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Largest sized hydro unit (180 MW at Chamera) in the country
Salient FeaturesNorthern Regional Power System
Welcome
UNUSUAL
GRID OPERATING CONDITIONS
LOAD FORECASTING
T SRINIVASMANAGERSRLDC
MAIN COMPONENTS OF THE GRID
GENERATION
LOAD
TRANSMISSION NETWORK
DETAILS
PERFORMANCE INDICES
SYSTEM FREQUENCY
SYSTEM VOLTAGE
HEALTH OF TRANSMISSION NETWORK
SYSTEM RESERVES & REDUNDANCY
CAPABILITY TO OVERCOME A CONTINGENCY
MAIN FUNCTIONS OF A GRID CONTROL ROOM
Load Generation Balance
Merit Order Operation
Inter-regional/Intra-regional Exchanges
Maintenance of Grid Security
System Restoration/Revival
LOAD GENERATION BALANCE
Load Curves of Northern Region for Typical Summer & Winter Season
16000
17000
18000
19000
20000
21000
22000
23000
24000
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24
Hours
MW
Summer Summer high hydro Winter
11000
13000
15000
17000
19000
21000
23000
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24
HOUR ---->
DE
MA
ND
IN
MW
--->
TYPICAL LOAD CURVE OF SR
WINTER
MONSOON
SUMMER
EVENING PEAK
WEATHERCONSUMPTION
LOAD DIVERSITY
The unique load curve of different identities due to varied nature of load / requirements results in the overall load diversity.
Why Load forecasting?
Load forecasting helps an electric utility to make important
decisions including decisions on purchasing
and generating electric power, load switching, and
infrastructure development. Load forecasts are extremely
important for energy suppliers,
ISOs, .nancial institutions, and other participants in electric
energy generation, transmission, distribution, and markets.
Load forecasting Categories
• Short Term Load Forecasting
from one hour to one week
• Medium term Load Forecasting
from a week to a year
• Long term Load Forecasting
longer than a year
States/U.T Demand met Requirement Shortage ShortageMU/Day MU/Day MU/Day %age
Punjab 104.42 113.70 9.28 8.16Haryana 62.31 65.36 3.05 4.67
Rajasthan 69.39 70.91 1.52 2.14U.P. 103.95 131.75 27.80 21.10
Uttranchal 9.79 10.15 0.36 3.54Delhi 63.56 65.68 2.12 3.23H.P 9.22 9.23 0.01 0.11J&K 15.29 18.39 3.10 16.86
Chandigarh 3.72 3.72 0.00 0.00N.F.F./Rail 1.53 1.53 0.00 0.00
Total Region 443.18 490.42 47.24 9.63
Power Supply Position of Northern Region for a Typical Summer Month
Average Energy/day (Net)
States/U.T Demand met Requirement Shortage ShortageMU/Day MU/Day MU/Day %age
Punjab 63.89 68.00 4.11 6.04Haryana 44.21 48.00 3.79 7.90
Rajasthan 68.38 69.79 1.41 2.02U.P. 104.92 130.00 25.08 19.29
Uttranchal 10.79 11.00 0.21 1.91Delhi 52.49 56.16 3.67 6.53H.P 9.30 9.50 0.20 2.11J&K 18.72 20.00 1.28 6.40
Chandigarh 2.85 2.85 0.00 0.00N.F.F./Rail 1.91 1.91 0.00 0.00
Total Region 375.52 417.21 41.69 9.99
Average Energy/day (Net)
Power Supply Position of Northern Region for a Typical Winter Month
Max. Max.States/U.T Demand met Requirement Shortage Shortage
MW MW MW %ageA B D (D/B)*100
Punjab 5281 5691 410 7.20Haryana 3325 3411 86 2.52
Rajasthan 3610 3610 0 0.00U.P. 5626 6685 1059 15.84
Uttranchal 681 771 90 11.67Delhi 3101 3347 246 7.35H.P 505 505 0 0.00J&K 938 1160 222 19.14
Chandigarh 206 206 0 0.00N.F.F./Rail 75 75 0 0.00
Region 21767 24092 2325 9.65Diversity Factor= 1.07
Peak MW
Power Supply Position of Northern Region for A Typical Summer Month
Max. Max.States/U.T Demand met Requirement Shortage Shortage
MW MW MW %ageA B D (D/B)*100
Punjab 3582 3582 0 0.00Haryana 2647 2981 334 11.2Rajasthan 3535 3535 0 0.00U.P. 5018 6228 1210 19.43Uttranchal 680 695 15 2.16Delhi 3042 3367 325 9.65H.P 696 696 0 0.00J&K 939 1200 261 21.75Chandigarh 145 145 0 0.00N.F.F./Rail 75 75 0 0.00Region 20109 22040 1931 8.76Diversity Factor = 1.07
Peak MW
Power Supply Position of Northern Region for A Typical Winter Month
G1 G2
SERC
SLDCSEB/STU
State Govt.
