjacent parts. Axial compensators take-up the changes in bus bar length due to temperature variation. Parallel compensators are intended for accommodating large linear expansions and angle tolerances. Tolerance compensators are intended to take up manufacturing and assembly tolerances. Vibration compensators absorb vibrations caused by transformers connected directly to SF6 switchgear by oiUSF6 bushings. 6.2.1 3 Approximate space requirements for double bus lay out with vertical breaker scheme can be estimated approximately by assuming the width (3.0 m x 8.5 m x 8.0 m) leaving 1.5 m along the depth, for panels, 2.0 m for movement on either side along the length of bus bar for 400 kV system

..... .......... . - . ... ..

·-· ·- · ... ··· - · .......

-·

49 6.2.14 Depending on the bus bar arrangement, the various elements are assembled to constitute various bays in the desired sequence. 6.3

CONTROL CABINETS

6.3.1 The elements for control, indication and alarms are contained in local control cabinets mounted close to bays. The elements normally mounted in the control cabinets consist of the following: (i)

Mimic diagram with control switches for electrically operated breakers, load break switches, disconnects and earthing switches and indicators for all components provided with auxiliary switches.

(ii)

Local/Remote Selector Switches.

(iii)

Alarm facia with indicating lamps for monitoring operating system, gas density and auxiliary supplies.

(iv)

Contactors, timing relays etc.

(v)

Terminal blocks.

(vi)

Interior lighting, heater, cable glands.

(vii)

Lockable bypass switches for defeating the interlocks to facilitate maintenance work.

6.4

INTERLOCKS

6.4.1 GIS control cabinet includes electrical interlocks to prevent incorrect switching sequence and ensure correct operations of isolators, circuit breakers and earthing switches from local control cabinet or from the control room. 6.5

SAFETY LOCKS

6.5.1 Safety locks for locking the disconnects and earthing switches in the positions "Operation" or "Maintenance" are also provided. In the "Maintenance" position these locks interrupt the control circuits of motor drives for disconnects and earhing switches. In the manually operated earthing switches, these locks in the "Operation" position do not permit engagement of manual operating handle with the earthing switches operating shaft. 6.6

SUPPORTING STRUCTURES

6.6.1 Depending on the design of installation, the GIS can be self supporting or erected on steel supporting structures of simple design anchored to the substation floor.

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50 6.7

GROUNDING

The three enclosures of single phase GIS are required to be bonded to each other at the ends of GIS to ensure to flow circulating currents. These circulated enclosures currents cancel the magnetic field that would otherwise exist outside the enclosure out to conductor current. 3-phase enclosures GIS does not have circulating currents but does have eddy currents in the enclosure and should also be multi point grounded. Although multi point grounding leads to some losses in the enclosure due to circulating current multi point grounding results in many parallel path for the current from an internal path to flow to the switchyard ground grid. The recommendations of manufacturers and multi point grounding concept normally ensures touch and step potentials within safe levels prescribed by IEEE 80. 6.8 The GIS should be extendable to meet the requirement of addition of bays in future. The side on which the extension is to be made should be provided with suitable extension bellows/flanges with blanking plates. The building that is to house the GIS should have space provision for future extension. 6.9

GIS TERMINATIONS

GIS terminations could be any of the following: •

SF6 to air bushings

•

SF6 to cable termination

•

SF6 to oil bushings for direct connection to transformer

•

SF6 bus duct

All termination modules are commonly used to connect the GIS with transformer. Overhead lines could be connected to GIS either though cables or through SF6 to air bushings. Type of terminations has also bearing on the size of substations. If cable or SF6 bus ducts are used, substation can be kept quite compact. SF6 to air bushings, on the other hand, requires minimum clearance in air and thus requires more space and in addition, they are subject to environmental conditions. Especially in cities/ industrial areas where space is both restricted and expensive and the surrounding environment has impact on type of termination, preference should be for cable termination or SF6 bus duct. Selection of cable termination will have to be judiciously done keeping in view the specific requirement.

