*

AVAILABILITY BASED TARIFF An Overview

Dr. S. K. Agrawal, General Manager, POWERGRID

Kathmandu : April 1, 2009

Energy Transmission Partnership on the Cross Border Exchange of Electricity

SKA*Chronological Sequence of Implementation of ABT

1990 : K. P. Rao Committee Proposed Two Part Tariff structure consisting of Fixed and Variable charges1993-94 : A structured study by M/s ECC, USA, funded by ADB, sponsored by WB as a covenant of loans to POWERGRID Availability Based Tariff (ABT)1995-98 : NTF / RTFs, formed for ABT implementation. 1999 : Matter transferred to CERC : Hearings etc.2000 : CERC Order, but stayed due to petitions2001-02 : Problems of regional grid operation continued : Many intractable commercial disputes also arose2002-03 :ABT implemented successfully.

SKA

*Outline of the presentationNeed for ABTABT conceptHow UI pricing works?Amendments to UI ratesPayment of capacity & Energy ChargesMany dimensions of UI mechanismSettlement system and logisticsImpact of ABTLimitations and way ahead

*Conditions when ABT was conceivedGrid indiscipline No respect for schedule by generating stations as well as beneficiary SEBsPoor Frequency regime Low frequency during peak periods, high frequency during off-peak periodsReasonPerverted incentives in the tariff regime at that time Recover of capacity charges based on PLF and no differential payment for deviations from schedule

SKA*ABC of ABTFrequency actuated signalSignal transmitted at the speed of dynamics to be controlledQuasi-steady state assumption not validReal time pricing stretched to its physical limitsMerit orderEconomic load managementIncentives for helping the gridOpportunities for a diligent playerSimple, dispute-free weekly settlement system

SKA

SKA*Deviations from Schedule - UI

SKA

SKA*DECENTRALIZED SCHEDULINGAvailability Declaration (DC)EntitlementsSLDC

Requisition & Bilateral AgreementsInjection ScheduleDrawal ScheduleRevision in DCRevision in RequisitionFinalInjection ScheduleFinalDrawal ScheduleRLDCISGSTimeRevisions duringCurrent dayRevisions duringCurrent day0 to 24 hours

09:00 10:0015:0017:0022:0023:00

SKA

SKA*

SKA

Chart1

10001000

10001000

10001000

10001000

10001000

10001000

10001000

10001000

10001000

10001000

10001000

10001000

10001000

10001000

10001000

10001000

10001000

10001000

10001000

10001000

10001000

10001000

10001000

10001000

10001000

10001000

982982

964964

946946

928928

910910

892892

874874

856856

838838

820820

802802

784784

766766

748748

730730

712712

694694

676676

658658

640640

622622

604604

586586

568568

550550

532532

514514

496496

478478

460460

442442

424424

406406

388388

370370

352352

334334

316316

298298

280280

272272

264264

256256

248248

240240

232232

224224

216216

208208

200200

192192

184184

176176

168168

160160

152152

144144

136136

128128

120120

112112

104104

9696

8888

8080

7272

6464

5656

4848

4040

3232

2424

1616

88

00

050.52

050.54

050.56

050.58

050.6

050.62

050.64

050.66

050.68

050.7

050.72

050.74

050.76

050.78

050.8

050.82

050.84

050.86

050.88

050.9

050.92

050.94

050.96

050.98

051

Unscheduled Interchange (UI) Rate Applicable only for deviations from contract in real-time

280

Surplus condition in the Grid

Deficit Condition in the Grid

Signal to use all available generating resources else reduce energy consumption

signal to serve more consumer if possible else save fuel by reducing generation

UI Rate wef 07th Jan 2008

UI Rate wef 07th January 2008

Frequency (HZ)--->

Rate(Paise/KWH)--->

Balancing Market guiding Vector

Sheet1

48.51000

48.521000

48.541000

48.561000

48.581000

48.61000

48.621000

48.641000

48.661000

48.681000

48.71000

48.721000

48.741000

48.761000

48.781000

48.81000

48.821000

48.841000

48.861000

48.881000

48.91000

48.921000

48.941000

48.961000

48.981000

491000

49.02982

49.04964

49.06946

49.08928

49.1910

49.12892

49.14874

49.16856

49.18838

49.2820

49.22802

49.24784

49.26766

49.28748

49.3730

49.32712

49.34694

49.36676

49.38658

49.4640

49.42622

49.44604

49.46586

49.48568

49.5550

49.52532

49.54514

49.56496

49.58478

49.6460

49.62442

49.64424

49.66406

49.68388

49.7370

49.72352

49.74334

49.76316

49.78298

49.8280

49.82272

49.84264

49.86256

49.88248

49.9240

49.92232

49.94224

49.96216

49.98208

50200

50.02192

50.04184

50.06176

50.08168

50.1160

50.12152

50.14144

50.16136

50.18128

50.2120

50.22112

50.24104

50.2696

50.2888

50.380

50.3272

50.3464

50.3656

50.3848

50.440

50.4232

50.4424

50.4616

50.488

50.50

50.520

50.540

50.560

50.580

50.60

50.620

50.640

50.660

50.680

50.70

50.720

50.740

50.760

50.780

50.80

50.820

50.840

50.860

50.880

50.90

50.920

50.940

50.960

50.980

510

Sheet2

Sheet3

*Concept of ABTCapacity (fixed) Charge recovery of generator linked to AvailabilityCapacity charges payable by beneficiary based on capacity allocatedEnergy (variable) charges based on scheduled energyA third component known as Unscheduled Interchange (UI) charge is levied for deviation from the schedulesRate of UI Charge is based on frequencySettlement period of 15 minutesApplicability - Central Generating Stations and drawal from the grid by beneficiaries

*Unscheduled Interchange (UI)For Generating StationUI = Actual generation - Scheduled generation

For beneficiary (getting supply from grid)UI = Total actual drawal - Total scheduled drawal