RLDC
REB
CTU
CERC
Central Govt. CEA
ISTS
ISGS
Load
L1 L2
Intra State System
IEGC to Operate on the periphery
X= - GL G
DEMAND ESTIMATION
DEMAND ESTIMATION
Availability = Own Generation (+) Entitlement from Grid (+) Bilaterals
DEMAND ESTIMATION
IEGC Chapter –6Para 6.3 Sub-Para 6.3.3Each State / SLDC shall develop methodologies / mechanisms for estimation (MW, MVAR and MWH) for operational purposes. The data for estimation shall also include Load Shedding, Power Cuts etc. SLDCs shall also maintain Historical Database for Demand Estimation.
DEMAND ESTIMATION
Load Restriction = Demand (Requirement)(Load shedding)
(-) Availability
ENTITLEMENTS = Fixed Shares + Unallocated Shares
FIXED SHARES
Allocation to States from the Central Sector Stations in terms of Percentages which generally remain fixed.
UNALLOCATED SHARES
Allocation to States from Central Sector Stations in terms of Percentages which are changed on seasonal basis and / or under typical conditions as decided by Govt. of India.
NTPC & NAPP
Chandigarh 5.00Delhi 25.00Haryana 26.00H.P. 0.00J & K 8.00Punjab 16.00Rajasthan 20.00U.P. 0.00Uttranchal 0.00Total 100.00
State Constituent
ALLOCATION FROM UNALLOCATED QUOTA OF ISGS TO CONSTITUENTS OF NORTHERN REGION
0.000.00
UNALLOCATED (%)
RAPP "B"
0.00100.00
0.00100.00
0.000.000.000.00
Gross Ex- busStation Installed Installed
Capacity Capacity Total Peak Off peak Peak Off peak
(MW) (MW) (2000 hrs) (0300 hrs) (2000 hrs) (0300 hrs)Singrauli 2000 1835 11.25 1835 1835 206 206Rihand 1000 910 13.75 910 910 125 125Dadri (T) 840 760 90.00 760 760 684 684Unchahar-I 420 380 6.90 380 380 26 26Unchahar-II 420 380 14.94 380 380 57 57Anta 419 406 14.26 380 380 54 54Auraiya 663 643 13.46 587 587 79 79Dadri (G) 830 805 12.73 800 800 102 102NTPC TOTAL 6592 6120 6033 6033 1334 1334
NAPS 440 385 14.31 363 363 52 52RAPS#3 220 198 15.00 200 200 30 30RAPS#4 220 198 35.00 200 200 70 70NPC TOTAL 880 781 763 763 152 152
Baira Siul 180 178 11.10 178 119 20 13Salal 690 683 11.62 653 653 76 76Tanakpur 94 93 12.81 89 89 11 11Chamera 540 535 7.90 535 356 42 28Uri 480 475 11.04 475 475 52 52NHPC TOTAL 1984 1964 1931 1693 202 181TOTAL 9456 8865 8726 8488 1688 1667
` ENTITLEMENT FROM CENTRAL SECTOR 1688 1667PURCHASE FROM UTTRANCHAL UNDER BILATERAL AGREEMENT(THRU PTC) 150 150PURCHASE FROM U.P. UNDER BILATERAL AGREEMENT 100 100PURCHASE FROM H.P. UNDER BILATERAL AGREEMENT 379 379PURCHASE FROM PTC UNDER BILATERAL AGREEMENT (WBPDCL POWER) 100 100ONE THIRD SHARE OF HARYANA IN IP UNIT # 2,3 & 4 -12 -12SALE TO PUNJAB UNDER BILATERAL AGREEMENT (0000-0930 HRS.) 0 -300SALE TO HARYANA UNDER BILATERAL AGREEMENT (0000-1000 HRS.) 0 -200SALE TO M.P. THROUGH PTC (0000-0800 HRS.) 0 -200TOTAL BILATERAL EXCHANGES 717 17NET ENTITLEMENT FROM GRID 2405 1684TRANSMISSION LOSSES ( @ 2.00 %) -48 -34NET DRAWAL SCHEDULE FROM GRID AT STATE'S PERIPHERY 2356 1650
NOTE: 1. Badarpur generation, which is totally allocated to Delhi, is taken as within Delhi's system. 2.Delhi has been allocated 25% from unallocated quota of central sector.