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Chapter 7

PHYSICAL LAYOUT 7.1

STATION SITE

7.1.1 Site limitation is one of the important considerations in deciding the type of layout of a substation. It should be free from all obstructions from the point of view of convenience of terminating high voltage transmission lines. At the same time it should be accessible to the public road to facilitate transport of plant and equipment. As far as possible, it should be near a town and away from municipal dumping grounds/ areas and also away from police and military rifle ranges. The site should have good drinking water for station staff. Outdoor substation should not be within 3 km from aerodrome or should be as per aviation guidelines. 7.1.2Type of isolators has great influence in bay width and level of the substation. Using double break type of Isolators compared to Horizontal Centre Break Isolators, bay width can be reduced by 10-15%. Pantograph isolators are best suited for Double Main and Transfer (OMT) scheme (with flexible bus arrangement) but it requires proper and careful erection of isolator and stringing of buses. By using vertical break isolators, the height of levels increases but vertical break isolators are more economical for voltages more than 400 kV due to lesser length of beam, bay width and ultimately lesser requirement of land. 7.1.3 While planning the layout and orientation of an EHV sub station in order to avoid right of way problem in future, approximate provision sh.ould be made for installation of towers for incoming/ outgoing lines and this aspect should be considered simultaneously and provision made accordingly in the construction of emanating transmission lines. It is necessary to consider in the layout design, the possibility of extension of substation. The line and transformer bays sequence should, if possible, be fixed minimizing the possibility of overloading bus bars and connecting conductor. 7.2

SELECTION OF LAND

The land for substation should be selected on the basis of size of substation. switchyard layout design depends on switching scheme, shape and size of land. A substation requires land for consist of switchyard, control and administrative building, stores, security barrack, colony, etc. Considering increasing cost of land but keeping provision for future extension, following size of lands are required for a substation

52 7.3

ILLUSTRATIONS

7.3.1 Figure 7 (a) to 34 illustrates some typical layouts of 420, 245, 145, 72.5 and 36 kV substations as mentioned in Table 7.1 including some typical layouts adopted recently commissioned substations. These layouts are being given for general guidance only and are not intended to serve as standard layouts. The various types of layouts included herein are as follows: Table 7.1 : Various Types of Layouts Generally Adopted Fiqure No. Fiaure 1 Fiaure 2 Fiaure 3 Fioure 4A. Fioure 4B Fiaure 5 Fioure 6 Figure No. Figure 7 (a) Figure 7 (b) Figure 8(a) Figure 8{b) Figure 8(c) Figure B(d)

Figure B(d), Sheet 1 of 6 Figure B(d) , Sheet 2of 6 Figure 8(d) , Sheet 3 &4 of 6 Figure B(d) , Sheet 5 of 6 Figure 8(d) , Sheet 6 of 6 Fioure 8Cel Fioure 9A Figure 9B

Fioure 9C Fioure 10A Figure 1OA , Sheet 1 of 2 Figure 1OA, Sheet 2 of 2 Fioure 10B Fioure I OC

Descriotion Tvnical cable trench section Switchvard and substation oil handlina svstem schematic oioina diaaram Tvaical comoressed air svstem for air blast circuit breaker Tvoical 400/220 kV control room I around floor) Tvnical 400/220 kV control room (first floor) Details of Hioh Velocitv Water fHVWl sorav svstem Sinole line diaaram for various tvoes of switchin ~ schemes Voltage Bus system Bay width Bus level ltvl">icall kV Double main and transfer bus 420 27m Low (Plan) 420 Double main and transfer bus 27m Low
Plan

27m

Low

420

Sections

27m

Low

420

Plan of transformer area

27m

Low

420

Section of transformer area

27m

Low

420 245 245

24m 15m 15m

Low Low Low

245 245 245

Breaker and half Double main and transfer Main and transfer with provision for conversion to double main and transfer Double main and transfer Double bus Single line diagram and plan

16m 15m 15m

Low Low Low

245

Sections

15m

Low

245 245

Double bus Double bus

16m 17m

Hiqh Hioh

•

...

