Largest sized hydro unit (180 MW at Chamera) in the country

Salient FeaturesNorthern Regional Power System

Welcome

UNUSUAL

GRID OPERATING CONDITIONS

LOAD FORECASTING

T SRINIVASMANAGERSRLDC

MAIN COMPONENTS OF THE GRID

GENERATION

LOAD

TRANSMISSION NETWORK

DETAILS

PERFORMANCE INDICES

SYSTEM FREQUENCY

SYSTEM VOLTAGE

HEALTH OF TRANSMISSION NETWORK

SYSTEM RESERVES & REDUNDANCY

CAPABILITY TO OVERCOME A CONTINGENCY

MAIN FUNCTIONS OF A GRID CONTROL ROOM

Load Generation Balance

Merit Order Operation

Inter-regional/Intra-regional Exchanges

Maintenance of Grid Security

System Restoration/Revival

LOAD GENERATION BALANCE

Load Curves of Northern Region for Typical Summer & Winter Season

16000

17000

18000

19000

20000

21000

22000

23000

24000

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Hours

MW

Summer Summer high hydro Winter

11000

13000

15000

17000

19000

21000

23000

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

HOUR ---->

DE

MA

ND

IN

MW

--->

TYPICAL LOAD CURVE OF SR

WINTER

MONSOON

SUMMER

EVENING PEAK

WEATHERCONSUMPTION

LOAD DIVERSITY

The unique load curve of different identities due to varied nature of load / requirements results in the overall load diversity.

Why Load forecasting?

Load forecasting helps an electric utility to make important

decisions including decisions on purchasing

and generating electric power, load switching, and

infrastructure development. Load forecasts are extremely

important for energy suppliers,

ISOs, .nancial institutions, and other participants in electric

energy generation, transmission, distribution, and markets.

Load forecasting Categories

• Short Term Load Forecasting

from one hour to one week

• Medium term Load Forecasting

from a week to a year

• Long term Load Forecasting

longer than a year

States/U.T Demand met Requirement Shortage ShortageMU/Day MU/Day MU/Day %age

Punjab 104.42 113.70 9.28 8.16Haryana 62.31 65.36 3.05 4.67

Rajasthan 69.39 70.91 1.52 2.14U.P. 103.95 131.75 27.80 21.10

Uttranchal 9.79 10.15 0.36 3.54Delhi 63.56 65.68 2.12 3.23H.P 9.22 9.23 0.01 0.11J&K 15.29 18.39 3.10 16.86

Chandigarh 3.72 3.72 0.00 0.00N.F.F./Rail 1.53 1.53 0.00 0.00

Total Region 443.18 490.42 47.24 9.63

Power Supply Position of Northern Region for a Typical Summer Month

Average Energy/day (Net)

States/U.T Demand met Requirement Shortage ShortageMU/Day MU/Day MU/Day %age

Punjab 63.89 68.00 4.11 6.04Haryana 44.21 48.00 3.79 7.90

Rajasthan 68.38 69.79 1.41 2.02U.P. 104.92 130.00 25.08 19.29

Uttranchal 10.79 11.00 0.21 1.91Delhi 52.49 56.16 3.67 6.53H.P 9.30 9.50 0.20 2.11J&K 18.72 20.00 1.28 6.40

Chandigarh 2.85 2.85 0.00 0.00N.F.F./Rail 1.91 1.91 0.00 0.00

Total Region 375.52 417.21 41.69 9.99

Average Energy/day (Net)

Power Supply Position of Northern Region for a Typical Winter Month

Max. Max.States/U.T Demand met Requirement Shortage Shortage

MW MW MW %ageA B D (D/B)*100

Punjab 5281 5691 410 7.20Haryana 3325 3411 86 2.52

Rajasthan 3610 3610 0 0.00U.P. 5626 6685 1059 15.84

Uttranchal 681 771 90 11.67Delhi 3101 3347 246 7.35H.P 505 505 0 0.00J&K 938 1160 222 19.14