Entitlement
ENTITLEMENT OF DELHI FROM CENTRAL GENERATION DURING SUMMER 2003
Actual Ex- busPlant Availability (MW)
Delhi's Ex- busEntitlement (MW)
Delhi's Power Sourcing Composition During Summer 2003
1000
1400
1800
2200
2600
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24
Hours
MW
NTPC (1334 MW)
NPC (152 MW)
NHPC (181 to 202 MW)
Net sch. at state's periphery (1650-2356 MW)
BILATERAL = (17 to 717 MW)
1650
1334
1486
1688
1667
2356
IMPORT = 729 MWEXPORT = -712 TO -12 MW
AGRICULTURE SUPPLY TIMINGS : PUNJAB
GROUP – ANIGHT (2000 - 0600 Hrs) 10 Hrs
Avg.DAY (2100 - 0500 Hrs) 16 Hrs
Avg.(0800 - 1600 Hrs)
GROUP – BNIGHT (2000 - 0600 Hrs) 10 Hrs
Avg.DAY (2100 - 0500 Hrs) 16 Hrs
Avg.(0800 - 1600 Hrs)
GROUP – C (BORDER AREAS)(0800 - 1800 Hrs) 10 Hrs
Avg.
STATE AVG. 12.40 HrsGroups are Rotated on Weekly Basis
LOAD DESPATCHING
Barring the period, 1800 – 2200 Hrs, Supply is given in any seven hour stretch as decided by the respective zone. The segregation / Load Staggering is done at zonal level and monitored closely.
State Avg. 7 Hrs.
AGRICULTURE SUPPLY TIMINGS : RAJASTHAN
AGRICULTURE SUPPLY TIMINGS : HARAYANA
GROUP – I (2200 - 0500 Hrs) 9 Hrs
Avg. (0800 - 0900 Hrs)
(1600 - 1730 Hrs)
GROUP – II (0900 - 1600 Hrs) 7 Hrs
Avg.
AMBALA, KARNAL, KURUKSHETRA, SONEPAT, YAMUNANAGAR, JIND & SIRSA :
AGRICULTURE SUPPLY TIMINGS : HARAYANA
GROUP – I (2200 - 0600 Hrs) 10
Hrs Avg. (0800 - 0900 Hrs)
(1630 - 1730 Hrs)
GROUP – II (0800 - 1600 Hrs) 8 Hrs
Avg.
State Avg. 8.5 Hrs.Groups are rotated on weekly basis
SINGLE CROP AREAS COMPRISING BHIWANI, NARNAUL, GURGAON, ROHTAK & FARIDABAD CIRCLE :
CONTROL AREAS
CS - 1 CS - 3
CS - 2
SEB-B SEB-C
STATE
DISTR - A DISTR - C
DISTR - B
SEB's GRIDSLDCCOORDINATES/DIRECTS
SEB-A
COORDINATES/RLDC
REGIONAL GRID
IPP
STATEGENR.
