northern regional load dispatch center -...

Power Grid Corporation Of India Ltd.

Welcomes

Delegates

fromfrom

South Asia & USEA

To

Northern Regional Load Dispatch CenterNew DelhiNew Delhi

Presentation OutlinePresentation Outline• Overview of Indian Power System• Grid Operation• Grid Operation• Power System In Extremes• Indian Electricity MarketIndian Electricity Market

– Availability Based Tariff (ABT) & Unscheduled Interchange (UI)Sh T O A (STOA)– Short Term Open Access (STOA)

– Metering and Settlement System

• International Interconnections• International Interconnections• IEGC

19-July-2007 POWERGRID - NRLDC 2

Overview of Indian Power Systemy

Spatial Distribution

Of Load

Source:

Powerline

(Siemens


(Siemens Ad),

Oct-2006

Energy Resource Map Of India

Jammu

Hydro• Hydro potential in North

east and upper part of

NRPartabpur

RAPP

SIKKIMNEPAL

BHUTANDelhi

Guwahati

Ludhiana

J i

east and upper part ofNorthern Region

• Coal reserves mainly in

WR

ERNER

Talcher/Ib Valley

Vindhyachal

Korba

RAPP

MYA

NMM

AR

CHICKEN NECK

DESHBANGLA

Pipavav

Kolkata

PatnaLucknow

Bhopal

GuwahatiJaipur

Gandhinagar

Indore

Eastern Region

• Distribution of energy resources and consumption

SR

LEGEND

Coal

VizagSimhadri

Kaiga

Tarapur

Krishnapatnam

Generation Load-Centre

Bhubaneswar

Mumbai

Raipur

Hyderabad

Coalresources and consumption centres are extremely unbalanced

Ennore

KudankulamKayamkulam

Hydro

Lignite

Coastal

Nuclear

Kaiga

Mangalore

p

Cuddalore

South MadrasChennai

Bangalore

Thiruvananthapuram

Kozhikode • Necessitate power transfer over long distances


NuclearSRI LANKA

COLOMBO

680 720 760 880 920 960800 84 082.5 0

J&KDi it J&K

HPPUNJAB

HARIANA

Diversity

• Time NN

EE

NE

B’DESH

NEPAL BHUTANHARIANA

RAJASTHAN UP BIHARASSAM

MNPMIZTRP

NG

MEMYANMAR

SKMDELHI

NER NER • Time

• Generation Resources

W W DESH-MP

ORISSA

WBL

GUJARAT

MAHARASHTRA

MIZTRP

DIUDAMAN

JKND

CTGR

Resources

• Load Centers

L H l f S S

KARNATAKAAP

A&N

PONDICHERYGOA

• Long Haulage of Power

• WeatherTAMILNADULAKSHADWEEP

A&N• Weather

• Seasons


SRI

LANKA

Indian Scenario: Regional GridsIndian Scenario: Regional GridsInter regional Link

MW capacityTwo synchronous systems-North-Central (New) Grid

30,500 MW

NER-ER 1,240

ER-NR 4,220

( )& Southern Grid

36,437 MW

16,00039,749 MW

ER-SR 3,120

ER-WR 1,76017,159 MW

2,506 MW

39,749 MW

SR-WR 1,680

WR-NR 2,080

38,144 MWTotal as on date

14,100

T t f 37 700

Installed Generation CapacityCurrent : 134,077 MWT t f Y 2012 200 000 MW


Target for 2012

37,700Target for Year 2012 : 200,000 MW

Figures as on 31-May-2007

EHV Infrastructure (as on 31st May 2007)

TRANSMISSION

OWNERSHIP TOTAL

(as on 31st May 2007)

SION VOLTAGE

CENTRAL STATE

Circuit Kilometer

765 kV charged at 400 kV

1863 409 2272

400 kV 52786 24998 77784400 kV 52786 24998 77784

220 kV 9466 105970 115436

+ 500 kVHVDC

4368 1504 5872

T l 68483 132881 201364


Total 68483 132881 201364

‘ELECTRICAL’

