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POWER GRID CORPORATION OF INDIA LTD

POWER GRID CORPORATION OF INDIA LTD. GRID EVENTS AND ISSUES. in 3 rd SRPC MEETING 19 TH FEBRUARY 2007 BANGALORE. SOUTHERN REGIONAL LOAD DESPATCH CENTRE. ISSUES. 3.0 COMPUTATION OF TALCHER STPS-II INJECTION 5.0 AMC FOR SCADA-EMS SYSTEM UNDER SR ULDC SCHEME

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POWER GRID CORPORATION OF INDIA LTD

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  1. POWER GRID CORPORATION OF INDIA LTD GRID EVENTS AND ISSUES in 3rd SRPC MEETING 19TH FEBRUARY 2007 BANGALORE SOUTHERN REGIONAL LOAD DESPATCH CENTRE

  2. ISSUES 3.0 COMPUTATION OF TALCHER STPS-II INJECTION 5.0AMC FOR SCADA-EMS SYSTEM UNDER SR ULDC SCHEME 6.0WIDE BAND CONNECTIVITY OF PUDUCHERRY 8.0BACKUP TRANSMISSION SCHEME FOR EVACUATION OF TALCHER-II GENERATION 10.0CONCURRENCE FOR AUGMENTATION OF EXISTING ULDC WIDE BAND NETWORK FOR ENSURING DATA REDUNDANCY 14.011TH PLAN CENTRAL SECTOR THERMAL POWER PROJECTS FOR SR 15.0OPERATION OF TALCHER-KOLAR HVDC TRANSMISSION SYSTEM IN GROUND RETURN MODE 16.0REGIONAL TRANSMISSION SCHEMES FOR EXECUTION BY POWERGRID

  3. ISSUES 18.0 STATUS OF REGIONAL TRANSMISSION SCHEMES 18.1UPGRADATION TO 400KV LEVEL OF OPERATION OF KAIGA- GUTTUR D/C LINE 18.2SHIFTING OF ONE 315 MVA, 400/220 KV TRANSFORMER AT TRIVANDRUM 19.0HANDING OVER OF 220KV KODIKURUCHI-EDAMON LINE REQUIRED FOR CONSTRUCTION OF 400KV TIRUNELVELI- EDAMON LINE UNDER KUDUNKULAM EVACUATION SYSTEM 20.0COMPUTATION OF UI EXCHANGES BETWEEN ER-SR 21.0SPECIAL PROTECTION SCHEME(SPS) FOR 2X1000 MW KUDANKULAM ATOMIC POWER PROJECT 23.0PUMP MODE OPERATION OF KADAMPARAI

  4. ISSUES 25.0 EVACUATION SCHEMES FOR NEW CENTRAL GENERATING STATIONS 26.0TERMINATION OF TIRUNELVELI-EDAMON 400KV CIRCUIT UNDER KUDANKULAM EVACUATION SCHEME AT EDAMON 28.0REVISED UNIT TRIPPING SCHEME UNDER HVDC POLE OUTAGES AT TALCHER STAGE-II 29.0PREPONEMENT OF COMMERCIAL OPERATION OF PGCIL TRANSMISSION ELEMENTS 30.0GRID OPERATION 30.1LOW FREQUENCY OPERATION 30.4SCHEDULING OF KAYAMKULAM 32.0CLOSING OF 220KV BALIMELA-UPPER SILERU S/C LINE SCM 23rd AGENDA 29.1.i 29.1.ii