SHARECENTRAL
AGENCIES PARTICIPATING IN THE SCHEDULING PROCESS OF NORTHERN
REGION
NTPC
1. Singrauli2. Rihand3. Unchahar4. Dadri (Th)5. Dadri (GF)6. Dadri (LF)7. Anta (GF)8. Anta (LF)9. Auraiya
(GF)10. Auraiya
(LF)
NHPC
1. Bairasiul2. Salal3. Tanakpur4. Chamera-
15. Chamera-
26. Uri
NPC
1. NAPS2. RAPS –
33. RAPS - 4
Others
1. NJPC
AGENCIES PARTICIPATING IN THE SCHEDULING PROCESS OF NORTHERN
REGION
BBMB
1. Bhakra2. Dehar3. Pong
STATES
1. Punjab2. Haryana3. Rajasthan4. Delhi5. Uttar Pradesh6. Uttaranchal7. Himachal
Pradesh8. Jammu
Kashmir9. U.T.
Chandigarh
OTHERS
1. Eastern Region
2. Western Region
3. Railways4. NFF
AGENCIES PARTICIPATING IN THE SCHEDULING PROCESS OF NORTHERN
REGION
Generating Stations =23
States = 9
Others = 4 (+)
SCHEDULING AND DESPATCH PROCEDURE ALL ISGS STATIONS WITH CAPACITIES AND ALLOCATED SHARES TO BE LISTED OUT BY 1000 HRS EACH ISGS ADVISES RLDC OF ITS EX-POWER PLANT MW AND MWH CAPABILITIES ANTICIPATED FOR NEXT DAY i.e. 00:00 TO 24:00 HRS BY 1100 HRS BENEFICIARIES ADVISED OF ABOVE INFORMATION ALONG WITH THEIR ENTITLEMENTS BY 1500 HRS SLDCs ADVISE RLDC THEIR DRAWAL SCHEDULE FOR EACH OF THE ISGS IN WHICH THEY HAVE SHARE BY 1700 HRS RLDC CONVEYS THE 'EX-POWER PLANT DESPATCH SCHEDULE (IN MW)' TO EACH ISGS AND 'NET DRAWAL SCHEDULE (IN MW)' TO EACH BENEFICIARY (AFTER DEDUCTING TRANSMISSION LOSSES) RLDC TO ENSURE SCHEDULES ARE OPERATIONALLY REASONABLE WITH RESPECT TO RAMPING UP/RAMPING DOWN RATES AND THE MINIMUM TO MAXIMUM RATIO OF GENERATION.
SCHEDULING AND DESPATCH PROCEDURE (Contd.) ISGS/SLDCs TO INFORM ANY MODIFICATIONS IN FORESEEN CAPABILITY/STATION WISE DRAWAL SCHEDULE TO RLDC BY 2200 HRS. RLDC TO ISSUE FINAL SCHEDULE IN SUCH CASES BY 2300 HRS. REVISIONS IN SCHEDULE PERMITTED DURING THE COURSE OF THE DAY. SUCH REVISIONS EFFECTIVE ONE HOUR AFTER THE FIRST ADVISE IS RECEIVED BY THE RLDC. RLDC TO CHECK FOR TRANSMISSION CONSTRAINTS, IF ANY, BEFORE FINALISING THE DRAWAL/DESPATCH SCHEDULE. ON COMPLETION OF THE OPERATING DAY, SCHEDULE, AS FINALLY IMPLEMENTED DURING THE DAY SHALL BE ISSUED BY RLDC. THIS WOULD BE THE DATUM FOR COMMERCIAL ACCOUNTING. RLDC TO PROPERLY DOCUMENT ALL THE ABOVE INFORMATION EXCHANGED BETWEEN ISGS AND RLDC, CONSTITUENTS AND RLDC ETC. ALL RECORDS IN RESPECT OF ABOVE OPEN TO ALL CONSTITUENTS FOR ANY CHECKING/VERIFICATION FOR A PERIOD OF 20 DAYS.