REGIONS

NORTHERN REGION

NORTH-EASTERN REGION

1

WESTERNREGION

EASTERN REGION

2SOUTHERN REGION

2

WITH THE COMMISSIONING OF THE TALA PROJECT CONNECTING THE EASTERN AND NORTHERN GRIDS, INDIA NOW HAS ONLY TWO GRIDS

Peculiarities of Regional Grids in India

REGIONAL GRIDS

Deficit Region

Snow fed – run-of –the –river hydro

Highly weather sensitive load

NORTHERN REGION NORTH

GRIDS g y

Adverse weather conditions: Fog & Dust Storm

Very low load

CHICKEN-NECK

WESTERNREGION

EASTERN REGION

REGION NORTH-EASTERN REGION High hydro potential

Evacuation problems

Low load

SOUTHERN REGION

REGION Low load

High coal reserves

Pit head base load plants

Industrial load

High load


Monsoon dependent hydro

765 KV400 KV400 KV500 KV HVDC


Typical Load CurveAll I diAll India (Oct-2006)


Grid Operationp

HIERARCHY OF GRID MANAGEMENTMANAGEMENT

National Level

Regional LevelRegional Level

State Utilities Level

INTER STATE GRID

CS - 1 IPPCS - 2

Regional GridRLDCCoordinates

Trader

State - A State - C

Control Areas CS: Central SectorState - B

INTRA STATE GRID

STATE IPP

CENTRALSTATE GENR.IPP SHAREGENR.

SEB’s GridSLDCCoordinatesDirects

Discom - A Discom - C

Discom - BConsumer

Information Flow hierarchyNLDCNational

LevelUnified Load Despatch & data

y

RLDC5 Nos.Region Level

Despatch & data acquisition

SLDC23 Nos.

State HQ Level

SUB LDC51

Group of District Level

RTU

Nos.

1160 Nos.Plant/Sub

Station Level


Level

REAL TIME GRID OPERATION

REAL TIME OPERATION

I di El t i it A t

IEGC ABT

• REAL TIME OPERATION STANDS ON TWO FIRM FOOTINGSIEGC THE INDIAN ELECTRICITY GRID CODE

Indian Electricity Act


– IEGC – THE INDIAN ELECTRICITY GRID CODE– ABT – AVAILABILITY BASED TARIFF

GRID OPERATION:A TIGHT ROPE WALKA TIGHT ROPE WALK


DELHI LOAD VARIATION LAST WINTERCOLOUR CODE

High demandHigh demand

Z AXISZ-AXIS:

DEMAND MET

IN MWMorning k

Y-AXIS:

DATES IN JAN 05

Lo demand

peak

Day off peak

Evening peak

X-AXIS: TIME IN 5 MIN BLOCKS

Low demand

Night off peak


Severe morning peak is due to heating load

Operation Of Very Large P G idPower Grid

• “Large grid” comprising of NER ERLarge grid comprising of NER, ER, WR & NR

• Over 250 power stations• Over 250 power stations

• Total installed generation capacity of 88 000 MW88,000 MW

• Operating size of 60,000 MW

• Cover 80% of the country’s area

• Cater to 78 % of country’s population


Cater to 78 % of country s population

Challenges of interconnectionChallenges of interconnection

“…one can export bl ll“there is a vast trouble as well as

help. In fact, it is only by sharing the troubles that

there is a vast amount of information to be gathered and

h d d d the troubles that help is possible…”

comprehended, and a diversity of operating practices that must be coordinated and made compatible…”

Charles Concordia


Charles Concordia1908-2003

Utilization of Time DiversityUtilization of Time DiversityReversal of Flow

On AC InterconnectorOn AC Interconnector Between

North & Central GridsDuring Evening Peak

NORTH-EASTERN REGION

Ch i Fl

WESTERNREGION

REGION

EASTERN REGION

AT 1830 HRS

600 MW

Changing FlowBetween Eastern

And WesternRegions During

NORTH-EASTERN REGION1200 MW


Regions During Peak Hours

WESTERNREGION

EASTERN REGION

AT 2000 HRS

Optimal Utilization of Resources

22000

3480037752

31000

25000

30000

35000

40000

Growth In

p

814510850

13000

5000

10000

15000

20000

25000 Growth In Inter Regional Exchanges

(MUs)

0

5000

00-01 01-02 02-03 03-04 04-05 05-06 06-07

100

707580859095

100

Increased PLF

5055606570

'01-02 '02-03 '03-04 '04-05 '05-06 '06-07


01 02 02 03 03 04 04 05 05 06 06 07

Central Sector All India

InitiativesInitiatives• Stakeholder sensitization

– Operator training, Agenda in Regional Power Committee meetings

N i li ti t l d l d & h d ith SLDC• New visualization tools developed & shared with SLDCs– Geographical maps– Zones & flow-gates diagram