Chandigarh 206 206 0 0.00N.F.F./Rail 75 75 0 0.00

Region 21767 24092 2325 9.65Diversity Factor= 1.07

Peak MW

Power Supply Position of Northern Region for A Typical Summer Month

Max. Max.States/U.T Demand met Requirement Shortage Shortage

MW MW MW %ageA B D (D/B)*100

Punjab 3582 3582 0 0.00Haryana 2647 2981 334 11.2Rajasthan 3535 3535 0 0.00U.P. 5018 6228 1210 19.43Uttranchal 680 695 15 2.16Delhi 3042 3367 325 9.65H.P 696 696 0 0.00J&K 939 1200 261 21.75Chandigarh 145 145 0 0.00N.F.F./Rail 75 75 0 0.00Region 20109 22040 1931 8.76Diversity Factor = 1.07

Peak MW

Power Supply Position of Northern Region for A Typical Winter Month

G1 G2

SERC

SLDCSEB/STU

State Govt.

RLDC

REB

CTU

CERC

Central Govt. CEA

ISTS

ISGS

Load

L1 L2

Intra State System

IEGC to Operate on the periphery

X= - GL G

DEMAND ESTIMATION

DEMAND ESTIMATION

Availability = Own Generation (+) Entitlement from Grid (+) Bilaterals

DEMAND ESTIMATION

IEGC Chapter –6Para 6.3 Sub-Para 6.3.3Each State / SLDC shall develop methodologies / mechanisms for estimation (MW, MVAR and MWH) for operational purposes. The data for estimation shall also include Load Shedding, Power Cuts etc. SLDCs shall also maintain Historical Database for Demand Estimation.

DEMAND ESTIMATION

Load Restriction = Demand (Requirement)(Load shedding)

(-) Availability

ENTITLEMENTS = Fixed Shares + Unallocated Shares

FIXED SHARES

Allocation to States from the Central Sector Stations in terms of Percentages which generally remain fixed.

UNALLOCATED SHARES

Allocation to States from Central Sector Stations in terms of Percentages which are changed on seasonal basis and / or under typical conditions as decided by Govt. of India.

NTPC & NAPP

Chandigarh 5.00Delhi 25.00Haryana 26.00H.P. 0.00J & K 8.00Punjab 16.00Rajasthan 20.00U.P. 0.00Uttranchal 0.00Total 100.00

State Constituent

ALLOCATION FROM UNALLOCATED QUOTA OF ISGS TO CONSTITUENTS OF NORTHERN REGION

0.000.00

UNALLOCATED (%)

RAPP "B"

0.00100.00

0.00100.00

0.000.000.000.00

Gross Ex- busStation Installed Installed

Capacity Capacity Total Peak Off peak Peak Off peak

(MW) (MW) (2000 hrs) (0300 hrs) (2000 hrs) (0300 hrs)Singrauli 2000 1835 11.25 1835 1835 206 206Rihand 1000 910 13.75 910 910 125 125Dadri (T) 840 760 90.00 760 760 684 684Unchahar-I 420 380 6.90 380 380 26 26Unchahar-II 420 380 14.94 380 380 57 57Anta 419 406 14.26 380 380 54 54Auraiya 663 643 13.46 587 587 79 79Dadri (G) 830 805 12.73 800 800 102 102NTPC TOTAL 6592 6120 6033 6033 1334 1334

NAPS 440 385 14.31 363 363 52 52RAPS#3 220 198 15.00 200 200 30 30RAPS#4 220 198 35.00 200 200 70 70NPC TOTAL 880 781 763 763 152 152

Baira Siul 180 178 11.10 178 119 20 13Salal 690 683 11.62 653 653 76 76Tanakpur 94 93 12.81 89 89 11 11Chamera 540 535 7.90 535 356 42 28Uri 480 475 11.04 475 475 52 52NHPC TOTAL 1984 1964 1931 1693 202 181TOTAL 9456 8865 8726 8488 1688 1667