Time Schedule of interaction between ISGS, SLDCs and NRLDC for Scheduling
Time Interaction Purpose
A. Day ahead Scheduling:
By 1000 hrs ISGS to NRLDCAvailability forecast, time-wise for next day
By 1100 hrs NRLDC to SLDCsAnticipated ISGS wise entitlement for the next day
By 1500 hrs SLDCs to NRLDCISGS wise requisition, demand, bilateral arrangements etc. anticipated for the next day
By 1700 hrs NRLDC to ISGS/ SLDCsFinal generation schedule to ISGS & net drawal schedule to SLDCs for the next day
By 2200 hrs Any ISGS/ SLDC to NRLDCChanges in availability/ requisition, if any for the next day
By 2300 hrs NRLDC to all ISGS/ SLDCsRevised final generation schedule to ISGS & net drawal schedule to SLDCs respectively for the next day
B. Running day Scheduling:
Any time “a” Any ISGS/ SLDC to NRLDCChanges in availability / requisition, if any for rest of the day
Within next one and half hour of “a”
NRLDC to all ISGS/ SLDCsRevised generation schedule to ISGS & net drawal schedule to SLDCs respectively for rest of the day
ISGS: Inter State Generating StationsSLDC: State Load Despatch Centre
MERIT ORDER OPERATION
Components of inter-utility tariff(Pre – ABT Mechanism)
Fixed charges Interest on loans Depreciation O & M charges Return on equity Interest on Working Capital
Energy charges (fuel cost) Incentives Surcharge & other levies No charge for reactive energy
TENTATIVE COST FOR NTPC THERMAL STATIONS FOR THE MONTH OF JUNE 2002
Station
Fixed Cost Rs. Cr/yr
(1)
Average Fixed Cost Rs. Cr/day
(2)
Average Fixed Cost P / KWh
(3)
Variable Base Cost P / KWh
(4)
Variable FPA P / KWh
(5)
Total Variable Base Cost P / KWh
(6)
Composite Cost P / KWh
(3) + (6)
Singrauli 325.90 0.905 21.47 37.05 34.03 71.08 92.55
Rihand 478.74 1.330 65.83 34.29 37.29 71.58 137.41
Unchahar – I 221.71 0.616 73.00 55.83 58.53 114.36 187.36
Anta GPS 92.92 0.258 47.13 60.55 31.79 92.34 139.47
Auraiya GPS 160.20 0.445 42.17 61.92 65.64 127.56* 169.73
Dadri GPS 221.04 0.614 34.26 68.58 67.99 136.57* 170.83
Dadri (T) 416.78 1.158 76.97 90.56 61.71 152.27 229.24
Unchahar – II --- --- --- 235.00 -9.04 225.96 225.96
Payment to Inter State Generating Stations (ISGS) from beneficiaries
under Availability Based Tariff (ABT)
Capacity chargesEnergy chargesUnscheduled Interchange (UI)
1000
900
800
700
600
500
400
300
200
100
0
0 2 4 6 8 10 12 14 16 18 20 22 24
Forecast ex-bus capability of Power Plant
Hours
MW
Net Injection Schedule
SEB - A's Requisition
SEB - A's Entitlement - (40% )
SCHEDULING
Energy Charges (paise/kwh) for Central Sector stations (June 2002 level)
Sl. No. Power Station Rate (Paise / KWh)
1. Salal 54.59
2. Tanakpur 54.59
3. Singrauli 65.22
4. Rihand 68.63
5. Anta/Auraiya/Dadri GT 95.00
6. Unchahar 105.00
7. Dadri (Thermal) 146.25
FREQUENCY vs UI PRICE
