Trainee Report 2010

8/9/2019 Trainee Report 2010

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1. INTRODUCTION-THE NORTHERNREGION POWER SYSTEM

1.1 Background

India has been divided into five Electricity Boards viz., southern,

northern, western, eastern and north-eastern for the purpose of power

system planning and operation.

The Northern Regional Grid is composed of the generation, transmission

and distribution facilities of the following State Electricity Boards and

other national/regional agencies:

Himachal Pradesh Electricity Board (HPSEB)

Haryana Vidyut Prasan Nigam Limited (HVPNL)


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Haryana Vidyut Prasan Nigam Limited (HVPNL)


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Kashmir, Bhakra Beas Management board, Delhi Electric Supply

Undertaking and Central Sector.

Central power stations are regional in character and meant for the

benefit of all the States of the Region. Presently, power from a

Central Power Station is allocated to the various Constituents in

accordance with the following general agreed formula for sharing

of power:

1. 15% power is kept unallocated at the disposal of

Government of India to meet the urgent requirement of the

individual beneficiary States from time to time.

2. 10% of the power is kept allocated to the State in which the

power station is located.

3. The remaining 75% power is distributed amongst the

beneficiary States (including the home State) in

accordance with the energy consumption of these States

and the Central Plan Assistance to them


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GOI agreed with a three-phase development for Powergrid.

During phase 1, CEA would continue to operate the existing

RSCCs (Regional Systems Control Centres), while Powergrid

takes over transmission facilities from NTPC, NHPC, etc. and

undertakes projects to develop new RSCCs. Then Powergrid

would own and operate the project facilities and take over related

existing facilities from CEA not later than at the completion of the

project marking the commencement of phase 2, viz.

establishment/ augmentation of load dispatch and communication

facilities in various Regions. During phase 1, Powergrid will need

immediate access to and use of the existing control facilities at

the Regional level (present RSCC), co-operation with the various

constituents of REBs and CEA, to facilitate improved operation of

its transmission system, to help ensure a smooth transfer of old

system operational functions from CEA to Powergrid and to

facilitate the implementation of the new RSCC.


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2. CURRENT INSTITUTIONAL ANDOPERATIONAL PROBLEMS IN THENORTHERN REGION2.1 Current institutional arrangements

The task of regional grid management is vested with the NREB and they

have to co-ordinate the operation of autonomous Central and State

sector organizations in the Region. Under this set up the NREB has to

derive their power from the constituents. Lack of proper communication

and real time load dispatch facilities is the biggest constraint in effective

operation and control of the grid The NREB as association of the


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2.2 Operational guidelines and discipline

2.2.1 Operational discipline

It is necessary to have proper agreements spelling out the

operations regimes, obligation of suppliers as well as the

beneficially States in terms of maintaining the system parameters,

reliability criteria, penalties for violation of agreed operating

regimes, etc.

The operating norms should cover not only the normal state of

operation of the power system but also the alert, emergency and

restorative states.

At present there are no means to enforce the operational

discipline. In case of overdraws of power by any State, the

Regional Load Despatch Centre (RSCC) can onl req est the


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2.2.2 Frequency maintenance problems

The grid management problems of the country are compounded

by continuing power shortages in the different systems. While the

demand for power has been increasing at a rapid pace the

generation availability has not been keeping pace with it. The

short fall in availability is due to delays in commissioning for

generating units, lack of funds for construction, problems in

quality of coal and equipments, high level of forced outages, etc.

In most power systems in the world, the system frequency is kept

virtually constant and a combination of generator governors and

automatic generation control systems constantly control the

generators so that:

The total generation is kept equal to the total load and,

Generators are operated at the levels at which the total cost of the

power generated is at the minimum consistent with safe system

ti


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either case is that the SEB that fails to shed load as agreed

receives more energy than it is entitled to, and the other receives

less.