` ENTITLEMENT FROM CENTRAL SECTOR 1688 1667PURCHASE FROM UTTRANCHAL UNDER BILATERAL AGREEMENT(THRU PTC) 150 150PURCHASE FROM U.P. UNDER BILATERAL AGREEMENT 100 100PURCHASE FROM H.P. UNDER BILATERAL AGREEMENT 379 379PURCHASE FROM PTC UNDER BILATERAL AGREEMENT (WBPDCL POWER) 100 100ONE THIRD SHARE OF HARYANA IN IP UNIT # 2,3 & 4 -12 -12SALE TO PUNJAB UNDER BILATERAL AGREEMENT (0000-0930 HRS.) 0 -300SALE TO HARYANA UNDER BILATERAL AGREEMENT (0000-1000 HRS.) 0 -200SALE TO M.P. THROUGH PTC (0000-0800 HRS.) 0 -200TOTAL BILATERAL EXCHANGES 717 17NET ENTITLEMENT FROM GRID 2405 1684TRANSMISSION LOSSES ( @ 2.00 %) -48 -34NET DRAWAL SCHEDULE FROM GRID AT STATE'S PERIPHERY 2356 1650

NOTE: 1. Badarpur generation, which is totally allocated to Delhi, is taken as within Delhi's system. 2.Delhi has been allocated 25% from unallocated quota of central sector.

Entitlement

ENTITLEMENT OF DELHI FROM CENTRAL GENERATION DURING SUMMER 2003

Actual Ex- busPlant Availability (MW)

Delhi's Ex- busEntitlement (MW)

Delhi's Power Sourcing Composition During Summer 2003

1000

1400

1800

2200

2600

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Hours

MW

NTPC (1334 MW)

NPC (152 MW)

NHPC (181 to 202 MW)

Net sch. at state's periphery (1650-2356 MW)

BILATERAL = (17 to 717 MW)

1650

1334

1486

1688

1667

2356

IMPORT = 729 MWEXPORT = -712 TO -12 MW

AGRICULTURE SUPPLY TIMINGS : PUNJAB

GROUP – ANIGHT (2000 - 0600 Hrs) 10 Hrs

Avg.DAY (2100 - 0500 Hrs) 16 Hrs

Avg.(0800 - 1600 Hrs)

GROUP – BNIGHT (2000 - 0600 Hrs) 10 Hrs

Avg.DAY (2100 - 0500 Hrs) 16 Hrs

Avg.(0800 - 1600 Hrs)

GROUP – C (BORDER AREAS)(0800 - 1800 Hrs) 10 Hrs

Avg.

STATE AVG. 12.40 HrsGroups are Rotated on Weekly Basis

LOAD DESPATCHING

Barring the period, 1800 – 2200 Hrs, Supply is given in any seven hour stretch as decided by the respective zone. The segregation / Load Staggering is done at zonal level and monitored closely.

State Avg. 7 Hrs.

AGRICULTURE SUPPLY TIMINGS : RAJASTHAN

AGRICULTURE SUPPLY TIMINGS : HARAYANA

GROUP – I (2200 - 0500 Hrs) 9 Hrs

Avg. (0800 - 0900 Hrs)

(1600 - 1730 Hrs)

GROUP – II (0900 - 1600 Hrs) 7 Hrs

Avg.

AMBALA, KARNAL, KURUKSHETRA, SONEPAT, YAMUNANAGAR, JIND & SIRSA :

AGRICULTURE SUPPLY TIMINGS : HARAYANA

GROUP – I (2200 - 0600 Hrs) 10

Hrs Avg. (0800 - 0900 Hrs)

(1630 - 1730 Hrs)

GROUP – II (0800 - 1600 Hrs) 8 Hrs

Avg.

State Avg. 8.5 Hrs.Groups are rotated on weekly basis

SINGLE CROP AREAS COMPRISING BHIWANI, NARNAUL, GURGAON, ROHTAK & FARIDABAD CIRCLE :

CONTROL AREAS

CS - 1 CS - 3

CS - 2

SEB-B SEB-C

STATE

DISTR - A DISTR - C

DISTR - B

SEB's GRIDSLDCCOORDINATES/DIRECTS

SEB-A

COORDINATES/RLDC

REGIONAL GRID

IPP

STATEGENR.