  5. FREQUENCY SPECTRUM FROM AUGUST 06 TO OCT 06 (UPTO 20TH OCT 06) Low Frequency Operation

  6. Date: 17th October 2006 PRESS RELEASE CERC directs PowerGrid to ensure grid stability 1. In order to take action for violating the Indian Electricity Grid Code (IEGC) by drawing electricity in excess of their schedule drawal, the Central Electricity Regulatory Commission (CERC) has directed PowerGrid to furnish the list of States and their quantum of overdrawals in the time-blocks when the frequency in the extended Central Grid was below 49.0 Hz during the period 9th to 15th October 2006. 2. The Commission has further directed all the RLDCs to keep a strict watch over the Grid Code violations, which can possibly endanger the grid stability and promptly inform the Commission about the defaulters with appropriate recommendation regarding remedial action. 3. The maintenance of satisfactory grid frequency has assumed added importance after synchronization of Northern Regional Grid with Central Grid comprising Western, Eastern and North-Eastern Regional Grids. In this context, the IEGC requires that the various beneficiary States shall always endeavor to restrict their net drawal from the grid to their respective drawal schedules, whenever the system frequency is below 49.5 Hz and when the frequency falls below 49.0 Hz, the requisite load shedding shall be carried out by the concerned State to curtail its over drawal. S. K. Chatterjee Assistant Secretary

  7. Summary of ODs at Freq. LT 49 HZ. During the week 09-10-06 TO 15-10-06 Summary of ODs at Freq. LT 49 HZ. During the week 16-10-06 TO 22-10-06

  8. Computation of Talcher STPS-II Injection

  9. Computation of Talcher STPS-II Injection • The computation of actual injection of Talcher STPS-II for accounting purposes was done using SEMs installed on the out going feeders till 31.03.2006. • Clause 7.4.6 of revised IEGC effective from 1st April 2006, provided actual injection of Talcher STPS-II shall be metered on 400 kV side of Generator transformers of Talcher STPS-II units. • CEA has issued (installation and operation of meters) Regulations, 2006 to become effective from 22.03.06 (came to notice in May, 2005). CEA REGU IEGC AMENDMENTS BY SRLDC GT vis a vis Feedres Inj MINUTES OF 1st COMM. NTPC LETTER 070906 SRLDC REPLY 111006 SRLDC REPLY 110806 NTPC LETTER 020806

  10. Computation of UI Exchanges between ER - SR

  11. The methodology adopted by SRLDC for computation of UI between ER-SR during the period 03.04.06 to 27.08.06 was based on the following stipulations made in IEGC (effective from 1.4.2006): 7.6.1 The regional boundaries for scheduling, metering and UI accounting of inter-regional exchanges between ER & SR shall be as follows:  400 kV Bus couplers between Talcher-I and Talcher-II  400 kV East bus of Gazuwaka HVDC. 7.6.3. No attempt shall be made to split the inter-regional schedules into linkwise schedules (where two regions have two or more interconnections).

  12. As regards to the UI computation of Talcher Stage II, the following provisions as stated in IEGC were also taken into consideration: 7.4.2. For a clear demarcation of responsibilities and minimal to-and-fro coordination, the scheduling of Talcher-II shall be coordinated by SRLDC, and the 400 kV AC bus-couplers between Talcher-I (2x500 MW) and Talcher-II (4x500 MW) shall be treated as the interface between ER and SR. 7.4.6. …… The difference between the actual injection of Talcher II and the dispatch schedule shall constitute the UI of Talcher-II, for which payments shall be made from/into the UI pool account of Southern region operated by SRLDC, but at the UI rate corresponding to ER repeat ER frequency. The energy accounting for Talcher-II STPS shall be carried out by SRLDC. 7.4.7. While the dispatch schedule for Talcher-II shall be as advised by SRLDC, the actual generation at Talcher-II may be varied by station operators depending on ER frequency, as long as the resulting UI does not cause a transmission constraint in ER. In case of a transmission constraint being caused in ER by the UI of Talcher-II, ERLDC may advise Talcher-II to curtail its UI under intimation to SRLDC. Any such advise shall be immediately complied with by Talcher-II.

  13. Specific Issues related to UI exchange betweenSR & ERvis-à-vis betweenTalcher Stage II to ER : • Any UI exchange is carried outwith the consent of SRLDC/ERLDC control rooms to move power mainly from surplus to deficit region • The direction and quantum of UI between woulddependon the generation level maintained by Talcher II - irrespective of regions status • Any UI exchange is carried out depending on the frequency of both the regions and thereby resulting into positive differential UI • Talcher II may inject UI irrespective of the frequency relationship of the two regions and thereby at times resulting into negative differential UI Annexure-I • Any UI exchange gives equitable benefits to the constituents in both the regions • Injection of UI by Talcher II if clubbed with SR to ER UI, may not result in such equitable scenario Annexure-II