Power flow on major flow gates– Power flow on major flow gates– Angular separation

• Developed logistics for instant information dissemination– Website – www nrldc org– Website – www.nrldc.org– Short Messaging Service (SMS)– Flasher on NRLDC website homepage

• Night shift reinforcementNight shift reinforcement – Regular Duty Roster – 12 to 15 additional executives from Grid Management, SCADA/IT,

Technical Services, Commercial & Human Resource on SOS call


Situational AwarenessSituational Awareness

• Situational awareness– A mental model of our operating environment and our place

in it

– Consists of four processesConsists of four processes• Perception

• Comprehension

• Projection• Projection

• Prediction


Courtesy: PJM

System Security & StabilitySystem Security & Stability

• Decentralized Operation & Controlp• Unity of Command

– Regional Load Despatch apex body at the regional level

– State Load Despatch Centre apex body in the state

• Relay Coordination at Regional level– Under frequency, df/dt relays, under voltage relays

• Parallel operation of Long HVDC & EHV AC systemU f D i C ti FACTS SVC


• Use of Dynamic Compensation: FACTS, SVC

System Security & StabilitySystem Security & Stability

• Frequency Controller on HVDC Back to BackFrequency Controller on HVDC Back to Back

• Using Advanced tools of System Visualization– SCADA, EMS, Unified Network DatabaseSCADA, EMS, Unified Network Database

• Real-time Balancing by operator complemented byp y– Frequency linked Pricing for Active Power

imbalance

– Voltage linked Pricing for Reactive Power imbalance


Reliability of SupplyReliability of Supply

• Ensuring network adequacy at the EHV levelg q y– Maintaining redundancy in the network– Integrated Resource Planning– Regular feedback to system planners due to TSO structureg y p

• Ensuring EHV system availability– Prudent Operation and Maintenance practices

Thermo vision Scanning– Thermo vision Scanning– Hotline Maintenance

• Deployment of Emergency Restoration System• Asynchronous Inter-regional links • Coordination between utilities for all operational

issues


– Planned Generation/Transmission Outage Scheduling

Economy and EfficiencyEconomy and Efficiency

• Decentralized Resource SchedulingDecentralized Resource Scheduling

• Frequency Linked Balancing Mechanism

• Scientific Metering and Settlement SystemScientific Metering and Settlement System

• Open Access in Interstate Transmission SystemSystem

• Promoting Competition in the Sector

• Transparency• Transparency


Power System In ExtremesPower System In Extremes

MODES OF OPERATION

NORMAL

MODES OF OPERATION

NORMAL

A L E R TRESTORATIVE

EMERGENCY19-July-2007 POWERGRID - NRLDC 33

EMERGENCY

PROBLEMS IN GRID OPERATIONSPROBLEMS IN GRID OPERATIONS

UNIT FAILURE

INSUFFICIENTGENERATION

LOSS OFGENERATION

TRANSFORMER/LOSS OF

BUSTRANSFORMER/LINE FAILURE

LOADBUS ISOLATED

SYSTEM SYSTEM COLLAPSCOLLAPS

EEREDUCEDNETWORK

REDUNDANCY

LINE OVERLOADOR

UNSATISFACTORY

EE


BUS VOLTAGE ISLANDING

TYPICAL LOAD CRASH IN NORTHERN REGIONLoad Crash In Northern Region 09-10 June 2005

22000

24000

51.0

51.5

FREQUENCY

20000

22000

50.5

16000

18000MW

49.5

50.0

Hz.

