improving grid discipline through abt.pps
TRANSCRIPT
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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
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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
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*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
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*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
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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
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SKA*Deviations from Schedule - UI
SKA
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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
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SKA*
SKA
Chart1
10001000
10001000
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10001000
10001000
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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
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*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
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*Unscheduled Interchange (UI)For Generating StationUI = Actual generation - Scheduled generation
For beneficiary (getting supply from grid)UI = Total actual drawal - Total scheduled drawal
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*Kink at 49.8 HzNormal Operating Band specified in IEGC
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*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
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*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
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*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
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*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
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*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
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*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.
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*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.
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*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
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*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.
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*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
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*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.
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*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
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SKA*ABT encourages grid discipline leading to better frequency profile
SKA
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*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
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*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
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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
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*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
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*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)
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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
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*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
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*Impact of ABT Merit order
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*Limitations / ConstraintsShortage conditionsRegular and timely payments to UI poolExpectation of rational behabiour from utilities and operating personnelDemand forecastingControl over generation level and demand
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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
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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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