*Kink at 49.8 HzNormal Operating Band specified in IEGC

*How UI pricing works -High FrequencyExample: Generating Stations

Sheet1

Generating Station

AB

Energy Charge (INR /Kwh) =1.040.88

Frequency(Hz) =50.2

UI Rate (INR /Kwh)=1.2

Gain (Paise/ KWh) for generation below schedule =0.160.32

Conclusion:

Generating station A should srart reducing generation if frequency rises beyond the level at which UI rate is 1.04 INR/KWh i.e. 50.24 Hz

Generating station B should start reducing generation if frequency rises beyond the level at which UI rate is 88 INR/KWh i.e. 50.28 Hz

Frequency (Hz) =50.1

UI Rate (Paise /Kwh)=112

Variable cost of costliest operating generating station owned by the beneficairy (Paise /Kwh)=

120

Loss (Paise/ KWh) for each unit of own generation8

Conclusion:

Beneficiary should start reducing generation at the costliest operating station (and overdraw from the grid) if variable cost of this station exceed prevailing UI Rate..

Frequency (Hz) =49.849.5

UI Rate (Paise /Kwh)=196280

Variable cost of the cheapest hot standby generating resorrce owned by the beneficairy (Paise /Kwh)=

150

Loss (Paise/ KWh) for each unit of own generation-46

Conclusion:

Beneficiary should start generation at the cheapest hot standby unit at a frequency dips to a value at which UI rate becomes equal to variable cost of this unit.

Beneficiary should start loadshedding if UI rate is high and there is no standby generating resource.

Frequency (Hz) =49.4

UI Rate (Paise /Kwh)=308

Variable cost of the generating station despatched below availability or having margins295

Gain by generating over the schedule (Paise /KWh)13

Conclusion:

A generating station under ABT should, if feasible, start generating above schedule if frequency dips to a level at which UI Rate is equal to its variable cost.

Sheet2

Sheet3

*How UI pricing works -Low FrequencyExample: Generating Station

Sheet1

Generating Station

AB

Energy Charge (paise /Kwh) =9070

Frequency(Hz) =50.250.28

UI Rate (Paise /Kwh)=8461.6

Earning (Paise / KWh) for over generation =-6-8.4

Conclusion:

Generating station A should not generate over schedule beyond the frequency at which UI rate is 90 aise/KWh i.e. 50.18 Hz

Generating station B should not generate over schedule beyond the frequency at which UI rate is 70 aise/KWh i.e. 50.25 Hz

Frequency (Hz) =50.1

UI Rate (Paise /Kwh)=112

Variable cost of costliest operating generating station owned by the beneficairy (Paise /Kwh)=

120

Loss (Paise/ KWh) for each unit of own generation8

Conclusion:

Beneficiary should start reducing generation at the costliest operating station (and overdraw from the grid) if variable cost of this station exceed prevailing UI Rate..

Frequency (Hz) =49.849.5

UI Rate (Paise /Kwh)=196280

Variable cost of the cheapest hot standby generating resorrce owned by the beneficairy (Paise /Kwh)=

150

Loss (Paise/ KWh) for each unit of own generation-46

Conclusion:

Beneficiary should start generation at the cheapest hot standby unit at a frequency dips to a value at which UI rate becomes equal to variable cost of this unit.

Beneficiary should start loadshedding if UI rate is high and there is no standby generating resource.

Frequency (Hz) =49.8

UI Rate (INR /Kwh)=2.8

Energy charge of the generating station despatched below availability or having margins2.4

Gain by generating over the schedule (INR /KWh)0.4

Conclusion:

This generating station should, if feasible, start generating above schedule if frequency dips below the level at which UI Rate is equal to its energy charge i.e. 49.9 Hz.

Sheet2

Sheet3

*How UI pricing works -High FrequencyExample: Beneficiary

Sheet1

Generating Station

AB

Energy Charge (paise /Kwh) =9070

Frequency(Hz) =50.250.28

UI Rate (Paise /Kwh)=8461.6

Earning (Paise / KWh) for over generation =-6-8.4

Conclusion:

Generating station A should not generate over schedule beyond the frequency at which UI rate is 90 aise/KWh i.e. 50.18 Hz

Generating station B should not generate over schedule beyond the frequency at which UI rate is 70 aise/KWh i.e. 50.25 Hz

Frequency (Hz) =50.1

UI Rate (INR /Kwh)=1.6

Variable cost of costliest operating generating station owned by the beneficairy (INR /Kwh)=

2.4

Gain (INR/ KWh) for drawal above schedule (by reducing generation at own costiliest station)0.8

Conclusion:

Beneficiary should start reducing generation at the costliest operating station (and overdraw from the grid) if variable cost of this station exceed prevailing UI Rate.

Frequency (Hz) =49.849.5

UI Rate (Paise /Kwh)=196280

Variable cost of the cheapest hot standby generating resorrce owned by the beneficairy (Paise /Kwh)=

150

Loss (Paise/ KWh) for each unit of own generation-46

Conclusion:

Beneficiary should start generation at the cheapest hot standby unit at a frequency dips to a value at which UI rate becomes equal to variable cost of this unit.

Beneficiary should start loadshedding if UI rate is high and there is no standby generating resource.

Frequency (Hz) =49.4

UI Rate (Paise /Kwh)=308

Variable cost of the generating station despatched below availability or having margins295

Gain by generating over the schedule (Paise /KWh)13

Conclusion:

A generating station under ABT should, if feasible, start generating above schedule if frequency dips to a level at which UI Rate is equal to its variable cost.