During light load periods, those SEBs that should back down on

their more expensive units fail to do so. The result is that central

units with lower production cost must be back down instead,

resulting in uneconomical operation of the regional system. In

some cases, hydro units with full reservoir are required to back

down their output resulting in wasteful spilling of water over the

dense.

2.2.3 Lack of flexibility in generation scheduling at present the

energy invoicing is based on a single tariff system with

regards to the actual energy transfers metered under tie-

lines.


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2.3 Deficiencies in power transmission system

2.3.1 Power transmission lines and sub stations

The transmission system is being planned on a regional basis and

optimized without regard to ownership under the responsibility of

CEA. The establishment of central sector power plants hasincreased the complexity of the regional network by super

imposing a transmission system to the transmission system of the

SEBs.

With a view to optimizing investment, the regional transmissionsystems have been developed on the assumptions that the

shares of some state located far away from the central stations

would be delivered on the principles of net inter states exchanges

where ever feasible without affecting the reliability and security of

the transmission system.


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networks are very low voltage level at receiving end at the peak,

power swings involving cascade tripping and /or systems

isolations and collapses, massive loss of generation, voltage

collapses, partial and sometimes total power supply failure. One

of the numerous regions for these mishaps is due to the particular

weakness of the 400kv network and its long radial structure that

should be strengthened and reinforced by more intermediate

step-down substations.

2.3.2 Compensation means

Reactive power management has not received the attention it

deserves. Bulk of the present reactive power is being supplied by

the generating plants thereby resulting in large flows of reactive

power all over the transmission and distribution networks towards

the load points from the generating units that are most of them

l t d f f th l d Th l lt l l


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3. OPERATIONAL AND CONTROLPHILOSOPHY

3.1 Basic operational and functional requirements


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During the operation planning stage, the basic tasks to be carried out

are:

State wise generation scheduling and load prediction for a

complete day, week, month and year

Determining of the share of each State in Centrally owned

generation on given day

Scheduling of inter-State and inter-Regional exchanges for

a given day

Updating maintenance schedule for generators,

transformers, transmission and/or distribution lines

Spinning reserve assistance

Co-ordination with National Load Dispatch Centre in the

future

Collection of data regarding weather forecasts

Analysis of system performance under disturbances and

devising remedial actions to minimize their effects


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It is clear that operation of such a large system requires one to set up a

control hierarchy, which will also match the power system organization in

the Region. With this end in mind, a 3-tier hierarchical network has

already been defined , complying with the load dispatch facilities policy

established by Central Electricity Authority (CEA) for all India.

The following load dispatch centers are proposed to be implemented at

the different hierarchical levels:

Hierarchy level 1:

Regional System Control Centre at Delhi covering the region power

systems of Himachal Pradesh, Haryana, Jammu and Kashmir, Punjab,

Rajasthan, Uttar Pradesh, BBMB, DESU, Chandigarh.

Hierarchy level 2:

Comprising State Load Dispatch Centres (SLDCs) and Central Project

Control Centres as below:

SLDC f Hi h l P d h t Shi l


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Sub-load Dispatch Centres (Sub-LDCs) as below:

Sub LDCs at Kunihar and Hamirpur controlled by SLDC at Shimla

(Jutogh)

Sub LDCs at Dadri, Panipat TPS and Narwana controlled by

SLDC at Panipat;

Sub LDCs at Pampore and Udampur controlled by SLDC at

Udampur (NB: Udhampur Sub LDC is located in the same control

room as the SLDC);

Sub LDCs at Jallandhar, Lalton Kalan and Patiala controlled by

SLDC at Patiala.

Sub-LDCs at Ratangarh, Kota, Bhilwara and Heerapura controlled

by SLDC at Heerapura.

Sub-LDCs at Rishikesh, Moradabad, Panki, Varanasi and

Sultanpur controlled by SLDC Lucknow.