SHARECENTRAL

AGENCIES PARTICIPATING IN THE SCHEDULING PROCESS OF NORTHERN

REGION

NTPC

1. Singrauli2. Rihand3. Unchahar4. Dadri (Th)5. Dadri (GF)6. Dadri (LF)7. Anta (GF)8. Anta (LF)9. Auraiya

(GF)10. Auraiya

(LF)

NHPC

1. Bairasiul2. Salal3. Tanakpur4. Chamera-

15. Chamera-

26. Uri

NPC

1. NAPS2. RAPS –

33. RAPS - 4

Others

1. NJPC

AGENCIES PARTICIPATING IN THE SCHEDULING PROCESS OF NORTHERN

REGION

BBMB

1. Bhakra2. Dehar3. Pong

STATES

1. Punjab2. Haryana3. Rajasthan4. Delhi5. Uttar Pradesh6. Uttaranchal7. Himachal

Pradesh8. Jammu

Kashmir9. U.T.

Chandigarh

OTHERS

1. Eastern Region

2. Western Region

3. Railways4. NFF

AGENCIES PARTICIPATING IN THE SCHEDULING PROCESS OF NORTHERN

REGION

Generating Stations =23

States = 9

Others = 4 (+)

SCHEDULING AND DESPATCH PROCEDURE                 ALL ISGS STATIONS WITH CAPACITIES AND ALLOCATED SHARES TO BE LISTED OUT       BY 1000 HRS EACH ISGS ADVISES RLDC OF ITS EX-POWER PLANT MW AND MWH CAPABILITIES ANTICIPATED FOR NEXT DAY i.e. 00:00 TO 24:00 HRS       BY 1100 HRS BENEFICIARIES ADVISED OF ABOVE INFORMATION ALONG WITH THEIR ENTITLEMENTS       BY 1500 HRS SLDCs ADVISE RLDC THEIR DRAWAL SCHEDULE FOR EACH OF THE ISGS IN WHICH THEY HAVE SHARE         BY 1700 HRS RLDC CONVEYS THE 'EX-POWER PLANT DESPATCH SCHEDULE (IN MW)' TO EACH ISGS AND 'NET DRAWAL SCHEDULE (IN MW)' TO EACH BENEFICIARY (AFTER DEDUCTING TRANSMISSION LOSSES)     RLDC TO ENSURE SCHEDULES ARE OPERATIONALLY REASONABLE WITH RESPECT TO RAMPING UP/RAMPING DOWN RATES AND THE MINIMUM TO MAXIMUM RATIO OF GENERATION.

SCHEDULING AND DESPATCH PROCEDURE (Contd.)  ISGS/SLDCs TO INFORM ANY MODIFICATIONS IN FORESEEN CAPABILITY/STATION WISE DRAWAL SCHEDULE TO RLDC BY 2200 HRS. RLDC TO ISSUE FINAL SCHEDULE IN SUCH CASES BY 2300 HRS.     REVISIONS IN SCHEDULE PERMITTED DURING THE COURSE OF THE DAY. SUCH REVISIONS EFFECTIVE ONE HOUR AFTER THE FIRST ADVISE IS RECEIVED BY THE RLDC.   RLDC TO CHECK FOR TRANSMISSION CONSTRAINTS, IF ANY, BEFORE FINALISING THE DRAWAL/DESPATCH SCHEDULE.   ON COMPLETION OF THE OPERATING DAY, SCHEDULE, AS FINALLY IMPLEMENTED DURING THE DAY SHALL BE ISSUED BY RLDC. THIS WOULD BE THE DATUM FOR COMMERCIAL ACCOUNTING.   RLDC TO PROPERLY DOCUMENT ALL THE ABOVE INFORMATION EXCHANGED BETWEEN ISGS AND RLDC, CONSTITUENTS AND RLDC ETC.      ALL RECORDS IN RESPECT OF ABOVE OPEN TO ALL CONSTITUENTS FOR ANY CHECKING/VERIFICATION FOR A PERIOD OF 20 DAYS.