Sheet2

Sheet3

*How UI pricing works -Low FrequencyExample: Beneficiary

Sheet1

Generating Station

AB

Energy Charge (paise /Kwh) =9070

Frequency(Hz) =50.250.28

UI Rate (Paise /Kwh)=8461.6

Earning (Paise / KWh) for over generation =-6-8.4

Conclusion:

Generating station A should not generate over schedule beyond the frequency at which UI rate is 90 aise/KWh i.e. 50.18 Hz

Generating station B should not generate over schedule beyond the frequency at which UI rate is 70 aise/KWh i.e. 50.25 Hz

Frequency (Hz) =50.1

UI Rate (Paise /Kwh)=112

Variable cost of costliest operating generating station owned by the beneficairy (Paise /Kwh)=

120

Loss (Paise/ KWh) for each unit of own generation8

Conclusion:

Beneficiary should start reducing generation at the costliest operating station (and overdraw from the grid) if variable cost of this station exceed prevailing UI Rate..

Frequency (Hz) =49.949.4

UI Rate (INR /Kwh)=2.4390

Variable cost of the cheapest standby generating resource owned by the beneficairy (INR /Kwh)=2

Loss (Paise/ KWh) for each unit of drawal above schedule (and not harnessing own standby generation)0.4

Conclusion:

The distribution licensee should start generation at the cheapest standby unit if frequency dips below the value (50 Hz in this case) at which UI rate becomes equal to variable cost of this unit.

The distribution licensee should start loadshedding if UI rate is beyond its means and there is no standby generating resource.

Frequency (Hz) =49.4

UI Rate (Paise /Kwh)=308

Variable cost of the generating station despatched below availability or having margins295

Gain by generating over the schedule (Paise /KWh)13

Conclusion:

A generating station under ABT should, if feasible, start generating above schedule if frequency dips to a level at which UI Rate is equal to its variable cost.

Sheet2

Sheet3

*Changing UI Rates

Chart1

4.265.77.4510

2.8564.083.543.615.68

2.0162.882.192.192.98

0.0560.080.060.060.08

upto 31.03.2004

w.e.f. 01.04.2004

w.e.f. 01.10.2004

w.e.f. 01.04.2007

w.e.f. 07.01.2008

Frequency (Hz)

INR/kWh

Sheet1

HZpaisa/unit

upto 31.03.2004w.e.f. 01.04.2004w.e.f. 01.10.2004w.e.f. 01.04.2007w.e.f. 07.01.2008

49.024.265.77.4510

49.52.8564.083.543.615.68

49.82.0162.882.192.192.98

50.50.0560.080.060.060.08

4.265.77.4510

2.8564.083.543.615.68

2.0162.882.192.192.98

0.0560.080.060.060.08

Sheet2

Sheet3

*Determination of Availability : Thermal StationsAvailability means average of daily Declared Capacities expressed as % of Installed capacity minus Normative Auxiliary ConsumptionDeclaration of capacity taking into account fuel availabilityNormative Availability 80% (exception for some specified generating stations)Availability to be certified by Member Secretary of the RPC concerned.

*Determination of Availability : Hydro StationsCapacity Index (CI) as measure of availabilityDaily CI = (Declared Capacity/Max available capacity)*100Declared capacity over peaking hours of next day (not less than 3 hours each day) taking into account availability of water, optimum use of water and availability of machines. Max. available capacity is the max. capacity in MW the generating station can generate with all units running, under the prevailing conditions of water levels and inflows, over the peaking hours of next day .Normative CI: 90% for Purely Run-of-river (ROR) stations and 85% for Storage and ROR stations with pondageCI to be certified by Member Secretary of the RPC concerned.

*Energy ChargesBased on actually implemented scheduled energyRate for thermal stations based on norms of operationRate for hydro stations equal to lowest energy charge of Central Sector thermal station in the Region

*Mitigation of GamingThermal Stations: up to 105% of DC in time-block and 101% of average DC over the day allowed. Generation beyond these limits to be investigated by RLDC and UI to be made zero if gaming is foundHydro Stations: Schedule prepared for Day 4 (based on DC) is adjusted by deviation from the schedule on Day 1.RLDC may ask generating station to demonstrate DCPenalty for first mis-declaration equals 2 days fixed chargesPenalty to be doubled for 2nd mis-declaration and so on and so forth.

*Multi-dimensional ABTA commercial mechanism for settlement of deviations from the scheduleA commercial mechanism for improving grid discipline and frequency regimeA commercial mechanism to achieve near-merit order operation A default market mechanism for trading

*Settlement of DeviationsAny market liberalized or regulated, needs a mechanism for balancing to take care of imbalances arising out of deviations from contracted schedules.In some markets, there is separate market for balancing.In India, UI mechanism attempts real-time balancing.

*Grid discipline and frequency profilePayment of Capacity Charges based on capacity available rather than energy generated - Avoidance of unwanted generationUI Charges - Load shedding/ increased generation at low frequency and reduction in generation at high frequency

SKA*ABT encourages grid discipline leading to better frequency profile

SKA

*Merit order operation

Strict merit order operation - if generation scheduling is done for all the generating stations in the grid by single entity (Centralized scheduling)In Indian decentralized scheduling system UI Rate encourages: Backing down of generation in decreasing order of variable cost as frequency goes up Picking up of generation in increasing order of variable cost as frequency goes down

*Default market for tradingUnderdrawals with respect to schedule may be viewed as supply to the grid (at UI rate) and vice-versa Similarly, under generation with respect to schedule may be viewed as drawal from the grid (at UI rate)

. UI rate serves as default rate for trading

SKA*Time Line For UI SettlementSettlement weekMonday 0000 Sunday 2400Tuesday2400Meter Data download & receipt at RLDC & preliminary checksThursday 1200Data validation, processing and computation at RLDC. Forwarded to Regional Power Committee SecretariatSaturday2400Data cross checking by Regional Power Committee Secretariat & Issue of Pool Account

Unscheduled Interchange Account Reactive Energy AccountTuesday2400Payment by utilities to the pool account managed by System Operator (RLDC)Tuesday2400Friday 2400Disbursement to utilities from the pool accountThree day grace periodFor Bank processing0.04 % per day interest on defaultersAccount Settled within 21 days Monday 2400

SKA

*Settlement SystemSettlement period- 15 minutesDeclaration, scheduling and UI accounting on 15 minute basisSpecial Energy Meters - for time differentiated measurement of energyEnergy Accounting (capacity and energy charges) - on monthly basisUI accounting on weekly basisUI payments are received in a pool and payments are made from the pool

*LogisticsSEMs installed by CTU (POWERGRID)Meter readings downloaded and sent to RLDCs every week by staff of generating stations, POWERGRID and beneficiariesRLDCs validate and submit data to RPC Secretariat by Thursday noon for the week ending midnight of previous SundayRPC Secretariat to carry out UI charge accounting (weekly basis) and energy accounting (monthly basis)

SKA*01.01.200301.07.200201.04.200301.11.200301.12.2002ABT implemented in All Five Regions.POWERGRID co-ordinated and provided all infrastructure for ABT implementation.