3.3 Functions of the Control Centres and sharing out of

ibiliti


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The RSCC shall be responsible for the following:

Data acquisition and monitoring of all the transmission system at 220

kV and above, plus the 132 kV interstate lines and all the generating

stations of 50 MW and above.

Supervisory control of the power system operation pertaining to inter-

State/ Regional grid and control of central sector sub-station under its

direct jurisdiction.

Management and supervisory control of the centrally owned

generating unit. Load frequency control for the entire region and

sending corrective area control error messages to all the

constituents.

Monitoring inter-state exchanges of power with references to

schedule and AGC orders.


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Generation load management according to economic generation

Optimization carried out at state level and according to RSCC

request for inter-state power transfers and frequency regulation.

Transmission of orders directly to state owned power stations from

the state requirements.

Voltage and reactive power control.

3.6 Responsibilities of the Sub-LDCs

The Sub-LDCs will be responsible of the following:

Switching of equipments at 220 and 400 kV as per direction SLDC

V lt d ti t l ith i th i f ibilit


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4.2 Data Transmission Principles

The circuit breakers positions are collected under the shape of

double signals (DS) as this is necessary for remote control functions,

also these are more reliable.

The isolators positions are given single signal as these are not

needed for remote control.

For all apparatus positions, the information will be transmitted

when change of status occurs.

All possible alarms are collected under single signals.

4.3 Principles for Data Acquisition

4 3 1 B b ti


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33 kV: no value.

c) SS:

1 SS for loss of voltage per busbar.

4.3.2 Busbar coupler and bus section breaker

DS: 1 DS per circuit breaker.

SS: 1 SS for only one out of the 2 disconnectors.

4.3.3 Bus transfer

DS: 1 DS per circuit breaker.

SS: 1 SS for each disconnector on both sides of the C.B.

4.3.4Busbar disconnector


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1 SS for each bus selector disconnector in case of

single breaker arrangement.

1 SS for each disconnector in case of one-hand-half

breaker arrangement.

4.3.7 Gas generator and Hydroelectric Generator (substation

side)a) Active power:1 value.

b) Reactive power:1 value.

c) DS:

- 1 DS per substation circuit-breaker

- 1 DS per generator bus coupler

d) SS:

- 1 SS for each bus selector disconnector in case of

single breaker arrangement.

- 1 SS for each disconnector in the case of one-and-half

breaker arrangement.


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substation are to be described as overhead line connections and

remote generators as follows:

- 1 DS per circuit-breaker(if existing for outgoing feeder),

- 1 DS per generator bus coupler,

- one value of P for gross active output of a thermal

generator,

- one value of Q for gross reactive output of a thermal

generator.

4.3.10Overhead line

a) Active power and reactive power

- 400, 220 and 132 kV: one value of P and Q for each

outgoing line .

- 66 kV as a secondary part of Regional interest

substation: one value of P and Q only for outgoing inter-

system tie-line.

33 kV l


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- 1 SS for each by-pass disconnector in case of single

breaker+by-pass arrangnment

d) DC

- 1 DC for each 132 kV outgoing line.

The choice consisting in the implementation of remote control

only for 132kv feeders and below can be justified by the needs of

quick switching operation requirements for load shedding and

emergency action.

In some particular cases, some remote control facilities may be

interesting also for 220 kV or 400 kV components of the grid.

These specific requirements shall be precisely defined at

technical specification drafting.

4.3.11 Transformers


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whenever the load supplied by the transformers is

significant.

c) OLTC

The position of each On Load Tap Changer is indicated

with a digital or analog tele measuring. This shall be

specified for each individual case at specification drafting.

d) DS:

1 DS per circuit breaker. If the secondary level doesnt

belong to same network, 1 DS shall also be collected for

the secondary circuit breaker.

e) S S:

1 SS for each bus selector disconnector in

case of single breaker arrangement.