53 Fiaure 11 Fiaure 12 A Fiaure 12 B Fiaure 13 Fiaure 14 Fiaure 15 Flaure 16 Flaure 17 Flaure 18 Fiaure 19 Flaure 19A Figure 19A, Sheet 1 of 4 Figure 19A. Sheet 2 of 4 Figure 19A, Sheet 3&4 of 4 Figure 20 Fiaure 20A Fiaure 21 Flaure 22 Fiaure 23 Fiaure 24 Fiaure 24A Flaure 25 Fiaure 26 Flaure 27 Fiaure 28 Fiaure 29 Fiaure 30 Fiaure 31 Fiaure 32 Fiaure 33 Fiaure 34

245 245 245 245 245 245 245 145 145 145 145 145

Double bus Double bus GIS Double bus GIS Main transfer Main and transfer Slnole bus Slnale bus Double bus Double bus Main and transfer Main and transfer Single line diagram

145

Plan

12 m

Low

145

Sections

12 m

Low

145 145 145 145 72.5 72.5 72.5 72.5 72.5 72.5 72.5 36 36 36 36 36

Main and transfer Main and 1ransfer Sinale bus Sinale bus Double bus Double bus Double bus Main and transfer Main and transfer Sinale bus Sonale bus Double bus Double bus Main and transfer Main and transfer Sinale bus Sinale bus

10.4 m 10.5 m 10.4 m 10.4 m 7.6 m 7.6m 7.6m 7.6m 7.6m 7.8m 7.6m 5.5m 5.5m 5.5m 5.5m 5.5m 5.5m

Low Low Hiah Low Hiah Low Law Hiah Law Hi ah Law Hiah Low Hiah Low Hi ah Low

36

17 m NA NA 17 m 17 m 17 m 17 m 10.4 m 10.4 m 10.4 m 12 m 12 m

Law

. .

Hiah Law Hiah Low High Low Hiah Low Low

Note: Layouts shown in this Manual are the ones generally adopted by the utilities

7.4 It is recommended that based on the equipment selected, the basic data included in this manual and the operating experience, the layouts may be standardized so that a uniform design is obtained which would reduce the cost as well as construction period. 7.5

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LAYOUT OF CONTROL ROOM BUILDING

The size of the control room building is dependant on the number of rooms, equipments in the room and varies from utility to utility. Typical sizes for different rooms of the control room building for a 400/220 kV substation with conventional control and relay panels having the following number of bays is given in Table 7.2. 400 kV system - One and half breaker bus scheme having 8 nos. diameters to. accommodate 12 nos. line feeders, 2 nos. 400/220 kV transformers, 2 nos. bus reactors.

54 220 kV system - Double main and transfer bus scheme to accommodate 7 nos. line feeders, 2 nos. 400/220 kV transfotmers, 1 nos. bus transfer and 1 nos. bus coupler bay. Table 7.2: Typical Sizes of the Different Rooms in Control Room Building SI. No. 1.

2. 3. 4. 5. 6. 7.

8. 9. 10. 11.' 12. 13. 14.

Control room Control Room Relav and PLCC Room MCC Room /Main Switchboard. ACDB. OCDB, Batterv Charaer) Battery Room (Accommodation of 2 nos. 220 V & 2 nos. 50V Batterv Bank in Sinole Row Sinnle Tier Arranoementl Communication Room Shift-in-Chame's Room Enoineer's Room Conference Room Maintenance Room Librarv cum Record Room Electronics Test Lab Maintenance Slaff Room Toilets Pantrv

Approximate size llenoth x breadth\ 15mx10m 20mx15m 15mx14m 15 mxBm 15mx7 m Smx4m 7mx5m 7mx5m 6mx5m 6mx5m 9mx5m 6mx5m As oer reauirement As oer reouirement

For an automated substation, relays and PLCC equipments may be accommodated in a weather proof bay controller unit located in the outdoor switchyard. Hence Relay, PLCC room and communication room are not required and size of control room can be reduced as the control room for such type of application should be suitable for accommodation of Computer peripherals and communication equipment.

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.. ABOUT CONTRIBUTORS Shri H.G. Chhabra did his B.E. (Elect.) from Punjab Engineering College, Chandigarh, in 1972. He has a wide experience, and is presently working as Superintending Engineer in Bhakra Beas Management Board, Chandigarh.