Pool Accounts Operated by RLDCs.

SKA

*Impact of ABT Comparison of frequency profile - Full year after and before ABT

Sheet1

Generating Station

AB

Energy Charge (paise /Kwh) =9070

Frequency(Hz) =50.250.28

UI Rate (Paise /Kwh)=8461.6

Earning (Paise / KWh) for over generation =-6-8.4

Conclusion:

Generating station A should not generate over schedule beyond the frequency at which UI rate is 90 aise/KWh i.e. 50.18 Hz

Generating station B should not generate over schedule beyond the frequency at which UI rate is 70 aise/KWh i.e. 50.25 Hz

Frequency (Hz) =50.1

UI Rate (Paise /Kwh)=112

Variable cost of costliest operating generating station owned by the beneficairy (Paise /Kwh)=

120

Loss (Paise/ KWh) for each unit of own generation8

Conclusion:

Beneficiary should start reducing generation at the costliest operating station (and overdraw from the grid) if variable cost of this station exceed prevailing UI Rate..

Frequency (Hz) =49.849.5

UI Rate (Paise /Kwh)=196280

Variable cost of the cheapest hot standby generating resorrce owned by the beneficairy (Paise /Kwh)=

150

Loss (Paise/ KWh) for each unit of own generation-46

Conclusion:

Beneficiary should start generation at the cheapest hot standby unit at a frequency dips to a value at which UI rate becomes equal to variable cost of this unit.

Beneficiary should start loadshedding if UI rate is high and there is no standby generating resource.

Frequency (Hz) =49.4

UI Rate (Paise /Kwh)=308

Variable cost of the generating station despatched below availability or having margins295

Gain by generating over the schedule (Paise /KWh)13

Conclusion:

A generating station under ABT should, if feasible, start generating above schedule if frequency dips to a level at which UI Rate is equal to its variable cost.

Sheet2

YearFrequncy RangeRegion

NorthernWesternEastern & North-Eastern RegionSouthern

1994-95< 49.0 Hz32.718.913.969.6

> 50.5 Hz #14.316.722.313.5

# > 50.2 in case of Southern Region

1999-00< 49.0 Hz43.826.98.074.4

> 50.5 Hz *12.820.646.54.2

* > 51.0 Hz in case of Eastern Region

RegionPercentage of time when frequency was

< 49.0 Hz49.0 - 50.5 Hz> 50.5

2001-022003-042001-022003-042001-022003-04

Northern11.24.876.289.412.65.8100100

Western31.42.861.689.47.02.410094.6

Southern78.02.317.997.34.10.4100100

2002-032003-042002-032003-042002-032003-04

Eastern13.02.955.795.931.31.2100100

Sheet3

*Impact of ABT Merit order

*Limitations / ConstraintsShortage conditionsRegular and timely payments to UI poolExpectation of rational behabiour from utilities and operating personnelDemand forecastingControl over generation level and demand

SKA*ABC of ABTScientific settlement system for contracted sale & purchase of powerHas three componentsFixed Charges or capacity chargeLinked to day-ahead declared availability / subscriptionVariable Charges or fuel chargesLinked to before the fact energy schedulesCharges for deviation from commitments

SKA

SKA*

SKA

Base UI Status 17-23Sept-ISGS

All India UI Summary of ISGS - Payables (+) / Receivables (-)

For the Period 17th September To 23rd September, 2007

UI Payables (+) / Receivables (-) (in Rs.)UI Payables (+) / Receiables (-) (Rs. in Lakhs)

