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Presentation on Intra-State ABT

Presentation on Intra-State ABT. APTRANSCO,VIDYUTH SOUDHA,HYDERABAD 01 st JULY 2005. by : Power Grid Corporation of India Ltd. Contents. ABT at Regional Level Need for Intra-State ABT Similarities at State Level Options for Market Models Options for UI

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Presentation on Intra-State ABT

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  1. Presentation on Intra-State ABT APTRANSCO,VIDYUTH SOUDHA,HYDERABAD 01st JULY 2005 by : Power Grid Corporation of India Ltd

  2. Contents • ABT at Regional Level • Need for Intra-State ABT • Similarities at State Level • Options for Market Models • Options for UI • Features of Special Energy Meters • Allocations from PPAs • Regulatory Issues • Achievement of Intra-State ABT • Implementation Plan

  3. POWERGRID co-ordinated and provided all infrastructure for ABT implementation. Pool Accounts Operated by RLDCs. 01.11.2003 01.12.2002 01.04.2003 01.07.2002 ABT implemented in All Five Regions. 01.01.2003

  4. AVAILABILITY BASED TARIFF (ABT) Spearheaded by POWERGRID Features: • Unique commercial mechanism linked with frequency. • Fixed Charges i.e. Capacity charges • As per Plant Availability. • Variable Charges i.e. Energy charges • As per Schedule. • Unscheduled Interchange (UI) • Price as per prevailing system frequency

  5. ABT implementation – activities involved • Scheduling (Pre –Despatch Activities) • Real time operation • Settlement System (Post – Despatch Activities)

  6. Scheduling (Pre –Despatch Activities)

  7. SCHEDULING AT SRLDC ISGS MAPS KGS RSTPS NLC STAGE2/1 NLC STAGE2/2 NLC TS1 EXP TALCHER ST2 Legend AVAILABILITY DECLARATION BY ISGS DESPATCH SCHEDULE TO ISGS ENTITLEMENTS FROM ISGSs REQUISITIONFROM ISGSs and STOAs SRLDC DRAWAL SCHEDULE TO BENFICIARIES AP TRANSCO KPTCL TNEB PONDY GOA NLCMINES KSEB BENEFICIARIES

  8. ABT implementation - Pre-Despatch Activities • Day- Ahead Scheduling • Demand forecasting • Availability Declaration – ISGS • Scheduling of ISGSGeneration and Bilaterals • In Southern Region • - 5 ISGS stations • - 10 Notional control areas • - 5 bilateral and inter State open access transactions per day

  9. Real time operation

  10. Settlement System (Post – Despatch Activities)

  11. ABT in SR-----Settlement system • Monthly Accounts for Fixed Charge and Energy Charge payments to ISGS • Weekly Account for UI and Reactive Energy (Monday-Sunday) • Operation of Pool Account by SRLDC • (UI transactions)

  12. METERING LOCATIONS IN SR • Total No Of SEMS in SR USED FOR REA 350 No.s • Total No Of SEMS in APTRANSCO USED FOR REA 127 No.s SR METERING DIAGRAM

  13. INTER STATE LINES METERING LOCATIONS

  14. Intra–State ABT

  15. Intra–State ABT : Power Grid Expertise -Implementation ofIntra-State ABT in Gujarat and Punjab - Preparation of Roadmap for Intra-State ABT in Maharastra - Consultancy Proposals under consideration for other states

  16. Need for intra-State ABT • To empower the utilities to take decisions in their interest. • Management of UI • To identify agencies responsible for Overdrawal / Underdrawal, Overgeneration / Undergeneration resulting in UI payment to regional pool. • Proper Demand forecast and management by DISCOMs • Generation Availability of GENCOs • To establish a framework for bilateral trading at intra-State level • To achieve overall merit order operation.