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Magnetic tape storage devices or equivalent

equipment,

Failover system,

Line printer,

Software package,

One time & frequency system,

One receiver for time synchronization signals.

Man machine interface

Control room:

Two dispatcher consoles with two VDUs each, Two hard copy units linked to any console,

Two loggers and one plotter,

One line printer,

One frequency recorder,


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Reduced equivalent network,

Logical controls,

State estimation,

Contingency analysis,

Load flow,

LFC,

One local RTU.

5.2 SLDCs scope of supply

Two categories of SLDCs have been considered in the northern region,

depending on the size of the constituent:

1st category (large sized SLDC): Lucknow, Heerapura.

2nd category (standred sized SLDC): Shimla, Panipat,


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One time and frequency system,

One receiver for time synchronization signals.

Man Machine Interface

Control Room:

Dispatcher consoles:

- For SLDCs: 2 dispatcher consoles each with two VDUs,

- For large mixed SLDC/sub-LDC: 3 dispatcher consoles

each with two VDUs.

Two hard copy units linked to any console,

Two loggers and one plotter,

One line printer,

One frequency recorder,

One mimic board along with its driver,


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Network topology,

Reduced equivalent network,

Logical controls,

State estimation,

Contingency analysis,

Load flow, LFC.

Option two for EMS:

One computer,

At least two disk storage units with controllers,

One streamer or magnetic tape storage device,

One line printer,

Two programming terminals,

One software package.


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failover system,

line printer,

software pakage:

one time and frequency system,

one receiver for time synchronization signals

-Main Machine interface

-Control Room:

3 PC workstations,

two hard copy units linked to any console,

two loggers,

one line printer ,

one plotter,

one frequency recorder,

one mimic board along with its driver,

one audible alarm.

-computer section:


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These are :

RTU(substation level )

Sub-LDC, 3rd tier

SLDC or CPCC, 2nd tier

RSCC, 1st tier.

All the state owned RTUs are only linked to Sub-LDCs. Thus a data

communication protocol and procedure shall be provided for this first

layer.

The data transferred on these links are:

Either real-time data

Or files

Or data related to remote logging procedures.

In order to enable all these data transfers between computers, it is

mandatory to have in each control center a communication software

which implements the seven layer of Open System Interconnection(OSI)

ISO Recommendation.

The OSImodel in seven layers is the following one:


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for acquisition,processing, transmission and display of the necessary

process information. The performance of a telecontrol system is

determind basically by:

The data integrity of information transfer, from a source to its

destination , and ,

The speed with which information is transferred to its

destination.

Since telecontrol systems have to operate in real-time mode, limitations

imposed by the telecommunication channels may heavily impair the

overall system efficiency.The implicatin is restricted bandwidth and

hence restricted bit rates to be transmitted under noisy environment

conditions, which cause distortion of transmitted signals elements. The

data transmission system has to be considered in the sense as an

integrated part of the telecontrol system.

Basic requirements of the data transmission system

Data transmission should fulfill the following requirements:High data


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required.The data link protocol accepts and transmits arbitrary bit

sequence structures from the data source.

Transmission software and protocol specifications

Transmission software arrangment

For standardization reasons and easy future upgrading of the Data

Transmission Network(DTN) to packet switching, communication

software is based over the latest ISO(CCITT) standards in force

implementing the ISOs OSI model.This subdivision into modular layers

is a useful theoretical model for difining standards. Each layer is

essentially independent of the layers below and above it. It treats the

layer below as a service function and the layer above as a master

with witch it exchanges data and to which it reports errors.

The independent of the layers gives a modularity to the system. It

ispossible to alter one layer without altering others, in the some layers

may be omitted.Telecontrol system functions will be divided into the


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The protocol to be used for RTU-sub-LDC links and for direct RTU-

RSCC links will be one of the following by order of decreasing

preferences:

- X.25(up to layer 2), -IEC 870-5-1, -Manufactrurs specific.If one of

the first 2 solutions is proposed, it must not induce additional cost with

respect to the manufcturers specific solutions.