S. No.RegionName of Org.Name of ISGS

1ERNHPCRANGIT-294081-2.94

2ERNTPCKAHALGAON STPP-2624059-26.24

3ERNTPCTALCHER STPP246247124.62

4ERNTPCFARAKKA STPP-5431810-54.32

5NERNEEPCOKOPILI-II-112096-1.12

6NERNEEPCODOYANG HEP-135880-1.36

7NERNEEPCOKOPILI-504892-5.05

8NERNEEPCOKHANDONG-269087-2.69

9NERNHPCLOKTAK-497353-4.97

10NERNEEPCORANGANADI HEP-1595517-15.96

11NERNEEPCOAGARTALA GAS TPP-903566-9.04

12NERNEEPCOASSAM GAS BPP9151509.15

13NRNHPCTANAKPUR HEP-244102-2.44

14NRNHPCDHAULIGANGA-2059850-20.60

15NRNHPCBAIRASIUL HEP-343793-3.44

16NRNHPCCHAMERA HEP-II-1170785-11.71

17NRNTPCRIHAND STPS-2588468-25.88

18NRNHPCURI HEP-1121943-11.22

19NRNHPCSALAL HEP-2882880-28.83

20NRNTPCUNCHAHAR-I TPS-704690-7.05

21NRTHDCTEHRI HEP-4851745-48.52

22NRNTPCRIHAND-II STPS-988864-9.89

23NRNTPCDADRI GPP925250.93

24NRSJVNLNATHPA JHAKRI-5964496-59.64

25NRNHPCCHAMERA HEP-2241529-22.42

26NRNTPCANTA GPP-4129276-41.29

27NRNTPCUNCHAHAR-II TPS-1778983-17.79

28NRNTPCSINGRAULI STPS-6578621-65.79

29NRNTPCAURAIYA GPP-21430659-214.31

30NRNTPCDADRI TPS-2510866-25.11

31SRNTPCRAMAGUN. STPS STG-III-3834859-38.35

32SRNLCNEYVELI TPS-I (EXPN.)-664290-6.64

33SRNLCNEYVELI TPS-II STG-I-4920041-49.20

34SRNTPCTALCHER STPS-II-30143798-301.44

35SRNLCNEYVELI TPS-II STG-II-3645487-36.45

36SRNTPCRAMAGUN. STPS STG-I & II-2581587-25.82

37WRNTPCKAWAS GPP-2280770-22.81

38WRNTPCVINDHYACHAL STPS # 3-4160533-41.61

39WRNTPCVINDHYACHAL STPS # 1-3342585-33.43

40WRNTPCGANDHAR GPP262430726.24

41WRNTPCVINDHYACHAL STPS # 2-2638244-26.38

42WRNTPCKORBA STPS-5967277-59.67

UI Status 17-23 Sept - ISGS

All India UI Summary of ISGS - Payables (+) / Receivables (-)

For the Period 17th September To 23rd September, 2007

UI Payables (+) / Receiables (-) (Rs. in Lakhs)

S. No.Name of Org.Name of ISGS

1NTPCGANDHAR GPP0.262430726.24

2NTPCTALCHER STPP0.246247124.62

3NEEPCOASSAM GAS BPP0.0915150139.15

4NTPCDADRI GPP0.00925250.93

5NEEPCOKOPILI-II-0.011209558-1.12

6NEEPCODOYANG HEP-0.013587981-1.36

7NHPCTANAKPUR HEP-0.0244102-2.44

8NEEPCOKHANDONG-0.026908712-2.69

9NHPCRANGIT-0.0294081-2.94

10NHPCBAIRASIUL HEP-0.0343793-3.44

11NHPCLOKTAK-0.049735321-4.97

12NEEPCOKOPILI-0.050489156-5.05

13NLCNEYVELI TPS-I (EXPN.)-0.066429-6.64

14NTPCUNCHAHAR-I TPS-0.070469-7.05

15NEEPCOAGARTALA GAS TPP-0.090356627-9.04

16NTPCRIHAND-II STPS-0.0988864-9.89

17NHPCURI HEP-0.1121943-11.22

18NHPCCHAMERA HEP-II-0.1170785-11.71

19NEEPCORANGANADI HEP-0.159551718-15.96

20NTPCUNCHAHAR-II TPS-0.1778983-17.79

21NHPCDHAULIGANGA-0.205985-20.60

22NHPCCHAMERA HEP-0.2241529-22.42

23NTPCKAWAS GPP-0.228077-22.81

24NTPCDADRI TPS-0.2510866-25.11

25NTPCRAMAGUN. STPS STG-I & II-0.2581587-25.82

26NTPCRIHAND STPS-0.2588468-25.88

27NTPCKAHALGAON STPP-0.2624059-26.24

28NTPCVINDHYACHAL STPS # 2-0.2638244-26.38

29NHPCSALAL HEP-0.288288-28.83

30NTPCVINDHYACHAL STPS # 1-0.3342585-33.43

31NLCNEYVELI TPS-II STG-II-0.3645487-36.45

32NTPCRAMAGUN. STPS STG-III-0.3834859-38.35

33NTPCANTA GPP-0.4129276-41.29

34NTPCVINDHYACHAL STPS # 3-0.4160533-41.61

35THDCTEHRI HEP-0.4851745-48.52

36NLCNEYVELI TPS-II STG-I-0.4920041-49.20

37NTPCFARAKKA STPP-0.543181-54.32

38SJVNLNATHPA JHAKRI-0.5964496-59.64

39NTPCKORBA STPS-0.5967277-59.67

40NTPCSINGRAULI STPS-0.6578621-65.79

41NTPCAURAIYA GPP-2.1430659-214.31

42NTPCTALCHER STPS-II-3.0143798-301.44

NET PAYABLES (+)60.9

NET RECEIVABLES (-)-1381.4

SUMMARY OF RECEIVABLES (-) BY ISGS

NAME OF ORG.NET RECEIVABLES (-) (Rs. in Lakhs)

NTPC-1037.15949

NHPC-108.5631621

NEEPCO-35.2103752

NLC-92.29818

SJVNL-59.64496

THDC-48.51745

UI Status 17-23 Sept - Const

All India UI Summary of Constituents - Payables (+) / Receivables (-)

For the Period 17th September To 23rd September, 2007

UI Payables (+) / Receivables (-) (in Rs.)UI Payables (+) / Receiables (-) (Rs. in Lakhs)