0
28
56
84
112
140
168
196
224
252
280
308
336
364
392
420
448
51
50.9
50.8
50.7
50.6
50.5
50.4
50.3
50.2
50.1 50
49.9
49.8
49.7
49.6
49.5
49.4
49.3
49.2
49.1 49
48.9
48.8
48.7
48.6
48.5
FREQUENCY
PA
ISE
/UN
IT
49 HZ
50.5 HZ
49.5 HZ
50 HZ
49.5 HZ CORRESPONDS TO RS.2.80
UI PRICE AND FREQUENCY
Percentage of time frequency remained within the IEGC band (49.0-50.5 Hz) in Northern Region
60
65
70
75
80
85
90
95
100
December January February March April May June July August September October November
Perc
enta
ge o
f tim
e
pre-ABT
post-ABT
Singrauli & Rihand
2555
2530
2491 25
05
2200
2300
2400
2500
2600
2700
Pre ABT(Dec 01-Nov 02) Post ABT(Dec 02-Nov 03)
Av
era
ge
MW
Declared Capability Injection Schedule
Unchahar-1 & 2
691
687
599
653
500
550
600
650
700
750
Pre ABT(Dec 01-Nov 02) Post ABT(Dec 02-Nov 03)
Ave
rag
e M
W
Declared Capability Injection Schedule
Dadri (T)
711
640
619
717
500
550
600
650
700
750
800
Pre ABT(Dec 01-Nov 02) Post ABT(Dec 02-Nov 03)
Ave
rag
e M
W
Declared Capability Injection schedule
Anta, Auraiya & Dadri
1478
1336
1330
1636
1100
1200
1300
1400
1500
1600
1700
1800
Pre ABT(Dec 01-Nov 02) Post ABT(Dec 02-Nov 03)
Ave
rag
e M
W
Declared Capabilty Injection Schedule
Schedules as percentage of Declared Capability (DC)
97.5%
86.7%
89.9% 90.4%
99.0%
95.0%
86.3%
81.3%
75.0%
80.0%
85.0%
90.0%
95.0%
100.0%
105.0%
Pithead Unchahar-I +II Dadri (T) Combined cycle ISGS
pre-ABT (Dec 01-Nov 02)
post-ABT (Dec 02-Nov 03)
Minimum voltage recorded at Dadri 400 kV bus
330
340
350
360
370
380
390
400
Volta
ge
in k
V
pre-ABT min. voltage post-ABT min. voltage
INTER REGIONAL EXCHANGES
HCDC Sasaram B-B
HCDC Vindhyachal B-B
HCDC Gazuaka B-B
HCDC Talcher Kolar
HCDC Chandrapur B-B
Inter Regional HVDC Links
IMPORT (MW) 450TIME (Hrs) 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23
10
140
TIME (Hrs) 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23
450 450
100 MW (ISGS Allocations 0000 to 2400 hrs)
100 MW {WBPDCL (ER ) to J & K 0000 to 2400 hrs}-PTC
450 450
10 MW (ER to HVPNL 0000 to 1700 hrs & 2300 to 2400 hr)-NVVNL
INTER REGIONAL EXCHANGE BETWEEN ER & NR ON SASARAM HVDC BACK TO BACK LINK
50 MW (GRIDCO to DTL)-NVVNL
100 MW (ER to HVPNL 0000 to 1700 hrs & 2300 to 2400 hrs)-PTC 100
140 MW {ER (DVC, WBSEB,GRIDCO) to DTL 0000 to 2400 hrs}-PTC200 MW
100 MW ISGS Allocations 0000 to 2400 hrs
100 MW WBSEB to J&K 0000 to 2400hrs- PTC
50 MW GRIDCO to DTL-NVVNL
140 MW WBSEB to DTL 0000 to 2400-PTC
100 MW DVC to HVPNL 0000 to 1700 & 2300 to 2400 hrs-PTC
10 MW GRIDCO to HVPNL 0000 to 1700 & 2300 to 2400 hrs-NVVNL
440
10050 MW DVC to DTL-
PTC
450 450 450 450
1 2 3 4 5 6 7 8FROM
ISGS WB DVC WB GRIDCO DVC WB TOTAL
PERIODTO
DTL DTL J & K DTL RRVPNL RRVPNL
PTC PTC PTC NVVN PTC PTC
00:00 01:00 100 100 100 100 400