Shi:i M. Gopala Rao, M.E. (Elect) & F.I.E. is presently Chief Engineer Construction AP TRANSCO. He has 35 years of experience in various areas of Engineering, and introduced 132 kV Shunt Capacitor Banks in 1998 in AP, TRANSCO. He is trained in GIS in Germany and Japan, and has contributed several technical papers in National and International Seminars.

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Shi:i M.M. Goswami is presently working as Additional General Manager in POWERGRID. He has over 25 years of experience working with ~·arious organizations like ASEB, NTPC, POWERGRID in the field of Design & Engineering of Transformer and Substations, Condition Monitoring, DOA etc. He is also associated in the development of technical specification, design review and testing of first 800 kV transformer and reactors being corrunissioned by PO\VERGRID. He has published a number of technical papers. He is also associated with standardization of Transformer & Substation by BIS, CB IP, CIGRE etc. Shri R.K. Gupta is Post Graduate in High Voltage Engineering from Govt. Engineering College, Jabalpur, and PGDC in Tuem1al Power Plant Engineering from NPTI, Delhi. He joined POWERGRID in 1998 as Executive trainee. At present, he is working as Assistant Chief Design Engineer in Corporate Engineering (Substation) Department. He is involved in various substations engineering activities relating to standt rdization_ of Layout, type testing of various equipment, failure analysis of Transformer/Reactors and Design Review & Type Testing of the first 800 kV class Shunt Reactor.

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Shri Raj Kumar did his B.E. from IIT and is presently working as General Manager (Design E&M) in NHPC: Faridabad. He has very rich experience in design as well as construction of EHV Transmission Systems. Associated with 400 kV field testing, he. contributed to elimination of closing resistors from 400 kV CBs. He is senior member of IEEE, associated with Power Engineering Society, CIGRE National Study Committee 23,38,34,CS and presently A2-3 l on Contamination in Transformer Oil.

Shri S.K. Ray Mohapatra was born in Orissa, India in 1961.He graduated in Electrical Engineering from Sambalpur University, Orissa in 1982 and had his Master's Degrees and MBA from Indian Institute of Technology, Kharagpur and Faculty of Management Studies, University of Delhi in 1984 and 2003 respectively. His professional experience of more than 20 years includes Project appraisal, tendering & procurement, design and engineeri ng of EHV substations with the Central Electricity Authority of Government of India, identi fication and investigation work for harnessing hydro power potential (micro I mini I small hydroelecuic power projects) and assessment of wind power potential with Govt. of Orissa (India) and testing & quality control of PVC & XLPE cables of 11 kV .and 33kV grade with M/s NlCCO Orissa Ltd., India. He has already contributed ten papers and articles in National seminars and Indian Power magazines and representing as a member in various technical committees of CBI&P, India. Subrata Mukhopadhyay was born in Asansol, India in 1947. He graduated in Electrical Engineering from Jadavpur University, Calcutta in 1968 and had his Master's and Doctorate Degrees from Indian Institute of Technology, Kharagpur and Roorkee in 1970 and 1979 respectively. His employment experience of more than 34 years includes teaching and research in Roorkee, and power system planning, design and operation with the Central Electricity Authority of Government of India. He has authored two books and twentyseven papers, won IEEE Third Millennium Medal in 2000, PES Delhi Chapter Outstanding Engineer Award & PES Asia-Pacific Regional Outstanding Engineer Award for 2001, IEEE RAB Leadership & Achievement Awards in 2002 & 2004 respectively. Since beginning of 2005 he is in the PES Governing Body as Asia-Pacific Regional Representative. He is also Fe\low of the Institution of Engineers (India) and Institution of Electronics and Telecommunications Engineers (India). Shri RN. Saini did his BE (Elect.) from Malviya Regional Engineering College, Jaipur, in 1972 and later M.Tech.(Power Apparatus & Systems) from Indian Institute of Technology Delhi, in 1983. He is presently working as Superintending Engineer (400 kV Design) in Rajasthan Rajya Vidyut Prasaran Nigam Limited. He had been posted on deputation in CEA during 1978-83. He has vast experience in design of EHV substations. Shri K.S. Kattigehallimatt Chief Engineer (Retd), Karnataka Power Transmission Corporation Ltd.