S. No.RegionState

1NRUttar Pradesh3587518293587.5235.88358751829

2NRHaryana2532197482532.2025.32253219748

3NRPunjab2243703642243.7022.44224370364

4SRTamilnadu1181941671181.9411.82118194167

5ERBihar88768650887.698.8888768650

6WRMadhya Pradesh58466687584.675.8558466687

7WRDadra & NH47881754478.824.7947881754

8WRMaharashtra41245451412.454.1241245451

9NRChandigarh16473992164.741.6516473992

10ERJharkhand10990562109.911.1010990562

11WRDaman & Diu971280697.130.979712806

12ERSikkim695770469.580.706957704

13NERNagaland519918051.990.525199180

14NERTripura366004236.600.373660042

15SRPondicherry171710217.170.171717102

16NRRajasthan168253616.830.171682536

17SRGoa-SR127961412.800.131279614

18NRJ & K-1602152-16.02-0.16-1602152

19NRDelhi-4080439-40.80-0.41-4080439

20NERAr. Pradesh-4182776-41.83-0.42-4182776

21SRKerala-12051965-120.52-1.21-12051965

22WRChattisgarh-14505602-145.06-1.45-14505602

23NRUttaranchal-15431377-154.31-1.54-15431377

24NERMizoram-18165430-181.65-1.82-18165430

25NERManipur-19517218-195.17-1.95-19517218

26NERMeghalaya-21760457-217.60-2.18-21760457

27WRGoa - WR-22199217-221.99-2.22-22199217

28SRKarnataka-48948907-489.49-4.89-48948907

29NRHP-55613441-556.13-5.56-55613441

30NERAssam-58464292-584.64-5.85-58464292

31ERWest Bengal-64934533-649.35-6.49-64934533

32SRAndhra Pradesh-74199638-742.00-7.42-74199638

33WRGujarat-81680500-816.81-8.17-81680500

34ERDVC-111890129-1118.90-11.19-111890129

35EROrissa-349279831-3492.80-34.93-349279831

NET PAYABLES (+)12485.72

NET RECEIVABLES (-)-9785.08

RE Status 17-23Spt - Const

All India RE Summary of Constituents - Payables (+) / Receivables (-)

For the Period 17th September To 23rd September, 2007

RE Payables (+) / Receivables (-) (in Rs.)RE Payables (+) / Receiables (-) (Rs. in Lakhs)

S. No.RegionState

1NRUttar Pradesh239383723.94

2NRJ & K185583318.56

3NRPunjab126876312.69

4NRHP553300.55

5NERAr. Pradesh144980.14

6NERMizoram97340.10

7NERMeghalaya38820.04

8NERNagaland24800.02

9NERManipur14220.01

10WRDadra & NH00.00

11WRDaman & Diu00.00

12SRGoa-SR00.00

13SRPondicherry00.00

14NRUttaranchal00.00

15ERWest Bengal00.00

16ERSikkim00.00

17ERJharkhand00.00

18ERDVC00.00

19EROrissa00.00

20ERBihar00.00

21NERTripura-800-0.01

22WRGujarat-33768-0.34

23NRDelhi-34230-0.34

24NRChandigarh-37117-0.37

25NERAssam-108495-1.08

26NRHaryana-151841-1.52

27WRGoa - WR-294473-2.94

28SRKerala-871447-8.71

29NRRajasthan-877842-8.78

30WRMadhya Pradesh-1478458-14.78

31WRChattisgarh-1481886-14.82

32WRMaharashtra-2797814-27.98

33SRKarnataka-4080431-40.80

34SRTamilnadu-4579029-45.79

35SRAndhra Pradesh-4836248-48.36

NET PAYABLES (+)56.06

NET RECEIVABLES (-)-216.64

Chart UI Status - ISGS

0.2624307

0.2462471

0.091515013

0.0092525

-0.011209558

-0.013587981

-0.0244102

-0.026908712

-0.0294081

-0.0343793

-0.049735321

-0.050489156

-0.066429

-0.070469

-0.090356627

-0.0988864

-0.1121943

-0.1170785

-0.159551718

-0.1778983

-0.205985

-0.2241529

-0.228077

-0.2510866

-0.2581587

-0.2588468

-0.2624059

-0.2638244

-0.288288

-0.3342585

-0.3645487

-0.3834859

-0.4129276

-0.4160533

-0.4851745

-0.4920041

-0.543181

-0.5964496

-0.5967277

-0.6578621

-2.1430659

-3.0143798

UI Payables (+) / Receivables (-) (in Rs.)

UI Billing (Rs. in Crores)

A Typical Week UI Billing For ISGS ( UI Payables(-) / Receivables (+))

Chart UI Status - Constituents

35.8751829

25.3219748

22.4370364

11.8194167

8.876865

5.8466687

4.7881754

4.1245451

1.6473992

1.0990562

0.9712806

0.6957704

0.519917962

0.36600417

0.1717102

0.1682536

0.1279614

-0.1602152

-0.4080439

-0.418277595

-1.2051965

-1.4505602

-1.5431377

-1.816543025

-1.951721757

-2.176045678

-2.2199217

-4.8948907

-5.5613441

-5.846429208

-6.4934533

-7.4199638

-8.16805

-11.1890129

-34.9279831

UI Payables (+) / Receivables (-) (in Rs.)

UI Billing (Rs. in Crores)

A Typical week UI Bill-Statewise Pattern

Chart RE Status - Constituents

23.93837

18.55833

12.68763

0.5533

0.1449788

0.097335

0.0388206

0.0248031

0.0142191

0

0

0

0

0

0

0

0

0

0

0

-0.0079979

-0.33768

-0.3423

-0.37117

-1.0849472

-1.51841

-2.94473

-8.71447

-8.77842

-14.78458

-14.81886

-27.97814

-40.80431

-45.79029

-48.36248

RE Payables (+) / Receivables (-) (in Rs.)

RE in Rs. in Lakhs

Statewise pattern in terms of RE Payables (+) / Receivables (-) for the week 17 Sept To 23 Sept2007

SKA*

SKA

Base UI Status 17-23Sept-ISGS

All India UI Summary of ISGS - Payables (+) / Receivables (-)

For the Period 17th September To 23rd September, 2007

UI Payables (+) / Receivables (-) (in Rs.)UI Payables (+) / Receiables (-) (Rs. in Lakhs)