The protocol to be used for inter LDClinks will be the X.25 with the

option and particulars alredy applied by department of science and

technology in consulation with CEA.

5.7. Physical structure of the protocol system

5.7.1. General

The structure of the data communication network which is thus a

sub-set of the telecommunication system is mainly determined by

the operational philosophy, i.e.:

National Control Centre,

Regional Control Centre,


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Transmission link redundancyIn order to maintain a high quality of

service with strategic sites, the physical communication links

arriving on the latter will be duplicated. This will be the case

atleast for:

The links arriving on 400/200kv substation and power station

RTUs,

All the links interconnecting contral centers.

5.8. Transmission modes

5.8.1. Transmission initiation modes

In the case if RTU/sub-LDC links, two basic transmission initiating

modes will be used for telecontrol data transmission:

Event initiated transmission(spontaneous transmission, also

called master-master),

Transmission on demand(interrogative or polling mode, also

called master-slave).


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For sub-LDC/SLDC links:1200 Bds(1200 bits/s), FSK, CCITT V-

23, 4-wire.

For higher hierarchical rank inter-computer links:4800 Bds(4800

bits/s), phase modulation, CCITT V.29.

For RTUs:

All RTUs would be configured to work at 200 bauds on FSK

channels located above the 300 to 2.4 kHz speech sub-bands of

4 kHz VFTs.

5.10. Modems

5.10.1. Basic requirement of RTUs modems

Frequency shift channel modems are to be used to convert a

binary signal into two distinct frecuencies.The rack modem of

RTU will contain 2 single-card modem boards.The modem will

accept CCITT V.24 serial signals and communicates at the

standardized data rates from 50 to 1200 bauds.


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Sequential Event recording :

TTY will be provided only at 400kv, 220kv substation and power

station sites.

5.11.2. Charateristics of RTU I/O circuits

RTU will be capable of accepting :Single point information

indication signals, double point information indication signals,

telemetering signals, under the form of potential free contacts.

RTU will be capable of issuing:Single point digital controls,

Double point digital controls,

Under the form of potential free contacts .

RTU basic functional processing requirements

The RTU will be capable of time-tagging the status changes

with a 10ms resolution for transmission to the control centre as

well as local editing on a TTY terminal(sequential event

recording)RTUs bills of quantitiesAn RTU will equip each side

that will be under supervisory. For power station and the control


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efficient, reliable and modern communication system for the Power

authorities. Keeping in view the specific and the Government of India has

recommended an independent Dedicated communication system to be

owned and operated by the Power Utilities up to the State Load

DESPATCH CENTRE level from remote power stations and substations .

As recommended by the Working Group and the Secretariess Steering

Committee, the Government of India decided to appoint a Consultant of

repute for the planning of a comprehensive communication systems for

the Power Sector .

Merz & Mac Lellan (MML) , U.K. , in association with Bharat Electronics

Ltd.(India) working as Consltants to the Central Electricity Authority have

submitted , among other reports, a detailed Project Report for

Telecommunication system of Northern Region including all Constituents

and have recommended for wide-ranging strengthening of

Telecommunication network and requisite organization structure. These

reports have been prepared with active participation of Engineers from

CEA/NREB/SEBs.Electricite de France International(EDF), Consultant for


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The telecommunication part of the project will cater for the requirements of

the load dispatch computerized scheme in respect of the following

:Speech and data transmission for system operation and control,

Transmission of operational data for generation of reports and statistical

information.

The hierarchy of communication network will start from Remote Terminal

Units at remote substations/power stations participating significantly in the

intrigrated operation of the Northern grid and terminate at Sub Load

dispatch centers .

The communication system will support the following applications

Speech communication on express /dialing basis ,

Data transmission

Teleprinting

Facsimile transmission.