  17. Issues need to be addressed forintra-State ABT • Identification of entities for intra-State ABT • Metering Arrangements • Scheduling Principles & Procedures • Commercial Principle • Treatment of existing Agreements • Organisational Development • Regulatory Issues

  18. Inter-State ABT Intra-State ABT • Distribution Control Centre –One for each Discom • ISGS: Inter State Generating Stations • SGS: State Generating Stations • CTU: Central Transmission Utility • STU: State Transmission Utility

  19. WR ER Inter-regional Inter-regional ISGS1 Inter-regional Inter-regional APNPDCL ANDHRA PRADESH SGS6 KARNATAKA SGS1 APEPDCL SGS5 CTU STU IST APCPDCL STU IST SGS2 IST CTU TAMILNADU SGS4 KERALA APSPDCL STU ANDHRA PRADESH SGS3 INTER STATE ABT INTRA STATE ABT

  20. Market Models • Option – 1 Single Buyer Model • All the generation including IPPs to be pooled /purchased by residual Electricity Board & all power sale / purchase from other agencies through residual Electricity Board • Option – 2 Multi Buyer Model • All the generation including IPPs to be sold/purchased by DISCOMs directly & all power sale / purchase from other agencies also directly by DISCOMs

  21. External Purchases ISGS Allocations APNPDCL APEPDCL APSPDCL STATE POWER POOL : Single Buyer Model- Option 1 GEN GEN IPP 2 1 3 Power Purchases/Sales GEN IPP 1 2 s APGENCO RESIDUAL EB/TRADECO/HOLDING CO. TO POOL ALL GENERATION THROUGH TRANSCO SYSTEM APCPDCL

  22. STATE POWER POOL : Multiple Buyer Model Option2 ISGS Allocations APNPDCL APEPDCL APSPDCL External Purchases GEN GEN IPP 2 1 3 GEN IPP 1 2 APGENCO TRANSMISSION SYSTEM OF APTRANSCO TRADE CO / HOLDING CO. APCPDCL

  23. Options for UI • UI Rate Curve • Same as inter-state UI-Rate Curve • Higher inter-state UI-Rate Curve • Lower inter-state UI-Rate Curve • Differential Rate Curve ( for injection and drawal of UI) • Different curves for CPPs and other bulk power licensee • Frequency –UI rate curve • Single-slope Curve • Multi-slope Curve

  24. DISCOM-B • DISCOM-A • Case-I • Case-III • Case-II • CPP/ Co-Gen Options for different market participants CPPs/Co-gens

  25. Special Energy Meters&Metering philosophy

  26. Special Energy Meters • 0.2s class of IEC static type. • Works in 3-phase, 4 wire principle • Voltage from 110V secondary side VT and current from CT's of ratio 1A or 5 Amp • In Model-A with 1Amp CT, model-B with 5 Amp CT. • Meter will store the data in the memory for 10 days. • Meter is having a optical port for tapping the stored data by using a hand held unit called DCD (data collection device)

  27. SEM stores the following • Net active energy (wh) in each 15 minute time-block with +/- sign. • Cumulative Wh reading at each mid night. • Average frequency of each 15 minute block with a 2 digit code. • Integrate the reactive energy (VARh) algebrically into two separate registers, one for Vave RMS ≥ 103% and other for Vave RMS ≤ 97%, at each midnight.

  28. SEM displays following • Processor's identification code and model • Date (year month day) • Time (hour min sec) • Cumulative Wh reading • Average frequency of the previous block • Net Wh transmittal during the previous block • Average per unit voltage • Reactive power (VAR) • Voltage – high VARh register reading • Voltage – low VARh register reading

  29. 1 • 1 • 1 Meter 1 Meter 2 Local data collection through Optical Port –as backup Meter 31 DCD DCD

  30. 1 • 1 • 1 Meter 1 Meter 2 AMR System : Through RS485 connection PSTN Modem PSTN Meter 31 Remote Data Collection RS 485 / RS 232 Conv. RS 232 port Local Data Collection