S. No.RegionName of Org.Name of ISGS

1ERNHPCRANGIT-294081-2.94

2ERNTPCKAHALGAON STPP-2624059-26.24

3ERNTPCTALCHER STPP246247124.62

4ERNTPCFARAKKA STPP-5431810-54.32

5NERNEEPCOKOPILI-II-112096-1.12

6NERNEEPCODOYANG HEP-135880-1.36

7NERNEEPCOKOPILI-504892-5.05

8NERNEEPCOKHANDONG-269087-2.69

9NERNHPCLOKTAK-497353-4.97

10NERNEEPCORANGANADI HEP-1595517-15.96

11NERNEEPCOAGARTALA GAS TPP-903566-9.04

12NERNEEPCOASSAM GAS BPP9151509.15

13NRNHPCTANAKPUR HEP-244102-2.44

14NRNHPCDHAULIGANGA-2059850-20.60

15NRNHPCBAIRASIUL HEP-343793-3.44

16NRNHPCCHAMERA HEP-II-1170785-11.71

17NRNTPCRIHAND STPS-2588468-25.88

18NRNHPCURI HEP-1121943-11.22

19NRNHPCSALAL HEP-2882880-28.83

20NRNTPCUNCHAHAR-I TPS-704690-7.05

21NRTHDCTEHRI HEP-4851745-48.52

22NRNTPCRIHAND-II STPS-988864-9.89

23NRNTPCDADRI GPP925250.93

24NRSJVNLNATHPA JHAKRI-5964496-59.64

25NRNHPCCHAMERA HEP-2241529-22.42

26NRNTPCANTA GPP-4129276-41.29

27NRNTPCUNCHAHAR-II TPS-1778983-17.79

28NRNTPCSINGRAULI STPS-6578621-65.79

29NRNTPCAURAIYA GPP-21430659-214.31

30NRNTPCDADRI TPS-2510866-25.11

31SRNTPCRAMAGUN. STPS STG-III-3834859-38.35

32SRNLCNEYVELI TPS-I (EXPN.)-664290-6.64

33SRNLCNEYVELI TPS-II STG-I-4920041-49.20

34SRNTPCTALCHER STPS-II-30143798-301.44

35SRNLCNEYVELI TPS-II STG-II-3645487-36.45

36SRNTPCRAMAGUN. STPS STG-I & II-2581587-25.82

37WRNTPCKAWAS GPP-2280770-22.81

38WRNTPCVINDHYACHAL STPS # 3-4160533-41.61

39WRNTPCVINDHYACHAL STPS # 1-3342585-33.43

40WRNTPCGANDHAR GPP262430726.24

41WRNTPCVINDHYACHAL STPS # 2-2638244-26.38

42WRNTPCKORBA STPS-5967277-59.67

UI Status 17-23 Sept - ISGS

All India UI Summary of ISGS - Payables (+) / Receivables (-)

For the Period 17th September To 23rd September, 2007

UI Payables (+) / Receiables (-) (Rs. in Lakhs)

S. No.Name of Org.Name of ISGS

1NTPCTALCHER STPS-II3.0143798301.44

2NTPCAURAIYA GPP2.1430659214.31

3NTPCSINGRAULI STPS0.657862165.79

4NTPCKORBA STPS0.596727759.67

5SJVNLNATHPA JHAKRI0.596449659.64

6NTPCFARAKKA STPP0.54318154.32

7NLCNEYVELI TPS-II STG-I0.492004149.20

8THDCTEHRI HEP0.485174548.52

9NTPCVINDHYACHAL STPS # 30.416053341.61

10NTPCANTA GPP0.412927641.29

11NTPCRAMAGUN. STPS STG-III0.383485938.35

12NLCNEYVELI TPS-II STG-II0.364548736.45

13NTPCVINDHYACHAL STPS # 10.334258533.43

14NHPCSALAL HEP0.28828828.83

15NTPCVINDHYACHAL STPS # 20.263824426.38

16NTPCKAHALGAON STPP0.262405926.24

17NTPCRIHAND STPS0.258846825.88

18NTPCRAMAGUN. STPS STG-I & II0.258158725.82

19NTPCDADRI TPS0.251086625.11

20NTPCKAWAS GPP0.22807722.81

21NHPCCHAMERA HEP0.224152922.42

22NHPCDHAULIGANGA0.20598520.60

23NTPCUNCHAHAR-II TPS0.177898317.79

24NEEPCORANGANADI HEP0.15955171815.96

25NHPCCHAMERA HEP-II0.117078511.71

26NHPCURI HEP0.112194311.22

27NTPCRIHAND-II STPS0.09888649.89

28NEEPCOAGARTALA GAS TPP0.0903566279.04

29NTPCUNCHAHAR-I TPS0.0704697.05

30NLCNEYVELI TPS-I (EXPN.)0.0664296.64

31NEEPCOKOPILI0.0504891565.05

32NHPCLOKTAK0.0497353214.97

33NHPCBAIRASIUL HEP0.03437933.44

34NHPCRANGIT0.02940812.94

35NEEPCOKHANDONG0.0269087122.69

36NHPCTANAKPUR HEP0.02441022.44

37NEEPCODOYANG HEP0.0135879811.36

38NEEPCOKOPILI-II0.0112095581.12

39NTPCDADRI GPP-0.0092525-0.93

40NEEPCOASSAM GAS BPP-0.091515013-9.15

41NTPCTALCHER STPP-0.2462471-24.62

42NTPCGANDHAR GPP-0.2624307-26.24

NET PAYABLES (+)641.2

NET RECEIVABLES (-)679.2

SUMMARY OF RECEIVABLES (-) BY ISGS

NAME OF ORG.NET RECEIVABLES (-) (Rs. in Lakhs)

NTPC344.16291

NHPC108.5631621

NEEPCO26.0588739

NLC92.29818

SJVNL59.64496

THDC48.51745

UI Status 17-23 Sept - Const

All India UI Summary of Constituents - Payables (+) / Receivables (-)

For the Period 17th September To 23rd September, 2007

UI Payables (+) / Receivables (-) (in Rs.)UI Payables (+) / Receiables (-) (Rs. in Lakhs)