6.2.1. Structure of the switched PABX network

The switched PABX network is designed to provide voice

communication .


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channel required to protect a line or to transmit a control single is a vital

part of the total system .The consultants have recommended generally

and independent telecommunication network owned and operated by

power utilities .Howerever , DOT lines are proposed from SLDCs

/CPCCs to RLDCs and sub LDCs to SLDCs for back up speech and

data circuits .

Planning Philosophy

For communication between RTUs and sub-LDC , PLCC has been

recommended by the constants , as their requirement is generally not

more than 4 channels which can be accommodated by PLCC .A 200

baud channel , required for RTU communication , can readily be

accommodated above the 300 Hz to 2.4 KHz speech band in a 4 KHz

wide PLC channel . The speed of composite data transmission beyond

sub-LDC is about 1200 baud . This requirment can not be met by PLCC

alone and multichannel system /leased DOT channels have been

recommended by the MML consultants

General


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The HIMACHAL PRADESH proposed communication will comprise:1

radio link with 2 radio repeater stations1 fiber optic link without repeater

station17 Nos of PLC links No DOT leased circuit.

HARYANA Communication system

The HARYANA proposed communication system will comprise :

7 radio links with 3 radio repeater stations1 fiber optic link without

repeater station (in total 15 Kms)

32 Nos of PLC links

No DOT leased circuit.

JAMMU & KASHMIR Communication system

The JAMMU & KASHMIR proposed communication system will

comprise:

No radio link

2 fiber optic links without repeater stations

25 Nos of PLC links

No DOT leased circuits


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1400 Kms of leased DOT circuits

Central sector communication system

The central sector communication system will comprise :

16 radio links with 6 radio repeater stations

5 fiber links with 6 repeater stations

79 Nos of PLC links

4005 Kms of leased DOT circuits .

Merits of the network

The merits of communication system so designed are as follows :

The major portion of the network is owned by the Power Sector.leased

DOT circuits have also been envisaged to support the dedicated

communication networkthe system caters for the present requirements

of administrative and operational speech channels with provision for

future growth .Since future expansion is likely to be along the radio /fiber

optic routes, it can be operated at very low cost if tower heights are

adequate, all the towers and parabolic antennas of the existing analogue

microwave back-bone in UTTAR PRADESH will be re-used for the new


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Power supplies for supply of :New RTU an interface cubicle , new

communication equipment , Data processing equipment in the various

control centers,Airconditioning and security lighting in Control Centres .

They are one of thefollowing types:

Uninterruptible DC source (or DC power system)

Uninterruptible AC source

Standby power supply.

In the scope of this project , it was generally decided by Powergrid and the

constituents that the DC power supply in the sub stations will not be

included.Thus , only the AC and DC power supplies for the sub-LDCs ,

CPCCs, SLDCs and RLCC will be considered .

7.2. AC auxiliary power supplies in Control Centres

7.2.1. Makingup of 415/240V AC uninterruptible power

supply in Control Centres

Two 415V, 3 phase AC supply together with an emergency diesel

generator will ensure a secure supply to the essential services


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A control center 48V DC power supply system will comprise in fact

two traditional 48V DC system chains , each including:2 rectifiers

simulteneusly operating in parallel ,

1 lead-acid stationary type battery ,

1 distribution board,

An inter-connection between the 48V DC power supply system

distribution boards which will be left normally opened under normal

operating conditions.7.3.2. Sizing the 48V DC system in Control

Centre

The minimum sizing for each DC system chain will be one 800Ah

battery and two 160A rectifires .

7.4. 48V DC system in sub-station

7.4.1. General

Communication and telecontrol means of sub-stations are power

supplied under a mean voltage of 48V DC with possible link of the

positive polarity end to the earth.For this purpose, we must have

DC systems suited to the new equipment.


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7.4.3. 48V DC system sizing and BOQs in sub-stations

Adequately sized batteries and rectifires will be provided by some

SEBs/boards/central Sectors themselves as a part of the sub-

station power/plant components.