  31. A CASE STUDY CONDUCTED FOR GUJARAT Metering Location Philosphy

  32. Metering Location Philosphy Alternatives: • Metering at actual boundary points (66/11kV Xers) • Metering at 132/66 or 220/66kV Xers • Metering at 220/132 or 220/66kV substations • Metering at notional boundarires

  33. Assessment of Meters/DCDs - Alternatives Alternative 1 : • Discom boundary at 11 kV feeder from 66/11 kV X’ers • Metering at 11 kV side of 66/11 kV Xers. • More meters and data recording at lower voltage level would add to inaccuracies. • Data collection would be exhaustive and unnecessary. Since 66kV network is owned by GETCO, proportionate losses would be borne by all Discoms. • Lot of bulk customers are connected above 11kV and are consumers of Discoms. Metering requirement would be high. • No. of meters exceed 3600 Nos. (incl 20% spares) • No. of DCDs/MTEs would be high

  34. No of meters>3600

  35. Assessment of Meters/DCDs - Alternatives Alternative 2 : • Metering at 66kV side of X’ers of 220/66kV, 132/66kV. • Losses in 66kV transmission network included in actual drawal. • Inter-discom lines 66kV and below to be metered. • Customers connected at 132kV and above to be metered ….? • No. of meters 1195(incl 20% spares) • No. of DCDs 203( incl 20% spares)

  36. No of meters = 1195

  37. Assessment of Meters/DCDs - Alternatives Alternative 3 : • Metering at 220kV side of 220/66kV, 220/132kV X’ers . • Inter-Discom lines at 132kV and below to be metered. • Bulk customers connected at 220kV to be metered. • Losses below 132kV and 66kV network included in the drawal • No. of meters 772 (incl 20% spares) • No. of DCDs 133 (incl 20% spares)

  38. No of meters = 772

  39. Assessment of Meters/DCDs - Alternatives Alternative 4 : RECOMMENDED ALTERNATIVE • Metering at Discom’s boundaries (the network dedicated to Discom) • Metering at GETCO (Dedicated to Discom) – GETCO (dedicated to other discom) • Metering at inter-Discom, Discom-to-Genco, Discom-to-IPP, Discom-to-CPP feeders Advantages • Cost of metering and infrastructure for data communication would reduce drastically. • Losses of dedicated overlayed GETCO network included in Discom drawal, which anyway has to be apportioned. • Losses of common GETCO network shall be pooled. • As such differences between estimated and actual losses becomes negligible. • No. of meters reduces to 614 (incl 20% spares) • No. of DCDs 114 (131 with 20% spares 131)

  40. No of meters = 614

  41. Comparison with 4 Alternatives

  42. Metering Location Philosphy Recommended option : Option 4 • Logical, • cost-effective • easy-to-administer

  43. Allocations from PPAs Options 1. Pro-rata allocation • in the ratio of demands at the time of restructuring. • fixed for complete period of PPA or life of shared generating stations. • Differential allocation based on ‘Capacity to pay’ • More allocation from cheaper power stations to Discoms with higher percentage of low-revenue loads (agriculture/social etc.). • Reviewed at intervals depending on consumer mix of Discoms • Consistent with principles on which consumer tariff is based Recommended: Differential allocation based on ‘Capacity to pay’

  44. Regulatory issues

  45. Regulatory issues • ABT Structure and inter-utility tariff scheme. • Generation Tariff • SERC to notify principles for fixation of tariff for SGS. • Cost-plus • Market based (may be explored in future) If cost-plus tariff, then fixing profit • Return on Equity • Return on Capital Employed • Norms of Operation for SGSs for Thermal & Hydro, Gas, Wind Generators • Target availability • Specific oil consumption • Gross Heat Rate • Auxiliary Power Consumption • Financial Norms for existing and new SGSs • RoE • Interest on Working Capital • Norms for O&M Expenses • Debt:Equity allowed for new power stations • Interest on loan component

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