14000

16000

48.5

49.0LOAD

VARIATION IN LOAD: 22762 TO 14907VARIATION IN FREQ: 51.35 TO 48.58Variation In Load: 22762 Tto 14907

12000

0:00 3:00 6:00 9:00

12:00

15:0018:00

21:00

0:00 3:00 6:00 9:00

12:0015:00

18:00

21:00

48.0Variation In Freq: 51.35 To 48.58


TIME FOR 09/10 JUNE 2005

Tsunami Of Trippings Number of line faults/trippings on 22nd/23rd Dec 2005 night in

Northern Region180

167

120140160180

Cumulative trippingsCumulative restoration

11880

100120 Net lines out

49204060

0

2300 00100

02000300

04000500

06000700


23 01 02 03 04 05 06 07

Foggy ZoneFoggy Zone


Earthquake – 08th Oct 2005 (0920 Hrs)• Magnitude 7 3Magnitude 7.3• Load throw off – 1500 MW approx

• Kashmir Valley collapse Gladni (Jammu) ICTs tripped Tertiary short curcuit• Gladni (Jammu) ICTs tripped – Tertiary short curcuit

• Wagoora ICT –1• 400/220 KV 315 MVA XFMR at Ratangarh tripped - Bucholz

• Generation Loss 500 MW approx (Turbine vibration)• Generation Loss – 500 MW approx (Turbine vibration)• Shanan Power House – Bassi generation backed down• Suratgarh #5 – 250 MW• Ropar #1 – 210 MW• Ropar #1 – 210 MW

• Line Trippings – on over voltage• 400 KV Baspa-SJVNL – II• 400 KV Chamera 1 Chamera 2• 400 KV Chamera 1 – Chamera 2 • 400 KV Chamera 1- Jullundher D/C• 400 KV Jullundher – Moga - II• 220 KV Salal – Kishenpur – IV


220 KV Salal Kishenpur IV

• System normalized by 1300 hrs

REGIONAL LOAD AND FREQ FOR 8-OCTOBER-2005

25000 53.00

NR LOAD FREQ

21000

23000

52.00

52.50

17000

19000

51.00

51.50

13000

15000MW

50.00

50.50

11000

13000

49.50

50.00

7000

9000

48.50

49.00


50000 1 2 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22

TIME

48.00

ZOOM SCROLL

Generators trippingTripping in DTL system on Independence day

Generators tripping

Sl Station No. of Sl kV N Of

Line trippings

No. Name Tripping

1 Rajghat #2 3

2 IP Pos #2 2

Sl

No

kV

Level

No. Of Tripping

2 IP Pos #2 2

3 IP Ext GT3 2

4 IP Ext GT4 2

.

1 220 131

2 66 113 4 IP Ext GT4 2

5 IP Ext GT5 2

6 IP Ext GT6 2

2 66 113

3 33 2266 IP Ext GT6 2

7 IP Ext ST2 2

8 1 3

4 TOTAL 460


8 Pragati 1 3

Hourly Tripping Frequency on 15th Aug 2006Trippings in DTL system

4650

4644

35

40

45

220 kV 66kV 33kV

20

232220

25

30

35

of T

rippi

ng

12 12

15

9

13

20

8

13

77 7

13

7 7

18

7

20

7

10

16

79 8

11

10

15

20

No.

o

3 3

68 76 7

4

7 7

13

7 7

4

7 75 6

3

8

0

5

10

0800 0900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000


0800 0900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000Time(Hrs)

Indian Electricity Markety

Development of the Power M k i I diMarket in India

• Development of the Power Market p– Section 66, IE Act 2003

– National Electricity Policy, 12-Feb-2005, Para 5.7.1(d)

I l t ti f I t St t ABT 2002 03• Implementation of Inter-State ABT : 2002-03– Metering, Scheduling and Settlement

• Introduction of Open Access in Inter StateIntroduction of Open Access in Inter State Transmission : May 2004

• Development of PX– Staff paper by CERC : July 2006

– Public hearing : December 2006

– Guidelines for setting up PX : February 2007


g p y

– Proposal for setting up PX : MCX, March 2007

Regional Electricity Market in India

Long term contracts

Daily off take

Buyer SellerShort term Contract

TSOPhysical delivery

Physical Off takeDaily Delivery Commitment

Daily off‐take commitment Grid

Physical delivery

Pool AccountTransmission Charges

Capacity addition

Buyer SellerWeekly settlement

Operated by

System Operator

UI UI

System Operator

Availability & Energy Charges

RetailLenders& Owners


Retail Consumers

& Owners

Availability Based Tariff (ABT) & U h d l d I t h (UI)Unscheduled Interchange (UI)

Commercial Mechanism

ABC of ABTABC of ABT

• ABT is a scientific settlement system forABT is a scientific settlement system for contracted sale & purchase of power

• Has three components• Has three components– Fixed Charges or capacity charge

Li k d t d h d d l d• Linked to day-ahead declared availability/subscription

– Variable Charges or fuel chargesVariable Charges or fuel charges• Linked to before the fact energy schedules