01:00 02:00 100 100 100 100 400
02:00 03:00 100 100 100 100 400
03:00 04:00 100 100 100 100 400
04:00 05:00 100 100 100 100 400
05:00 06:00 100 150 100 100 450
06:00 07:00 100 150 100 100 450
07:00 08:00 100 150 100 100 450
08:00 09:00 100 150 100 100 450
09:00 10:00 100 150 100 100 450
10:00 11:00 100 150 100 100 450
11:00 12:00 100 150 100 100 450
12:00 13:00 100 150 100 50 50 450
13:00 14:00 100 150 100 50 50 450
14:00 15:00 100 150 100 50 50 450
15:00 16:00 100 150 100 50 50 450
16:00 17:00 100 150 100 50 50 450
17:00 18:00 100 150 50 100 400
18:00 19:00 100 150 50 100 400
19:00 20:00 100 150 50 100 400
20:00 21:00 100 150 50 100 400
21:00 22:00 100 150 50 100 400
22:00 23:00 100 150 50 100 400
23:00 24:00 100 150 100 350
INTER REGIONAL BILATERAL EXCHANGES (IMPORT) OF POWER IN NR THROUGH SASARAM
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TIME (Hrs) 0 1 2 3 4 6 7 8 9 10 11 13 14 15 16 18 19 20 21 22 23
TIME (Hrs) 0 1 2 3 4 6 7 8 9 10 11 13 14 15 16 18 19 20 21 22 23
50
250
50 50 150
100 200 100450 250 50
150
IMPORT
IMPORT
EXPORT
150 MW (Goa to DTL)- GEL150 MW
(Goa to DTL)- GEL
5 12 17
125
INTER REGIONAL EXCHANGE BETWEEN NR & WR ON VINDHYACHAL HVDC BACK TO BACK LINK
EXPORT
17
50 MW
100 MW
200 MW
200 MW ( 0000-0600 hrs) (DTL to MP)- PTC
200 MW100 MW
200
DTL to Gujrat- PTC0000 - 0500, 1200-1730, 2300-2400
(DTL to Chattisgarh)-PTC0000 - 0530 hrs
DTL to CSEB2300-2400 hrs
1 2 3 4 5 6FROM
WB DVC GRIDCO GRIDCO DVC TOTAL
PERIODTO
RRVPNL RRVPNL DTL DTL RRVPNL
PTC PTC PTC NVVN PTC
00:00 01:00 50 50
01:00 02:00 50 50
02:00 03:00 50 50
03:00 04:00 50 50
04:00 05:00 50 50
05:00 06:00 50 50
06:00 07:00 100 100 100 50 350
07:00 08:00 100 100 100 50 350
08:00 09:00 100 100 100 50 350
09:00 10:00 100 100 100 50 350
10:00 11:00 100 100 100 50 350
11:00 12:00 100 100 100 50 350
12:00 13:00 50 50 100
13:00 14:00 50 50 100
14:00 15:00 50 50 100
15:00 16:00 50 50 100
16:00 17:00 50 50 100
17:00 18:00 0
18:00 19:00 0
19:00 20:00 0
20:00 21:00 0
21:00 22:00 0
22:00 23:00 0
23:00 24:00 50 50
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SYSTEM SECURITY
TOTAL 1800-2200 MW
WESTWARD FLOW DURING WINTER NIGHTS
WEST SIDE BBMB
SYSTEM (PUNJAB,
HARAYANA,H.P.,J&K,
CHD) (SIZE 6000 MW)
EAST SIDE
DELHI /U.P./ RAJASTHAN
SYSTEM (SIZE 9000
MW)
400 kV Dadri Panipat(400-500 MW)
400 kV Bawana-Hissar(300-450 MW)
400 kV Bawana-Abdullapur(100-200 MW)
220 kV Ballabhgarh-Ch. Dadri(100-150 MW)
220 kV Khetri-Hissar (00-50 MW)
400 kV Bassi-Hissar(100-150 MW)
400 kV Bawana-Bhiwani(350-500 MW)
220 kV Samaypur-Ch. Dadri (100-150 MW)
220 kV Khetri-Ch. Dadri D/C (50-100 MW)
400 kV Dadri-Malerkotla(200-300 MW)
ECONOMY OF REQUISITIONING FROM GAS STATIONS ON LIQUID FIRING
Energy Charges (Liquid Firing)
Anta Rs. 3.20 /unit
Auraiya Rs. 3.00 /unit