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I CENTRAL BOARD OF IRRIGATION AND PO\VER

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Malcha Marg, Chanakyapuri, New Delhi- ll 0 021, India Phones: 91-11-26115984, 261ll294, 26875017, 26880557 Fax: 91-11-26116347 E-mail : [email protected], [email protected] Websi te : www.cbip.org

Manual on

SUBSTATION LAYOUT "

( \

DRAWINGS

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Publication No. 299

Editors

G.N. Mathur R.S. Chadha

NEW DELHI

ISO 9001 : 2000

CENTRAL BOARD OF IRRIGATION & POWER Malcha Marg, Chanakyapuri, New Delhi 110 021

TYf. SECTION

SECTION

3-~

2~?

--~~H--~-76l<6 MS !'VJ

$ECTIQN 4-4

SECTION ft-2

~

&

;s-3

·.EIAN TRAY SJ.lffORT FOB SECTIQN 1-1

TXP· PEIAIL Of SLAB

R.C.C MIX. SHOULD BE M20 GRAO~.

lfAM CONCRETE SHALL SE 1:4:6. CLEAR COVER FOR 801TOM SLAB R£1NF. ON TOP SIDE IS 25MM. LIFTING HOOK ARE TO B£ PROVIDED IN EVERY TENTH SLAB. 7. NECESSARY OPENING SHALL BE PROVIDED AT APPROPRIATE LOCATIOPN TO TAKE OUT CABLfS. 8. FOR ACTUAL DEPTH OF TRENCHES REFER CABLE TRENCH lAYOUT. 9. F.G.L DENOTES FINISHEO GRAOEt> LEVEL (FORMATION l.EVEl). 10. F.G.L TO BE TAK€N FROM LAYOUT ORG. 11. A SLOPE OF 1:250 SHAU. BE GIVEN IN lHE DIRECTION PERPENOtCULAR TO THE RUN OF THE TRENCH FOR ALL SECTIONS. 12. ALL CABLE TRENCHES SHALL BE GIVEN A SLOPE OF 1:500 IN THE DIRECTION OF MAIN RUN. t3. EARTHING CONDUCTOR '£' 50X6 ·MS FlAT WOULD BE WEt.OEO ON THE CABLE SUPPORTING STRUCTURES BEFORE INSTAUATION

SUPPORT

DETAIL OF TRENQR kOVEB FOR SECTION 3-;i & 4-4

~

DETAIL OE TRENCH COVER SLAB ER SECIION (1-1) & (2-2}

All DIMENSIONS ARE IN MM UNl..ESS OTHERWISE SPECtFlEO. DO NOT SCALE THE DRG. FOLLOW WRITTEN DIMENSIONS ONLY.

OF CABLES. l 4. ALL STEEL STRUCTURE PLATES WOULD BE PAINTED WITH NON .CORROSIVE PAINT ON A SUITABLE PRIMER BEFORE INSTAUATlON Of CABLES EARTHING CONDUCTORS WOULD HAVE RED PAINT. 15. TRENCH WALL SHALL Cl.EAR THE; EQUIPMENT FOUNDATION 8Y 100 MM. 16. NECESSARY CONSTRUCTION JOINTSHAU. SE PROVIDED AT EVt:RY 30M (MIN.) OR /IS PER SITE CONDffiON. 17. 40 MM CLEAR COVER FOR WALL AND BOTTOM SLAB REINFORCEMENT WHICH IS TOWARDS EARTH SIDE SHAU. BE PROVIDED. 18. ALL SUPPORT ANGLE SHALL BE L50X50X6. 19. ANCHORING Fl.AT (75X6 MM) SHALL BE PROVIDED AT EACH SUPPORT ANGLE POINT. 20. EARTHING CONDUCTOR MKD 'E' SHALL. BE PROVIDED ON THE TOP TIER OF EACH CABLE TRENCH SECTIONS.

l'XP DETAJL OF M!CUQRIN!J J5X6 ¥ S FLAT

.fLA1i CAIU.R TRAY 8UPP08T FOR

1. 2. 3. 4. 5. 6.

CABLE SUPPORT

=. . . . . .