Time Schedule of interaction between ISGS, SLDCs and NRLDC for Scheduling

Time Interaction Purpose

A. Day ahead Scheduling:

By 1000 hrs ISGS to NRLDCAvailability forecast, time-wise for next day

By 1100 hrs NRLDC to SLDCsAnticipated ISGS wise entitlement for the next day

By 1500 hrs SLDCs to NRLDCISGS wise requisition, demand, bilateral arrangements etc. anticipated for the next day

By 1700 hrs NRLDC to ISGS/ SLDCsFinal generation schedule to ISGS & net drawal schedule to SLDCs for the next day

By 2200 hrs Any ISGS/ SLDC to NRLDCChanges in availability/ requisition, if any for the next day

By 2300 hrs NRLDC to all ISGS/ SLDCsRevised final generation schedule to ISGS & net drawal schedule to SLDCs respectively for the next day

B. Running day Scheduling:

Any time “a” Any ISGS/ SLDC to NRLDCChanges in availability / requisition, if any for rest of the day

Within next one and half hour of “a”

NRLDC to all ISGS/ SLDCsRevised generation schedule to ISGS & net drawal schedule to SLDCs respectively for rest of the day

ISGS: Inter State Generating StationsSLDC: State Load Despatch Centre

MERIT ORDER OPERATION

Components of inter-utility tariff(Pre – ABT Mechanism)

Fixed charges Interest on loans Depreciation O & M charges Return on equity Interest on Working Capital

Energy charges (fuel cost) Incentives Surcharge & other levies No charge for reactive energy

TENTATIVE COST FOR NTPC THERMAL STATIONS FOR THE MONTH OF JUNE 2002

Station

Fixed Cost Rs. Cr/yr

(1)

Average Fixed Cost Rs. Cr/day

(2)

Average Fixed Cost P / KWh

(3)

Variable Base Cost P / KWh

(4)

Variable FPA P / KWh

(5)

Total Variable Base Cost P / KWh

(6)

Composite Cost P / KWh

(3) + (6)

Singrauli 325.90 0.905 21.47 37.05 34.03 71.08 92.55

Rihand 478.74 1.330 65.83 34.29 37.29 71.58 137.41

Unchahar – I 221.71 0.616 73.00 55.83 58.53 114.36 187.36

Anta GPS 92.92 0.258 47.13 60.55 31.79 92.34 139.47

Auraiya GPS 160.20 0.445 42.17 61.92 65.64 127.56* 169.73

Dadri GPS 221.04 0.614 34.26 68.58 67.99 136.57* 170.83

Dadri (T) 416.78 1.158 76.97 90.56 61.71 152.27 229.24

Unchahar – II --- --- --- 235.00 -9.04 225.96 225.96

Payment to Inter State Generating Stations (ISGS) from beneficiaries

under Availability Based Tariff (ABT)

Capacity chargesEnergy chargesUnscheduled Interchange (UI)

1000

900

800

700

600

500

400

300

200

100

0

0 2 4 6 8 10 12 14 16 18 20 22 24

Forecast ex-bus capability of Power Plant

Hours

MW

Net Injection Schedule

SEB - A's Requisition

SEB - A's Entitlement - (40% )

SCHEDULING

Energy Charges (paise/kwh) for Central Sector stations (June 2002 level)

Sl. No. Power Station Rate (Paise / KWh)

1. Salal 54.59

2. Tanakpur 54.59

3. Singrauli 65.22

4. Rihand 68.63

5. Anta/Auraiya/Dadri GT 95.00

6. Unchahar 105.00

7. Dadri (Thermal) 146.25

FREQUENCY vs UI PRICE

0

28

56

84

112

140

168

196

224

252

280

308

336

364

392

420

448

51

50.9

50.8

50.7

50.6

50.5

50.4

50.3

50.2

50.1 50

49.9

49.8

49.7

49.6

49.5

49.4

49.3

49.2

49.1 49

48.9

48.8

48.7

48.6

48.5

FREQUENCY

PA

ISE

/UN

IT

49 HZ

50.5 HZ

49.5 HZ

50 HZ

49.5 HZ CORRESPONDS TO RS.2.80

UI PRICE AND FREQUENCY

Percentage of time frequency remained within the IEGC band (49.0-50.5 Hz) in Northern Region

60

65

70

75

80

85

90

95

100

December January February March April May June July August September October November

Perc

enta

ge o

f tim

e

pre-ABT

post-ABT

Singrauli & Rihand

2555

2530

2491 25

05

2200

2300

2400

2500

2600

2700

Pre ABT(Dec 01-Nov 02) Post ABT(Dec 02-Nov 03)