– Charges for deviation from commitments


Charges for deviation from commitments

ABC of ABTABC of ABT

• Frequency actuated signal– Signal transmitted at the speed of dynamics to be

controlled– Quasi-steady state assumption not valid– Quasi-steady state assumption not valid

• Real time pricing stretched to its physical limits– Merit order– Economic load management

• Incentives for helping the grid• Opportunities for a diligent player• Simple, dispute-free weekly settlement system


DECENTRALIZED SCHEDULING

TimeAvailabilityDeclaration

Entitlements

10:00

11:00

Time

Entitlements

S

Requisition &Bilateral Agreements

I j i S h d l

11:00

15:00

RI LDC

Injection Schedule Drawal Schedule

Revision in DC Revision in Requisition

17:00

22:00

RLDC

ISGS

FinalInjection Schedule

FinalDrawal Schedule

23:00

S


Revisions duringCurrent day

Revisions duringCurrent day

0 to 24 hours

Balancing market guiding vectorU h d l d I h (UI) RUnscheduled Interchange (UI) Rate

applicable only for deviations from contract in real-time

745800NORMAL OPERATING BAND SPECIFIED BY IEGC

600

700

WH

)

Deficit condition in the grid

Signal to serve more

consumers if possible

NORMAL OPERATING BAND SPECIFIED BY IEGC

345

300

400

500

(Pai

se/K

W else save fuel

by reducing generation

Signal to use all available

150

210

100

200

300

Rat

e (

Surplus condition in the grid

use a ll available generating resources

Elsereduce energy consumption

0 00

100

48.5 49.0 49.5 50.0 50.5 51.0

the grid


Frequency (Hz) UI Rate wef 30th April 2007

Improvement in Frequency Profile


UI mechanismUI mechanism• Maximizes social welfare• Transparent, neutral & rigging proof• Diffuses market power • Ultimate open access• Facilitates reforms in the sector

E t d d bil t l h• Encourages trade and bilateral exchanges• Facilitates arbitrage with other regional power

poolspools• Offers alternative tariff mechanism for

independent power producers and merchant


p p pplants

ADVANTAGES ABT & UIADVANTAGES ABT & UI

• Inculcates self discipline among participantsInculcates self discipline among participants– Incentives to those who help the grid

– Disincentives to those who harm the gridg

• Is scientific commercial mechanism

• Brings in economy and efficiencyg y y

• Achieves natural merit order in generation

• Conducive for competition in power sectorConducive for competition in power sector

• Provides platform for power market to flourish


The End Result ….The End Result ….• Frequency is

– collectively controlledy– democratically stabilized

• Wholesale market is workably competitive – allocative efficiency– productive efficiency

• Economic signal available for• Economic signal available for – optimum utilization of resource – investments in generation capacityg p y

• Settlement is– streamlined


– dispute-free

Short Term Open Accessp

OPEN ACCESS IN INTER-STATE TRANSMISSIONTRANSMISSION

• Implemented w.e.f. 6-May-2004• Products –

– Long term Access– Short term Access

• MonthlyAd– Advance

– First Come First Serve• Day ahead • Intra day transactions

• Permits usage of spare transmission capacity through a transparent process

• Offers choice and freedom to buy & sell powery p• Provides signals for investment in transmission


Time Line For Open AccessTime Line For Open Access

Current MonthDay of

OperationS h d li &

19 25

M1 M2 M3

Scheduling & Accounting

AdvanceR ti U t 3

One Day Before Operation

Days

Reservation Upto 3 – Months

Approvals For Advance

First Come First Serve

Day – Ahead


Advance Reservation Intra - Day

Metering and Settlement Systemg y

Metering System

Meter Locations No. of Meters

North 181 1002

East 88 338

West 74 390West 74 390

Southern 80 441

North East 54 191

All India 477 2362


All India 477 2362

Utilities1 GRIDCO 24 LOKTAK 47 MPPTCL2 KSEB 25 BPSL 48 APPCC3 DVC 26 KAWAS 49 J&K4 KPCL 27 MIZORAM 50 UPCL5 MALANA 28 MSEDCL 51 RVVNL5 MALANA 28 MSEDCL 51 RVVNL6 RSTPS 29 CSEB 52 RST7 TRIPURA 30 MSETCL 53 PTC8 BHUSHAN 31 UPPCL 54 NVVNL9 JDVNL 32 MPSEB 55 AEL9 JDVNL 32 MPSEB 55 AEL