FiGURE-1

f

MANUAL ON SUBSTATIONS

s[(

(LAYOUT & DESIGN} TYP~CAL CABLE TRENCH SECTIONS

SE9ll0f9 X-X

DETAIL OF

JJrnNG HOOK

FOR SECTION 1-1 & 2-2

SECTION Y-X SHEET1 OF1

T \AUllHIOJUST£0 TO RELWN

tH:!..1:aR£o

o.D9EO CORING PRESSOR£ CMANGES ClJe TO YEMI' BUT TO 0P£N

C!fl.CIMY

(l(JRING Fll..t.!NG EMPTYING OF TANK

Q

1'R~~9FOR~R 6R::OA~.t>I OU.."\

TYPl()At. SANK OF Ft.OCR

MOUNTEO

~T

BREAl
DUPLICATE MAIN

i ,,,..?,~ a:ffi ~e o et<. tl'IA'l.JZFE'R

P'~

ROOTING ~LVeS !"OR SECTIONAL

'• 'l

OONOIT1m~1NG

AIR REO\JCING VALVE

\

~AOEFIS

6 VILTER - - - - $0AVENGltl0 $1.l'ilPS {lC-0·3828)

I

I TO ATMOSPHERE

EXPLANATION ORA fN--·

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MANUAL

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SWITCH YARD 8i SUB-STATION

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SCHEMATIC PIPING DIAGRAM

METALLIC HOSE (X·O·lfl2$)

LE GENO

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PRESSURE REl.IEF 'l«ILVE

(>-

UNLOADER. (PART Of COMP~SSOO)

0

COM.OR€SSOR

@

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0

l.OW PRESSURE SWITCH

@

PRESSURE GAUGE

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AFTER COOi.ER PRES~ CONTROi,..

PRESSURE RECUC.ING VALVE

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FIGURE-2

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FIGURE- 3

SCHEDULE OF OPENINGS

!TYPE

8

I

I I

0

! I !

DESCRIPTION

NOS.

SIZE

DOORS D

01

l 02 f

------ ------

I

2.0l'I

x 2.l+M

l.2H X 2.l+M 0.9K X 2.l.H

! 03

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i

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I

SD

x 2.4H

3

DOOi! Wlt11 Al.UHIHIUH Fl'IAHE ANO Gl.AZEll DOUB!.£

2

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8

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4

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2

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~I!.

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':

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l.9M X l.6SM

15

W2 1.211 X l.68H

3

i WI

li

i W3 I

VENTILATORS . VI

10

5.0H X l.6SH

10.45H x 0. 9H

I

6

ALllHINWtf GUottl> lll!ll0019.

.. ALU:lllNllM WAU:I> llllllJOW. AW~Nll,JH

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IAlUHJlllllH GU.ZED LOUVEllED

i

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I I

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l'l!:CfROUIC TE5T I.AB

STAFF OfflCf

MAIT. 5TAff' .ROOM

FIGURE-45 PICAL 400/220KV CONTROL ROOM

FIRST FLOOR FIRST FLOOR [

_ _ _ 1 _

_

MANUAL ON SUB STATION LAYOUT $ DESIGN

@

SCHEDULE OF OPENINGS

@

5 . 50

0

_J_

CABLE DUCT

I

---.--@ 50fl{l

"

BAn-ERY ROOM

UBR.AR.Y

• 70

PANTRY

TYPE DOORS

SIZE

NOS.

DESCRIPTION ALUMINIUM OOOR WITH &ORMA BTS80 ~ UNIVERSAL FLOOR SPRIN~, DOUBLE DOOR WJnf MECHANICAL SACK C!-!E<:K, ttYORAlJUC HOU> OPEN OR DELAYED ACTION.

MD

2.2M X 2.4M

D

2.0M X 2.4M

2

OOOR WITH ALUMINIUM FRAME AND GLAZED SHUTTER.

DI

f.Ztt X 2.4M

3

OOOR WITH ALUMINRJM FRAME ANO GLAZED SHUTTER.

DZ

0.9H X 2.4M

4

OOOR Wl!JH ALUMINIUM FRAME ANO GLAZED SHUTTER.

5 4

TEAK WOOD FlW1EWOfU\ WllH FLUSH OOOR OST.