Dadri Rs. 5.00 /unit(approx)
UI Rates
49.5 Hz Rs. 2.80
49.4 Hz Rs. 3.08
49.3 Hz Rs. 3.36
49.2 Hz Rs. 3.64
49.1 Hz Rs. 3.92
49.0 Hz & Below Rs. 4.20
Tariff Regulation – Economy and Efficiency vis-à-vis Security
Under Requisition vis-à-vis Overdrawal of Haryana (during the period when f<49.5Hz)
3776
11085
40 27 9
276 278
975
800
312
97118
0.00
200.00
400.00
600.00
800.00
1000.00
1200.00
06.10.2003 07.10.2003 08.10.2003 09.10.2003 10.10.2003 11.10.2003 12.10.2003
MW
Hr
Under Requisition Overdrawal
Under Requisition vis-à-vis Overdrawal by Rajasthan (during the period when the f < 49.5 Hz)
46
91
258
144129
105
2628
293
610
176
384
287
67
0.00
100.00
200.00
300.00
400.00
500.00
600.00
700.00
06.10.2003 07.10.2003 08.10.2003 09.10.2003 10.10.2003 11.10.2003 12.10.2003
MW
Hr
Underrequisition Overdrawal
Ex-Bus Capacity under requisitioned / underutilised in Gas and Nuclear stations (during the week 6th Oct to 12th Oct 2003)
121 121 121 128 126 123 128
60 59 60 60 50 60 58
91 91 96 96 100 96 96
113 113 114 120 124 121 116
180 180 180180 180 180 175
0
100
200
300
400
500
600
700
06.10.2003 07.10.2003 08.10.2003 09.10.2003 10.10.2003 11.10.2003 12.10.2003
Me
ga
wa
tts
Dadri (L) Anta (L) Aurya (L) NAPS RAPS
On 9th Oct 2003 f < 49.0 Hz = 1.56 % of time f < 49.5 Hz = 15.35 % of time f < 50.0 Hz = 81.01 % of time f < 50.5 Hz = 99.90 % of time
Thank You
FREQUENCY RESPONSE IN BHAKRA RIGHT UNIT 1 ON 23.10.2003
50.17
50.10
50.4850.37
50.20147
149
124
137
160
49.00
49.20
49.40
49.60
49.80
50.00
50.20
50.40
50.60
50.80
51.00
7:4
0:0
0
7:4
1:0
0
7:4
2:0
0
7:4
3:0
0
7:4
4:0
0
7:4
5:0
0
7:4
6:0
0
7:4
7:0
0
7:4
8:0
0
7:4
9:0
0
7:5
0:0
0
7:5
1:0
0
7:5
2:0
0
7:5
3:0
0
7:5
4:0
0
7:5
5:0
0
7:5
6:0
0
7:5
7:0
0
7:5
8:0
0
7:5
9:0
0
8:0
0:0
0
TIME
Her
tz
122
127
132
137
142
147
152
157
162
Meg
awat
ts
FREQUENCY BHAKRA RIGHT 1
AVG. NO. OF AGREEMENTS PER MONTH
11.25
7.5
0
1
2
3
4
5
6
7
8
9
10
11
12
PRE ABT POST ABT
TOTAL ENERGY TRADED (MU)
3550.12
5146.59
0
1000
2000
3000
4000
5000
6000
PRE ABT POST ABT
NR BILATERAL AGREEMENTS
SOUTHERN REGIONAL GRID▀ Centre Generating Stations in the Region are
• Ramagundam Super Thermal Power Stn. : 2,600 MW (200x3 + 500x4)
• Neyveli Lignite Corporation Ltd. - II : 1,470 MW (210 x 7)
• Madras Atomic Power Station : 390 MW (170 x 1 + 220X1)
• Kaiga Atomic Power Station : 440 MW (220x2)
• NLC EXPANSION TPS 1 : 420 MW (210X2)
• TALCHER STAGE II : 2000 MW (500X4) situated
in ER▀ Beneficiaries in southern Region are
. ANDHRA PRADESH
• KARNATAKA• KERALA• TAMIL NADU• Union Territory of Pondicherry• NLCMINES• GOA has share of 100MW from RSTPS
CONTROL AREAS
REGIONAL GRID
SEB’S GRID
CS -3CS - 2
CS - 1
CENTRALSHARE
STATEGENR
STATEIPP
DISTR-B
DISTR- A
DISTR- C
SEB - A SEB -CSEB -B
SLDCCOORDINATESDIRECTS
RLDCCOORDINATES