Av

era

ge

MW

Declared Capability Injection Schedule

Unchahar-1 & 2

691

687

599

653

500

550

600

650

700

750

Pre ABT(Dec 01-Nov 02) Post ABT(Dec 02-Nov 03)

Ave

rag

e M

W

Declared Capability Injection Schedule

Dadri (T)

711

640

619

717

500

550

600

650

700

750

800

Pre ABT(Dec 01-Nov 02) Post ABT(Dec 02-Nov 03)

Ave

rag

e M

W

Declared Capability Injection schedule

Anta, Auraiya & Dadri

1478

1336

1330

1636

1100

1200

1300

1400

1500

1600

1700

1800

Pre ABT(Dec 01-Nov 02) Post ABT(Dec 02-Nov 03)

Ave

rag

e M

W

Declared Capabilty Injection Schedule

Schedules as percentage of Declared Capability (DC)

97.5%

86.7%

89.9% 90.4%

99.0%

95.0%

86.3%

81.3%

75.0%

80.0%

85.0%

90.0%

95.0%

100.0%

105.0%

Pithead Unchahar-I +II Dadri (T) Combined cycle ISGS

pre-ABT (Dec 01-Nov 02)

post-ABT (Dec 02-Nov 03)

Minimum voltage recorded at Dadri 400 kV bus

330

340

350

360

370

380

390

400

Volta

ge

in k

V

pre-ABT min. voltage post-ABT min. voltage

INTER REGIONAL EXCHANGES

HCDC Sasaram B-B

HCDC Vindhyachal B-B

HCDC Gazuaka B-B

HCDC Talcher Kolar

HCDC Chandrapur B-B

Inter Regional HVDC Links

IMPORT (MW) 450TIME (Hrs) 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23