03

0.8M X 2.4M

SD

0.9M X Z.4M

RS

Z.4M X 2.4M

Tl!AK WOOi> FRAMEWORK WITH FLUSli DOOR OST.

MS ROLLING SHUTTERS

WINDOWS WI

l.9M X l.68M

13

W3

l.5H X L68M

7

ALUMINIUM GLAZED WINOOW. ALUMINIUM GlAZEO WINDOW.

VENTILATORS VI

0.45H X 0.9M

7

ALUMINIUM GLAZEP LOUVER!;D VEMTILATORS.

-+--~@ LOBBY

AD INISTRAT VE

FFICE AREA

FIGURE 4A TYPICAL 400/220KV CONTROL ROOM :.

GROUND 'FLOOR . --

.. ..... ··----··-····- .- .... ;

·~···-·

____

_,.~

..........

--~···-..,.__

________

GROUND FLOOR MANUAL ON SUB STATION LAYOUT ¢ DESIGN

·---------·--···~ --········-----------------------------------------------------------.-:A=PP::E:::-:N=D1~x--:1=11:-:r=a=-=rE=c::HN:::I::-CA:-:-L--=sP=E=c1=F:::IC:-:-A:::TI:::ON:-:--1

l

F'OR F'IRE PROTECTION SYSTEM

------+D=3
1

.

L

~CTOR

TRANSF'DRHER.

.

LEGEND

i

-F-F-PH-8.-

'Y-----+------.

ALARM GATE VALVE NORMALLY OPEN GATE VALVE NORMALLY CLOS~D NON-RETURN VAL VE GLOBE VALVE NORMALLY OPEN GLOBE VALVE NORMALLY CLOSED ~FLOAT OPERATED GATE VALVE

CONTROL

DG SET

BUILDING

ROOM BUILDING

** *......

I

TO TART

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~ ®

1

I I

,J ';

v-

~

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I

IO

ru

\

PRESSURE GAUGE PRESSURE SWITCH

@ LEVEL GAUGE ~ LEV£L SWITCH

PUMPHDUSE

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@ D ~

~

BASKET STRAINER

FLOAT OPERATED LEVEL GAUGE

Y-TYPE STRAINER \ti ATER MOTOR GONG

REDUCER THREE \JAY COCK/ VAL VE

y VENT . y. DRAIN ~ OUT DOOR HYDRANT

D I-

I

·e

TEST VALVE:

. J.

D

~

I

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-[ INDOOR HYDRANT ·~ QUARTZOlD BULB DETECTOR

LL

~

HV\/ SPRAY NOZZLE

@PUMP -

\/ATER LINE

gJ DELUGE VAL VE

I DRAINOVERF'LOIJ

\./ATER STORAGE

.I8NK

\./ATER STORAGE TANK

FIGURE - 5

TO DIESEL ENGINE.

DIESEL TANK

MANUAL ON SUBSTATION CLA YOUT 8c DESIGN>

TYPICAL ARRANGEMENT Of HV"1 SPRA y SYSTEM

DETAILS Of HIGH VELOCITY 'vi ATER SPRAY SYSTEM

• 1. THE HYDRANT POINTS F'OR TRANSF'ORMER/ REACTOR SHALL BE LOCATED AT LEAST 20M AIJAY FROM THEM.

2. AS SAFETY MEASURE, A 'WARNING PLATE SHALL BE PLACED NEAR HYDRANT POINTS FDR TRANSFORMER/ REACTOR TO CLEARLY INDICATE THAT \./ATER SHALL BE SPRAYED ONLY AFTER ENSURING THAT THE POW'ER TO THE TRANSFORMER/ REACTOR VHlCH IS

ON f"IRE IS $'WITCHED Off

AND THERE ARE NO LIVE PART \JITHIN 20 M. DISTANCE OF THE PERSONNEL USING THE HYDRANT.

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TAANSFORMEP. CIRCUlT BREAKER

lSOLATOR HCf3. lSOlATO~

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NO'tfi:·OlHER l'ft;MS ~. g. C"f. PT. SA.CVf. <;C ETC NOT $Hl'..%'\ll't ·---:·~--

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IFiGURE - 6 { A TO K . I ~-~-·~----·:..--~-·-~

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C.L. LIGHTNING MAST

0

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MAIN BUS N0.1

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C.L. BREAKER

SECTION E-E

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8000 .