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8.1 General

As a matter of the fact , once a utilitys network has reached a certain levelof development a modern control system becomes and absolute necessity,

and the question of its profitability is almost secondary .However , even

though a precise economic analysis is not possible , in view of the systems

nature , it is usual practice to evaluate such a project by advantages that it

offers to the utility .These advantages fall into the following two categories:

Economically quantifiable benefits Intangible benefits

8.2 Economically quantifiable benefits

The economically quantifiable benefits may be classified into four main

categories:

Improvement of system reliability and reduction of undelivered energy.

Saving in operating costs.

Capital investment savings.

Reduction of personnel costs.

These benefits have been evaluated on the basis of field data related to

disturbances and on some figures recommended by international


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halved. Assuming that a general collapes lasts one hour , in

1995:Avoidance of one tripping during one hour :

E=110841 MkWh/8760*1= 12.65 MkWh

Reduction of restoration time:

110841 MkWh / 8760 * 0.5 = 6.33 MkWh

i.e.: 19 MkWh /year.

Assuming that the cost of undelivered energy is 20 times the cost of

generation which is also a standard value and that the cost of generation in

Northern Region is Rs 12 lakhs / MkWh, then theyearly benefit in this area

expected from the control scheme is :

19 * 12 * 20 = Rs 4560 lakhs per year

i.e. Rs 45.6 Crores per year.

Operating costs savings

The reduction of operation costs is mainly expected from a reduction

in fuel expenditures

The control schemes enables a reduction of fuel outlays for three


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power storage for the Northern grid , these savings are quite real in so far

as there is a correlation between the energy saved and the additional

capacity installed to supply this lost energy .

It may be anticipated that 0.35 % of additional installed capacity could be

saved for an equivalent quality of service if 0.7% of energy is saved by the

implementation of the control scheme .With a 12, 258 MW additional

installed capacity planned for 1995 , the saving is 43 MW.

Assuming a hydro-thermal mix of 35/65 in installed capacity and Rs 3.5

crores /MW of hydel capacity and Rs 3crores /MW of thermal capacity , the

capital investmentSaving for generation facilities is :

43 * 0.35 * 3.5 + 43 * 0.65 * 3 = Rs 137 Crores

Reduction of personnel costs

The following considerations are also valid.

A measure benefit due to SCADA is the increased effectiveness of theLoad

Despatch personnel which can be achieved .Load dispatch personnel spend

an inordinate amount of time on paper work . Automated logging and

reporting software can drastically reduced this tedious tasks.


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influence in optimizing the hydro operation . It is important if the amount of

the water for power generation is less than volume available in an average

year .

Quick adoption of new operating philosophips according to the development

of the power system requires flexibility , which can be reached in a Control

Centre .Improved Reliability Procedures

It is normal practice to switch capacitors , reactors and cables at different

times during the day for voltage control purposes. Circuit breakers in the

transmission network may be opened or closed to limit short circuit levels .

Improved Operator Training

Operator training simulators are available today . The opening / closing of

breakers , tap changing of transformers , etc. can be simulated without

affecting the status /security of the actual power system . Network analysis

training will also guarantee higher level of understanding the features of a

power network .

Organization Improvent

Establishment of a control centre means that during the implementation


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Governments are concerned about security problems during blackouts .

Police force and damage costs due to social unrest can be high . Loss of

faith in the ability of the country to handle social problems can be even

higher ;Governments are concerned about their image . Blackouts and

unreliable electric supply are embarrassing.Most of these considerations

apply in the case of the control scheme for the Northern Regional grid.


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Capital investments savings :

Generation facilities : Rs. 137 Crores.

Transmission facilities : Rs. 21 Crores.

With a 447 Crores Project would be paid off in :

( 447 158) / 137.7 = 2.1 years

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Trainee Report 2010

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