  14. METHODOLOGY FOR ACCOUNTING OF UI BETWEEN TALCHER II AND ER • It may therefore be seen that in view of the specific location of Talcher II vis-à-vis other ISGSs, the UI computation in respect of Talcher II is required to be followed in a manner which would be based on the IEGC provisions as stated above and at the same time it would not defeat the basic UI philosophy which stipulates that the UI exchange between two agencies/ regions should benefit both the parties. • In order to achieve this, whenever UI transactions are there in respect of Talcher II with ER, the UI calculations have to be carried out as per the IEGC provisions (clause 7.4.6 ) i.e. at ER frequency. • However as per this clause, as the payment for this UI to Talcher II has to be made from the UI pool account operated by SR, it is natural that SR UI pool must be suitably compensated by getting the equivalent amount from the UI pool operated by ER. • Furthermore by following this methodology as no differential gets generated in SR/ER UI pool on this account, there cannot be any sharing of accumulated differential UI. therefore the possible viable approach within the framework of IEGC regulations could be: --- to treat this transaction as a UI only between Talcher II and ER and --- while accounting these amounts (as it is) these can be routed through the SR weekly UI accounts

  15. Payable by ER RS. 4.3 Lakhs Receivable by SR Rs. 6.2 Lakhs Negative Differential UI Rs.2.9 Lakhs

  16. Annexure -I CASE – 1 UI from Talcher Stage II to ER when SR frequency < ER frequency Base Case: Talcher Stage II UI =0 MW SR Freq = 49.16 Hz UI Rate= Rs.5/ SR Freq = 49.16 Hz UI Rate= Rs.5/ ER Freq = 49.6 Hz UI Rate= Rs.3/ ER Freq = 49.6 Hz UI Rate= Rs.3/ 0 MW UI (from SR to ER) 0 MW UI (from SR to ER) UI (SR to ER) 0 MW UI (SR to ER) 0 MW Talcher Stage I & II I/C Talcher Stage I & II I/C 0 MW ER 50 MW ER Talcher Stage II Gen: 1650 Schd: 1600 Talcher Stage II Gen: 1600 Schd: 1600 SR SR 1600 MW 1600 MW Base Case +Talcher Stage II 50 MW UI (Talcher Stage 2 actual Generation = 1650 MW against Schd. of 1600 MW) • Issues • Considering the variable cost of Talcher Stage II as around 80 paisa it would be beneficial for Talcher Stage II to generate positive UI as the ER UI rate is more than its variable cost. • For every unit of power exported to ER, Talcher Stage II would get a price of Rs 3/Unit. • However if the UI by Talcher Stage II to ER is considered as UI from SR to ER, then it would be a case of –ve UI • For every unit of power exported , SR would expect a price of Rs 5/Unit while ER would be able to give a price of Rs 3/Unit only. • Such transactions accumulated during that periods could cause commercial implications. • In order to address this issue ,the UI transactions can be considered between Talcher Stage II and ER, however the accounts can be routed through SR.

  17. BACKUP TRANSMISSION SCHEME FOR EVACUATION OF TALCHER-II GENERATION

  18. OPTION 1 400 KV TSTPP-II- MENDHASAL-BEHRAMPUR-GAZUWAKA. 400 KV TSTPP-II- MENDHASAL IS ORISSA GRIDCO LINE (YET TO BE DECIDED). HENCE LONG TERM STOA HAS TO BE SOUGHT. STOA WOULD NOT BE LINE WISE BUT FOR ORISSA GRID. STOA WOULD DEPEND ON THE LINE LOADING. CORRIDOR WOULD NOT BE USED, EXCEPT WHEN POLES ARE OUT MENDHASAL BEHRAMPUR

  19. MENDHASAL BEHRAMPUR OPTION 2 400 KV TSTPP-II- BEHRAMPUR-GAZUWAKA. SINCE NO GRIDCO LINE IS INVOLVED, THERE WOULD NOT BE A NEED FOR STOA. HENCE THIS OPTION WOULD BE PREFFERED