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STR-CTURE

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SECTION A-A

FIGURE- 7 (b)

MANUAL ON SUBSTATIONS

'l .I

I

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(LAYOUT & DESIGN} DOUBLE MAIN AND TRANSFER BUS TYPE 420KVB!l 1550KVp

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-1 ·-.~-:_"'~'°' T~lBNTS I 1 __

220 KV YARD !300x110)

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l

SPACE PROVISION FOR ' MAltfi. SAY 'o0x30

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104

16 .

SUB-STATION MANUAL LOW LEVEL TYPE . BREAKER AND HALF BUS ARRANGEMENT 420KV /245KV BIL 1425KV/1050KV ·.

;

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SUS-STATION MANUAL LOW LEVEL TYPE BREAKER AND 11Alf · BUS ARRANGEl1ElllT .

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STAGE-I. STAGE-I! .·

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flGURE 8 D (SHEET 1 OF 6) K

K

MANUAL ON· SUBSTATIONS (LAYOUT &DESIGN) SLD FOR BREAKER AND HALF SCHEME.

400/220KV SUBSTATION SINGLE LINE DIAGRAM .

-

400/220 KV SYSTEM 1--------------------------iL

L

1

2

•

6

6

7

8

9

10

11

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13

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MJ. DIMENSIONS t.RE IN IM.UMEmE UNl.!SS OlHERVltSE' Sf'EQFlEO, lH£ P.ARAM£!£FS F(Wl: Mli'Ctt 1'}1£ SY'S'l'iU 1$ OEPEN~T roR Mi;: :"1) S'tSTEll VOl..tAGE{A'MS) ·~v b) UCMtN!NC IUPVlSG M'JNSt#IHC> VOlTAC&(XW) - 1425 c) S-1'.cHNC: IMPt1l5t MDtSTAHD mTA«Qr\'P} - 1050 ~} POWER ffl£Ql1£HC'f lttTHSTAND VOLTAGE(RMS) - eJO} PHASE TO EMm - (IN Mll) ~ o} SECWQNAt. ~ - (IM MM) d} CROON() ~ - ~M{MINIMl/M) 8000

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ALL DIMENSIONS ARE IN MM. UNLESS OTHERWISE SPECIFIED

2- MINIMUM CLEARANCES: A

A

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4000MM.

BETWEEN PHASE TO EARTH 3500MM SECTONAL CLEARENCE 6500MM VERTICAL DISTANCE BETWEEN LOWEST 2550MM PART OF THE INSULATOR AND PLINTH LEVEL

3- THE PARAMETERS FOR WHICH THE SY?TEM IS DESIGNED ARE:

a) SYSTEM VOLTAGE 420kV (RMS)

400KV

b) UGHTN!NG IMPULSE WITHSTAND VOLTAGE : ±1550kVP

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B

B

4- LINE TRAP POSITIONS SHOWN IN THE LAYOUT ARE INDICATIVE ONLY, FINAL LOCA TlON Will BE DECIOED BASED ON PLCC REQUIREMENT.

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D

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SECTION AT Y'·Y' (TRANSFORMER BAY}

1. REP1.ACE lHE SECTIOtf'{.y Ytmi SECTION Y'·Y'

WHEN AH ISOIAlORlS BE PRGvlosl> 8ElWEEH lMe lPANSFORMER AHO CIR¢UIT BRl!Al
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2. EQUIPMENT BUS, WllN BUS, T~sreR

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ANO .IACIC BUS Htl
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·-· .....MANUAL ot4susst..\r10Ns (LAYOUT & DESIGN) 1~2133

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NOTES~1. Al.L OIMENSIONS ARE IN mm ONLESS OTEHRWISE SPECIFlEO.

2. EOLAPMENT SUS. MAIN BUS, TlWISFER BUS AND JACK BUS HEIGHT ARE FROM TOP OF PLINTH.

FIGURE 19 A {SHEET 4 OF 4}

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43 N; 37 E'

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CONDUCTOR

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MANUAL ON SUB STATIONS LAYOUT & DESIGN 2

3

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