10 BSEB 33 UTC 56 TATA11 NBFAL 34 GOA 57 RETL12 JTPCL 35 APTRANSCO 58 LANCO13 SIKKIM 36 PSEB 59 JSWEL14 ARUNACHAL 37 HPGCL 60 JSWPTCL15 DADRI GAS 38 DTL 61 SKPCL16 KAYAMKULAM 39 GUVNL 62 GEL17 BSES 40 TNEB 63 NPCL(UP)18 AURAIYA 41 WBSEB 64 GSML19 KPTCL 42 TATA 65 NHPC20 NBVL 43 MPSEB 66 OHPC21 ANTA 44 CESC 67 HPC22 RGCCPP 45 SAIL 68 USML


22 RGCCPP 45 SAIL 68 USML23 NAGALAND 46 HPSEB 69 RPPCC

Time Line For SettlementTime Line For Settlement

Settlement weekThree day grace periodFor Bank processing

0.04 % per day interest on defaulters

Mon

day

0000

unda

y 24

00 esda

y24

00 day

0 day

0 esda

y24

00esda

y24

00

rida

y 24

00

onda

y 24

00

M Su 2

Tu 2

Meter Data download & receipt at RLDC & preliminary checks

Thu

rs12

00

Satu

rd

2400 Tu 2

Tu 2 Fr 2

Disbursement to utilities from the pool account

Mo 2

Data validation, processing and computation at RLDC. Forwarded to Regional Power Committee Secretariat Account

Settled within 21 days

Data cross checking by Regional Power Committee Secretariat & Issue of Pool Account

Unscheduled Interchange Account Reactive Energy Account

Payment by utilities to the pool account managed by System Operator (RLDC)


International Interconnections

India – Bhutan Interconnection

SIKKIM BHUTAN KanglungTangmachu

Chukha HEP (4x84 MW), Bhutanconnected with Indian system

Kuruchhu HEP (4x15 MW) of

SIKKIM U Kanglung

Tintibi(336MW)

ChukhaKilikhar

(60MW)Kuruchhu

Pemagh

Tala HEP

KV)

(1020MW)

Kuruchhu HEP (4x15 MW) ofBhutan connected to IndianGrid (2

20 K

V)

Nganglam

Salakati Bornagar

Geylegphug(132 KV)

RangiaG

De

Siliguri (400

K

132kV Geylegphug -Salakati

Tala HEP(1020MW)

BongaigaonSiliguri

Dalkhola

Birpara

Agia

SalakatiDhaligaon Amingao

Guwahat

Rangia

interconnected with Indiangrid Aug’2006 BANGLADESH

GALST MEGHALAYA


India - Bhutan

Kurichu HEP (4x15 MW) of Bhutan already connected to Indian Grid through Kurichu – Geylegphug – Salakati 132 kV lineg y gp g

3 nos. of 33 kV links are also in service between India and Bhutan

Tala HEP 400kV level interconnection from Tala in Bhutan to Delhi in India for evacuation of power from Tala HEP(6x170MW)

More hydro projects envisaged to come up in BhutanMore hydro projects envisaged to come up in BhutanPunatsangechu - I : 1000 MWPunatsangechu - II: 1000 MWMangdechu : 600 MWMangdechu : 600 MWSankosh : 4060MW


India - Bhutan

Chukha HEP (4x84 MW) system in Bhutan, built with Indian technical and financial assistance -with Indian technical and financial assistance Chukha-Birpara 220kV 3 ckts.

S l f Ch kh HEP (336MW) i Bh t iSurplus power from Chukha HEP (336MW) in Bhutan is exported to India. – constitutes about 75% to 80% (1400 MU/year) of total power generatedMU/year) of total power generated.