S. No.RegionState

1NRUttar Pradesh3587518293587.5235.88358751829

2NRHaryana2532197482532.2025.32253219748

3NRPunjab2243703642243.7022.44224370364

4SRTamilnadu1181941671181.9411.82118194167

5ERBihar88768650887.698.8888768650

6WRMadhya Pradesh58466687584.675.8558466687

7WRDadra & NH47881754478.824.7947881754

8WRMaharashtra41245451412.454.1241245451

9NRChandigarh16473992164.741.6516473992

10ERJharkhand10990562109.911.1010990562

11WRDaman & Diu971280697.130.979712806

12ERSikkim695770469.580.706957704

13NERNagaland519918051.990.525199180

14NERTripura366004236.600.373660042

15SRPondicherry171710217.170.171717102

16NRRajasthan168253616.830.171682536

17SRGoa-SR127961412.800.131279614

18NRJ & K-1602152-16.02-0.16-1602152

19NRDelhi-4080439-40.80-0.41-4080439

20NERAr. Pradesh-4182776-41.83-0.42-4182776

21SRKerala-12051965-120.52-1.21-12051965

22WRChattisgarh-14505602-145.06-1.45-14505602

23NRUttaranchal-15431377-154.31-1.54-15431377

24NERMizoram-18165430-181.65-1.82-18165430

25NERManipur-19517218-195.17-1.95-19517218

26NERMeghalaya-21760457-217.60-2.18-21760457

27WRGoa - WR-22199217-221.99-2.22-22199217

28SRKarnataka-48948907-489.49-4.89-48948907

29NRHP-55613441-556.13-5.56-55613441

30NERAssam-58464292-584.64-5.85-58464292

31ERWest Bengal-64934533-649.35-6.49-64934533

32SRAndhra Pradesh-74199638-742.00-7.42-74199638

33WRGujarat-81680500-816.81-8.17-81680500

34ERDVC-111890129-1118.90-11.19-111890129

35EROrissa-349279831-3492.80-34.93-349279831

NET PAYABLES (+)12485.72

NET RECEIVABLES (-)-9785.08

RE Status 17-23Spt - Const

All India RE Summary of Constituents - Payables (+) / Receivables (-)

For the Period 17th September To 23rd September, 2007

RE Payables (+) / Receivables (-) (in Rs.)RE Payables (+) / Receiables (-) (Rs. in Lakhs)

S. No.RegionState

1NRUttar Pradesh239383723.94

2NRJ & K185583318.56

3NRPunjab126876312.69

4NRHP553300.55

5NERAr. Pradesh144980.14

6NERMizoram97340.10

7NERMeghalaya38820.04

8NERNagaland24800.02

9NERManipur14220.01

10WRDadra & NH00.00

11WRDaman & Diu00.00

12SRGoa-SR00.00

13SRPondicherry00.00

14NRUttaranchal00.00

15ERWest Bengal00.00

16ERSikkim00.00

17ERJharkhand00.00

18ERDVC00.00

19EROrissa00.00

20ERBihar00.00

21NERTripura-800-0.01

22WRGujarat-33768-0.34

23NRDelhi-34230-0.34

24NRChandigarh-37117-0.37

25NERAssam-108495-1.08

26NRHaryana-151841-1.52

27WRGoa - WR-294473-2.94

28SRKerala-871447-8.71

29NRRajasthan-877842-8.78

30WRMadhya Pradesh-1478458-14.78

31WRChattisgarh-1481886-14.82

32WRMaharashtra-2797814-27.98

33SRKarnataka-4080431-40.80

34SRTamilnadu-4579029-45.79

35SRAndhra Pradesh-4836248-48.36

NET PAYABLES (+)56.06

NET RECEIVABLES (-)-216.64

Chart UI Status - ISGS

3.0143798

2.1430659

0.6578621

0.5967277

0.5964496

0.543181

0.4920041

0.4851745

0.4160533

0.4129276

0.3834859

0.3645487

0.3342585

0.288288

0.2638244

0.2624059

0.2588468

0.2581587

0.2510866

0.228077

0.2241529

0.205985

0.1778983

0.159551718

0.1170785

0.1121943

0.0988864

0.090356627

0.070469

0.066429

0.050489156

0.049735321

0.0343793

0.0294081

0.026908712

0.0244102

0.013587981

0.011209558

-0.0092525

-0.091515013

-0.2462471

-0.2624307

UI Payables (+) / Receivables (-) (in Rs.)

UI Billing (Rs. in Crores)

A Typical Week UI Billing For ISGS ( UI Payables(-) / Receivables (+))

Chart UI Status - Constituents

35.8751829

25.3219748

22.4370364

11.8194167

8.876865

5.8466687

4.7881754

4.1245451

1.6473992

1.0990562

0.9712806

0.6957704

0.519917962

0.36600417

0.1717102

0.1682536

0.1279614

-0.1602152

-0.4080439

-0.418277595

-1.2051965

-1.4505602

-1.5431377

-1.816543025

-1.951721757

-2.176045678

-2.2199217

-4.8948907

-5.5613441

-5.846429208

-6.4934533

-7.4199638

-8.16805

-11.1890129

-34.9279831

UI Payables (+) / Receivables (-) (in Rs.)

UI Billing (Rs. in Crores)

A Typical week UI Bill-Statewise Pattern

Chart RE Status - Constituents

23.93837

18.55833

12.68763

0.5533

0.1449788

0.097335

0.0388206

0.0248031

0.0142191

0

0

0

0

0

0

0

0

0

0

0

-0.0079979

-0.33768

-0.3423

-0.37117

-1.0849472

-1.51841

-2.94473

-8.71447

-8.77842

-14.78458

-14.81886

-27.97814

-40.80431

-45.79029

-48.36248

RE Payables (+) / Receivables (-) (in Rs.)

RE in Rs. in Lakhs

Statewise pattern in terms of RE Payables (+) / Receivables (-) for the week 17 Sept To 23 Sept2007

SKA*The End Result .Frequency is collectively controlleddemocratically stabilizedWholesale market is workably competitive allocative efficiencyproductive efficiencyEconomic signal available for optimum utilization of resource investments in generation capacitySettlement isstreamlined dispute-free

SKA

*What lies ahead?Intra-State ABTModulating UI prices according to changing situations

Futuristic ScenarioAdopt operating practices and commercial mechanism for stricter frequency control (when shortages are eliminated?)

SKA*

SKA

SKA*

THANK YOU

SKA

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