10

140

TIME (Hrs) 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23

450 450

100 MW (ISGS Allocations 0000 to 2400 hrs)

100 MW {WBPDCL (ER ) to J & K 0000 to 2400 hrs}-PTC

450 450

10 MW (ER to HVPNL 0000 to 1700 hrs & 2300 to 2400 hr)-NVVNL

INTER REGIONAL EXCHANGE BETWEEN ER & NR ON SASARAM HVDC BACK TO BACK LINK

50 MW (GRIDCO to DTL)-NVVNL

100 MW (ER to HVPNL 0000 to 1700 hrs & 2300 to 2400 hrs)-PTC 100

140 MW {ER (DVC, WBSEB,GRIDCO) to DTL 0000 to 2400 hrs}-PTC200 MW

100 MW ISGS Allocations 0000 to 2400 hrs

100 MW WBSEB to J&K 0000 to 2400hrs- PTC

50 MW GRIDCO to DTL-NVVNL

140 MW WBSEB to DTL 0000 to 2400-PTC

100 MW DVC to HVPNL 0000 to 1700 & 2300 to 2400 hrs-PTC

10 MW GRIDCO to HVPNL 0000 to 1700 & 2300 to 2400 hrs-NVVNL

440

10050 MW DVC to DTL-

PTC

450 450 450 450

1 2 3 4 5 6 7 8FROM

ISGS WB DVC WB GRIDCO DVC WB TOTAL

PERIODTO

DTL DTL J & K DTL RRVPNL RRVPNL

PTC PTC PTC NVVN PTC PTC

00:00 01:00 100 100 100 100 400

01:00 02:00 100 100 100 100 400

02:00 03:00 100 100 100 100 400

03:00 04:00 100 100 100 100 400

04:00 05:00 100 100 100 100 400

05:00 06:00 100 150 100 100 450

06:00 07:00 100 150 100 100 450

07:00 08:00 100 150 100 100 450

08:00 09:00 100 150 100 100 450

09:00 10:00 100 150 100 100 450

10:00 11:00 100 150 100 100 450

11:00 12:00 100 150 100 100 450

12:00 13:00 100 150 100 50 50 450

13:00 14:00 100 150 100 50 50 450

14:00 15:00 100 150 100 50 50 450

15:00 16:00 100 150 100 50 50 450

16:00 17:00 100 150 100 50 50 450

17:00 18:00 100 150 50 100 400

18:00 19:00 100 150 50 100 400

19:00 20:00 100 150 50 100 400

20:00 21:00 100 150 50 100 400

21:00 22:00 100 150 50 100 400

22:00 23:00 100 150 50 100 400

23:00 24:00 100 150 100 350

INTER REGIONAL BILATERAL EXCHANGES (IMPORT) OF POWER IN NR THROUGH SASARAM

Trader -->

TIME (Hrs) 0 1 2 3 4 6 7 8 9 10 11 13 14 15 16 18 19 20 21 22 23

TIME (Hrs) 0 1 2 3 4 6 7 8 9 10 11 13 14 15 16 18 19 20 21 22 23

50

250

50 50 150

100 200 100450 250 50

150

IMPORT

IMPORT

EXPORT

150 MW (Goa to DTL)- GEL150 MW

(Goa to DTL)- GEL

5 12 17

125

INTER REGIONAL EXCHANGE BETWEEN NR & WR ON VINDHYACHAL HVDC BACK TO BACK LINK

EXPORT

17

50 MW

100 MW

200 MW

200 MW ( 0000-0600 hrs) (DTL to MP)- PTC

200 MW100 MW

200

DTL to Gujrat- PTC0000 - 0500, 1200-1730, 2300-2400

(DTL to Chattisgarh)-PTC0000 - 0530 hrs

DTL to CSEB2300-2400 hrs

1 2 3 4 5 6FROM

WB DVC GRIDCO GRIDCO DVC TOTAL

PERIODTO

RRVPNL RRVPNL DTL DTL RRVPNL

PTC PTC PTC NVVN PTC

00:00 01:00 50 50

01:00 02:00 50 50

02:00 03:00 50 50

03:00 04:00 50 50

04:00 05:00 50 50

05:00 06:00 50 50

06:00 07:00 100 100 100 50 350

07:00 08:00 100 100 100 50 350

08:00 09:00 100 100 100 50 350

09:00 10:00 100 100 100 50 350

10:00 11:00 100 100 100 50 350

11:00 12:00 100 100 100 50 350

12:00 13:00 50 50 100

13:00 14:00 50 50 100

14:00 15:00 50 50 100

15:00 16:00 50 50 100

16:00 17:00 50 50 100

17:00 18:00 0

18:00 19:00 0

19:00 20:00 0

20:00 21:00 0

21:00 22:00 0

22:00 23:00 0

23:00 24:00 50 50

Trader -->

SYSTEM SECURITY

TOTAL 1800-2200 MW

WESTWARD FLOW DURING WINTER NIGHTS

WEST SIDE BBMB

SYSTEM (PUNJAB,

HARAYANA,H.P.,J&K,

CHD) (SIZE 6000 MW)

EAST SIDE

DELHI /U.P./ RAJASTHAN

SYSTEM (SIZE 9000

MW)

400 kV Dadri Panipat(400-500 MW)

400 kV Bawana-Hissar(300-450 MW)

400 kV Bawana-Abdullapur(100-200 MW)

220 kV Ballabhgarh-Ch. Dadri(100-150 MW)

220 kV Khetri-Hissar (00-50 MW)

400 kV Bassi-Hissar(100-150 MW)

400 kV Bawana-Bhiwani(350-500 MW)

220 kV Samaypur-Ch. Dadri (100-150 MW)

220 kV Khetri-Ch. Dadri D/C (50-100 MW)

400 kV Dadri-Malerkotla(200-300 MW)

ECONOMY OF REQUISITIONING FROM GAS STATIONS ON LIQUID FIRING

Energy Charges (Liquid Firing)

Anta Rs. 3.20 /unit

Auraiya Rs. 3.00 /unit

Dadri Rs. 5.00 /unit(approx)

UI Rates

49.5 Hz Rs. 2.80

49.4 Hz Rs. 3.08

49.3 Hz Rs. 3.36

49.2 Hz Rs. 3.64

49.1 Hz Rs. 3.92

49.0 Hz & Below Rs. 4.20

Tariff Regulation – Economy and Efficiency vis-à-vis Security

Under Requisition vis-à-vis Overdrawal of Haryana (during the period when f<49.5Hz)