Benefits to both the countries

Earning to Bhutan - Rs. 1400 million (US$ 31 million) annually


India have access to environment friendly hydro power

India – Nepal Grid Interconnection

Presently 16 links at 132/33/11 kV voltage level

Ab t 50 MW b i h dAbout 50 MW power being exchangedNet export to Nepal (about 10% of demand of Nepal metthrough imports from India)


Supply of 70MU/annum from Tanakpur (India) to Nepal

India - NepalLimited Energy trade based on bilateral agreementsed e gy ade based o b a e a ag ee e s

Over 16 links at 132/33/11 kVAbout 50 MW of power being exchangedNet e port to Nepal (abo t 10% of demand of Nepal met thro gh imports fromNet export to Nepal (about 10% of demand of Nepal met through imports from

India)Supply of free power from Tanakpur (India) to Nepal – 70MU/annum

d l h i d d f i ddi i lIndo-Nepal Power Exchange Committee recommended for construction additional 132kV lines

Anandnagar (India) - Butwal (Nepal) Motihari (India) - Birganj Nepal Sitamarhi (India) – Dhalkebar (Nepal)

Large potential projects being considered for development and export of power toLarge potential projects being considered for development and export of power to India

West Seti HEP 750 MWArun HEP 685 MW


Arun HEP 685 MWPancheshwar HEP 6,500 MW

Indian Electricity Grid CodeIndian Electricity Grid Code

IEGCIEGC

The IEGC brings together a single set of technical g g grules,encompassing all the Utilities connected to/or using the inter-State transmission system (ISTS) and provides the following:provides the following:– Documentation of the principles and procedures which

define the relationship between the various Users of the inter State transmission system (ISTS) as well as theinter-State transmission system (ISTS), as well as the Regional and State Load Dispatch Centers

– Facilitation of the operation, maintenance, development and planning of economic and reliable Regional Gridplanning of economic and reliable Regional Grid

– Facilitation for beneficial trading of electricity by defining a common basis of operation of the ISTS, applicable to all the the users of the ISTS


the users of the ISTS

Chapter – 1: Generalp

1.1 Introduction1.2 Objective1.3 Scope1.4 Structure of the IEGC1.5 Non-Compliance

G f O1.6 Free Governor Mode of Operation1.7 Charge/payment for Reactive Energy Exchanges1 8 Exemptions1.8 Exemptions1.9 Glossary and Definitions


Chapter – 2: Role of Various O i ti d Th i Li kOrganizations and Their Linkages

2.1 Introduction2.2 Role of RLDCs2.3 Role of RPCs22.4 Role of CTU2.5 Role of CEA

f S C2.6 Role of SLDCs2.7 Role of STUs


Chapter – 3: Planning Code For Inter St t T i iState Transmission

3.1 Introduction3.2 Objective3.3 Scope3.4 Planning Policy3.5 Planning Criterion3.6 Planning Data3.7 Implementation of Transmission Plan


Chapter – 4: Connection Conditionsp4.1 Introduction4.2 Objective4 3 Scope4.3 Scope4.4 Procedure for Connection4.5 Connection Agreement4.6 ISTS Parameter Variations4.7 Agency & CTU equipment at Connection Points4.8 Generating Units and Power Stations4.9 Reactive Power Compensation4.10 Data & Communication Facilities4.11 System Recording Instruments4.12 Responsibilities for Operational Safety4 13 Procedure for site access site operational activities and maintenance4.13 Procedure for site access, site operational activities and maintenance

standards4.14 International Connections to ISTS4.15 Schedule of Assets of Regional Grid


gAnnexure : 1 Model Connection Agreement

Chapter – 5: Operating Code For R i l G idRegional Grids

5.1 Operating Policyp g y5.2 System Security Aspects5.3 Demand Estimation for Operational Purposes5.4 Demand Management5.5 Periodic Reports

O5.6 Operational Liaison5.7 Outage Planning5 8 Recovery Procedures5.8 Recovery Procedures5.9 Event Information


Chapter – 6: Scheduling and Dispatch C dCode

6.1 Introduction6.2 Objective6.3 Scope6.4 Demarcation of Responsibilities6.5 Scheduling and Despatch procedures

C6.6 Reactive Power and Voltage ControlAnnexure 1 : Complementary Commercial Mechanism Annexure 2 : Regulatory Requirements of Special Energy g y q p gy

MetersAnnexure 3 : Payment for Reactive Energy Exchanges on

State- owned Lines


Chapter – 7 & 8Chapter 7 & 8

• Chapter – 7: Inter – Regional ExchangesChapter 7: Inter Regional Exchanges

• Chapter – 8: Management of IEGC

I E G C


DiscussionDiscussion

northern regional load dispatch center -...

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