  20. REGIONAL TRANSMISSION SCHEMES FOR EXECUTION BY POWERGRID

  21. KRISHNAPATTINAM UMPP OPTION 1 TN UMPP D/C QUAD MOOSE 765 KV HVDC B2B

  22. KRISHNAPATTINAM UMPP OPTION 2 TN UMPP D/C QUAD MOOSE 765 KV HVDC B2B

  23. COMMENTS ON KRISHNAPATTINAM AND TN UMPP EVACUATION PLAN • THE FOLLOWING 400 KV LINES WOULD BE STRESSED • CUDDAPAH-KOLAR-SOMANAHALLI • KOLAR - MELKOTTAIYUR • HOSUR-SALEM • RAICHUR EVACUATION BOTTLENECK IN CASE OF 765 KV LINE TRIPPING • NUNNA-KHAMMAM-N’SAGAR • SRISAILAM-KURNOOL • NUNNA-NELLORE D/C EVACUATION WITH VEMAGIRI • HIGH VOLTAGES ARE ALSO A CAUSE OF CONCERN AND ADEQUATE REACTIVE ELEMENTS MAY HAVE TO BE PROVIDED

  24. UMPP EVACUATION BASE CASE TALCHER-KOLAR NIL 2500 MW EXPORT TO WR ON 765 KV RAICHUR-SHOLAPUR

  25. KRISHNAPATTINAM UMPP • CREATE ONE MORE 400 KV STATION NEAR CHENNAI FOR FULL FLEDGED RING MAIN • 400 KV STATION AT DB PURA NEAR BANGALORE AS NELAMANGALA IS TOO CONGESTED NAGARJUNA& ONGC PLANT SRLDC OPTION-A TN UMPP D/C QUAD MOOSE 765 KV RING CONSISTING OF NELLORE, MELKOTTAIYUR, ARASUR, HIRIYUR AND RAICHUR 765 KV HVDC B2B

  26. SHIFTING OF ONE 315 MVA, 400/220 KV TRANSFORMER AT TRIVANDRUM

  27. SHIFTING OF 3RD ICT FROM TRIVANDRUM TO MADAKKATHARA • LOADING OF MADAKKATHARA ICTs ARE AROUND 200-250 MW EACH • L/C ON ONE ICT TYPICALLY OVERLOADS OTHER ICT • LOAD REARRANGEMENTS AND TRIPPING OF ONE CKT OF UDUMALPET IS DONE TO CONTROL THE OVERLOAD. • LOADING OF ABOUT 600 MW IS SEEN IN 2012 CASE • SHIFTING OF THE ICT IS ADVISABLE

  28. MADAKKATHARA ICT TOTAL MW TRIVANDRUM ICT TOTAL MW

  29. ADVANCED COMMISSIONING OF NARENDRA-GUTTUR D/C

  30. CHARGING OF KAIGA GUTTUR TO 400 KV KOLHAPUR (MAHARASHTRA) CHIKKODI KARNATAKA 175 KMS KUDUCHI 2X100 MVA 220/110 TATA DIESEL 80 MW, 593 PS VAR COST M.L.PURA 70 KMS GHATAPRABHA ( 20 MW) 2X100 MVA 220/110 TO ALMATTI BAGALKOT,-BBWADI,-LINGSUGUR – Raichur TPS BELGAUM 63 KMS NARENDRA 220 PONDA (Goa) AMBEWADI HUBLI XELDEM(GOA) KODASALLI KADRA NAGJHARI HAVERI KAIGA

  31. ADVANTAGES OF NARENDRA GUTTUR LINE • KAIGA + KALI EVACUATION BECOMES MORE STABLE • LOOP GETS ADDED AT 400 KV LEVEL • SR GRID LOSSES GET REDUCED BY 6-10 MW • FLOW GETS SHARED BETWEEN KAIGA-GUTTUR AND NARENDRA-GUTTUR • EVACUATION OF UNIT 3 AND 4 • IMPORT FROM MAHARASHTRA THROUGH 220 KV D/C KOLHAPUR-BELGAUM IS MORE STABLE

  32. CLOSING OF 220KV BALIMELA-UPPER SILERU S/C LINE USL-BLM LETTER GRID MAP OF AP GRID MAP OF GRIDCO STUDY FOR EVACUATION

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