3776

11085

40 27 9

276 278

975

800

312

97118

0.00

200.00

400.00

600.00

800.00

1000.00

1200.00

06.10.2003 07.10.2003 08.10.2003 09.10.2003 10.10.2003 11.10.2003 12.10.2003

MW

Hr

Under Requisition Overdrawal

Under Requisition vis-à-vis Overdrawal by Rajasthan (during the period when the f < 49.5 Hz)

46

91

258

144129

105

2628

293

610

176

384

287

67

0.00

100.00

200.00

300.00

400.00

500.00

600.00

700.00

06.10.2003 07.10.2003 08.10.2003 09.10.2003 10.10.2003 11.10.2003 12.10.2003

MW

Hr

Underrequisition Overdrawal

Ex-Bus Capacity under requisitioned / underutilised in Gas and Nuclear stations (during the week 6th Oct to 12th Oct 2003)

121 121 121 128 126 123 128

60 59 60 60 50 60 58

91 91 96 96 100 96 96

113 113 114 120 124 121 116

180 180 180180 180 180 175

0

100

200

300

400

500

600

700

06.10.2003 07.10.2003 08.10.2003 09.10.2003 10.10.2003 11.10.2003 12.10.2003

Me

ga

wa

tts

Dadri (L) Anta (L) Aurya (L) NAPS RAPS

On 9th Oct 2003 f < 49.0 Hz = 1.56 % of time f < 49.5 Hz = 15.35 % of time f < 50.0 Hz = 81.01 % of time f < 50.5 Hz = 99.90 % of time

Thank You

FREQUENCY RESPONSE IN BHAKRA RIGHT UNIT 1 ON 23.10.2003

50.17

50.10

50.4850.37

50.20147

149

124

137

160

49.00

49.20

49.40

49.60

49.80

50.00

50.20

50.40

50.60

50.80

51.00

7:4

0:0

0

7:4

1:0

0

7:4

2:0

0

7:4

3:0

0

7:4

4:0

0

7:4

5:0

0

7:4

6:0

0

7:4

7:0

0

7:4

8:0

0

7:4

9:0

0

7:5

0:0

0

7:5

1:0

0

7:5

2:0

0

7:5

3:0

0

7:5

4:0

0

7:5

5:0

0

7:5

6:0

0

7:5

7:0

0

7:5

8:0

0

7:5

9:0

0

8:0

0:0

0

TIME

Her

tz

122

127

132

137

142

147

152

157

162

Meg

awat

ts

FREQUENCY BHAKRA RIGHT 1

AVG. NO. OF AGREEMENTS PER MONTH

11.25

7.5

0

1

2

3

4

5

6

7

8

9

10

11

12

PRE ABT POST ABT

TOTAL ENERGY TRADED (MU)

3550.12

5146.59

0

1000

2000

3000

4000

5000

6000

PRE ABT POST ABT

NR BILATERAL AGREEMENTS

SOUTHERN REGIONAL GRID▀ Centre Generating Stations in the Region are

• Ramagundam Super Thermal Power Stn. : 2,600 MW (200x3 + 500x4)

• Neyveli Lignite Corporation Ltd. - II : 1,470 MW (210 x 7)

• Madras Atomic Power Station : 390 MW (170 x 1 + 220X1)

• Kaiga Atomic Power Station : 440 MW (220x2)

• NLC EXPANSION TPS 1 : 420 MW (210X2)

• TALCHER STAGE II : 2000 MW (500X4) situated

in ER▀ Beneficiaries in southern Region are

. ANDHRA PRADESH

• KARNATAKA• KERALA• TAMIL NADU• Union Territory of Pondicherry• NLCMINES• GOA has share of 100MW from RSTPS

CONTROL AREAS

REGIONAL GRID

SEB’S GRID

CS -3CS - 2

CS - 1

CENTRALSHARE

STATEGENR

STATEIPP

DISTR-B

DISTR- A

DISTR- C

SEB - A SEB -CSEB -B

SLDCCOORDINATESDIRECTS

RLDCCOORDINATES