1. GRID OPERATION AND CONTROL

2. MAIN COMPONENTS OF THE GRID  GENERATION  LOAD  TRANSMISSION NETWORK

3. PERFORMANCE INDICES  SYSTEM FREQUENCY  SYSTEM VOLTAGE  HEALTH OF TRANSMISSION NETWORK  SYSTEM RESERVES & REDUNDANCY  CAPABILITY TO OVERCOME A CONTINGENCY

4. 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

5. LOAD GENERATION BALANCE

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

12. G1 G2 SERC SLDC SEB/STU State Govt. RLDC REB CTU CERC Central Govt. CEA ISTS ISGS Load L1L2 Intra State System IEGC to Operate on the periphery X=- GLG DEMAND ESTIMATION

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

14. DEMAND ESTIMATION IEGC Chapter –6 Para 6.3 Sub-Para 6.3.3 Each 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.

15. DEMAND ESTIMATION Load Restriction = Demand (Requirement) (Load shedding) (-) Availability

16. ENTITLEMENTS = Fixed Shares + Unallocated Shares

17. 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.

21. AGRICULTURE SUPPLY TIMINGS : PUNJAB GROUP – A NIGHT (2000 - 0600 Hrs)10 Hrs Avg. DAY (2100 - 0500 Hrs)16 Hrs Avg. (0800 - 1600 Hrs) GROUP – B NIGHT (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 Hrs Groups are Rotated on Weekly Basis LOAD DESPATCHING

22. 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

23. 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 :

24. 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 :

25. COORDINATES/ RLDC REGIONAL GRID IPP STATE GENR. SHARE CENTRAL

26. AGENCIES PARTICIPATING IN THE SCHEDULING PROCESS OF NORTHERN REGION NTPC 1. Singrauli 2. Rihand 3. Unchahar 4. Dadri (Th) 5. Dadri (GF) 6. Dadri (LF) 7. Anta (GF) 8. Anta (LF) 9. Auraiya (GF) 10. Auraiya (LF) NHPC 1. Bairasiul 2. Salal 3. Tanakpur 4. Chamera-1 5. Chamera-2 6. Uri NPC 1. NAPS 2. RAPS – 3 3. RAPS - 4 Others 1. NJPC

27. AGENCIES PARTICIPATING IN THE SCHEDULING PROCESS OF NORTHERN REGION BBMB 1. Bhakra 2. Dehar 3. Pong STATES 1. Punjab 2. Haryana 3. Rajasthan 4. Delhi 5. Uttar Pradesh 6. Uttaranchal 7. Himachal Pradesh 8. Jammu Kashmir 9. U.T. Chandigarh OTHERS 1.Eastern Region 2.Western Region 3.Railways 4.NFF

28. AGENCIES PARTICIPATING IN THE SCHEDULING PROCESS OF NORTHERN REGION Generating Stations =23 States =9 Others =4 (+)

29. SCHEDULING AND DESPATCH PROCEDURE  ALL ISGS STATIONS WITH CAPACITIES AND ALLOCATED SHARES TO BE LISTED OUT  BY 1000 HRSEACH 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 HRSBENEFICIARIES ADVISED OF ABOVE INFORMATION ALONG WITH THEIR ENTITLEMENTS  BY 1500 HRSSLDCs ADVISE RLDC THEIR DRAWAL SCHEDULE FOR EACH OF THE ISGS IN WHICH THEY HAVE SHARE  BY 1700 HRSRLDC 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.

30. 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.

31. Time Schedule of interaction between ISGS, SLDCs and NRLDC for Scheduling TimeInteractionPurpose A. Day ahead Scheduling: By 1000 hrsISGS to NRLDC Availability forecast, time-wise for next day By 1100 hrsNRLDC to SLDCs Anticipated ISGS wise entitlement for the next day By 1500 hrsSLDCs to NRLDC ISGS wise requisition, demand, bilateral arrangements etc. anticipated for the next day By 1700 hrsNRLDC to ISGS/ SLDCs Final generation schedule to ISGS & net drawal schedule to SLDCs for the next day By 2200 hrsAny ISGS/ SLDC to NRLDC Changes in availability/ requisition, if any for the next day By 2300 hrsNRLDC to all ISGS/ SLDCs Revised 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 NRLDC Changes in availability / requisition, if any for rest of the day Within next one and half hour of “a” NRLDC to all ISGS/ SLDCs Revised generation schedule to ISGS & net drawal schedule to SLDCs respectively for rest of the day ISGS:Inter State Generating Stations SLDC:State Load Despatch Centre

32. MERIT ORDER OPERATION

33. 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

34. 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) Singrauli325.900.90521.4737.0534.0371.08 92.55 Rihand478.741.33065.8334.2937.2971.58137.41 Unchahar – I221.710.61673.0055.8358.53114.36187.36 Anta GPS92.920.25847.1360.5531.7992.34139.47 Auraiya GPS160.200.44542.1761.9265.64127.56*169.73 Dadri GPS221.040.61434.2668.5867.99136.57*170.83 Dadri (T)416.781.15876.9790.5661.71152.27229.24 Unchahar – II--- 235.00-9.04225.96

35. Payment to Inter State Generating Stations (ISGS) from beneficiaries under Availability Based Tariff (ABT)  Capacity charges  Energy charges  Unscheduled Interchange (UI)

37. Energy Charges (paise/kwh) for Central Sector stations (June 2002 level) Sl. No.Power StationRate (Paise / KWh) 1.Salal54.59 2.Tanakpur54.59 3.Singrauli65.22 4.Rihand68.63 5.Anta/Auraiya/Dadri GT95.00 6.Unchahar105.00 7.Dadri (Thermal)146.25

38. FREQUENCY vs UI PRICE 0 28 56 84 112 140 168 196 224 252 280 308 336 364 392 420 448 51 50.950.850.750.650.550.450.350.250.1 50 49.949.849.749.649.549.449.349.249.1 49 48.948.848.748.648.5 FREQUENCY PAISE/UNIT 49 HZ 50.5 HZ 49.5 HZ 50 HZ 49.5 HZ CORRESPONDS TO RS.2.80 UI PRICE AND FREQUENCY

40. Singrauli & Rihand 2555 2530 2491 2505 2200 2300 2400 2500 2600 2700 Pre ABT(Dec 01-Nov 02)Post ABT(Dec 02-Nov 03) Average MW Declared CapabilityInjection 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) Average MW Declared CapabilityInjection 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) Average MW Declared CapabilityInjection 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) Average MW Declared CapabiltyInjection Schedule

43. INTER REGIONAL EXCHANGES

44. HCDC Sasaram B-B HCDC Vindhyachal B-B HCDC Gazuaka B-B HCDC Talcher Kolar HCDC Chandrapur B-B Inter Regional HVDC Links

45. 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 440 100 50 MW DVC to DTL- PTC 450

49. SYSTEM SECURITY

53. ECONOMY OF REQUISITIONING FROM GAS STATIONS ON LIQUID FIRING Energy Charges (Liquid Firing) AntaRs. 3.20/unit AuraiyaRs. 3.00/unit DadriRs. 5.00 /unit (approx) UI Rates 49.5 HzRs. 2.80 49.4 HzRs. 3.08 49.3 HzRs. 3.36 49.2 HzRs. 3.64 49.1 HzRs. 3.92 49.0 Hz & BelowRs. 4.20 Tariff Regulation – Economy and Efficiency vis-à-vis Security

63. Thank You

69. NR BILATERAL AGREEMENTS