2. Indian Power System
For the purpose of grid management and energy
accounting, the Indian Power system is divided into Five
Regional Grids –
Northern Region
Western Region
Eastern Region
North Eastern Region
Southern Region
5. Indian Power System
Sector
Hydro
STATE
25067.6
PRIVATE
1306.2
CENTRAL
7887
TOTAL
34260.7
Installed Capacity as on 30-09-2007
(Figures in MW)
Thermal
Wind/ RES
Coal
Gas
Diesel Total
Nuclear
/SHP
Total
39431 3759.8 604.6 43795.4
0
2084
70947
4491.4
4183 597.1 9271.5
0
8091 18668.7
28260
5899
0 34159
4120
0
46166
72182.4 13841.8 1201.8 87226
4120
10175 135781.7
Thermal
Wind/ RES/
Region
Hydro
Coal
Gas Diesel Total Nuclear
SHP
Total
NORTHERN 12671.1 18193.5 3433.2
15 21641.7
1180
1220.2
36713
WESTERN
7003.5 23635.2 5860.8
17.5 29513.5
1840
2670.3 41027.3
SOUTHERN 10646.2 15972.5 3586.3 939.3 20498.1
1100
5899.3 38143.7
EASTERN
2823.9 13996.2
190
17.2 14203.4
0
227.8 17255.1
N.EASTERN
1116
385
771.5 142.7 1299.2
0
146.1
2561.2
ISLANDS
0
0
0
70
70
0
11.4
81.4
ALL-INDIA
34260.7 72182.4 13841.8 1201.8
87226
4120
10175 135781.7
Installed capacity does not include benefits from projects in Bhutan
6. Power Supply Position National
(April 07 – Nov 07)
Peak
Region
Deman
MW
NORTHERN 32462
WESTERN 37955
SOUTHERN 26054
EASTERN 11385
NORTH1657
EASTERN
Peak Peak Deficit / Energy Energy Energy Deficit/
Met
Surplus Requir Availa Surplus
MW MW % MU MU MU %
29495 -2967 -9.10% 147720 135962 -11758 -8%
27852 -10103 -26.60% 155108 134701 -20407 -13.20%
24194 -1860 -7.10% 122152 119075 -3077 -2.50%
10669 -686 -6% 50494 48503 -1991 -3.90%
1347 -310 -18.70% 5932 5285 -647 -10.90%
7. INTER STATE FLOWS AT PEAK HOUR WHEN ISGS DESPATCH IS FULL
ER ISGS
BHADRAWATI HVDC
GAZUWAKA HVDC 143 MW
Ramagundam
2480 MW
APTRANSCO SYSTEM
TALCHER-KOLAR HVDC
TALCHER STG II
1640 MW
3 Nos. 400 kV lines &
2 Nos 220 kV lines
ENT: 1728 MW
6 Nos. 400 kV lines &
2 Nos 220 kV lines
895 MW
MAPS Nuclear
265 MW
585 MW
Goa
95 MW
TNEB SYSTEM
KPTCL SYSTEM
ENT: 1385 MW
KAIGA Nuclear
450 MW
1480MW
ENT: 2185 MW
940 MW
25 MW
262
MW
Pondy
NEYVELI II
NEY EXP
1642 MW
4 Nos. 400 kV lines &
1 Nos 220 kV line
KSEB SYSTEM
ENT: 965 MW
4 Nos. 400 kV lines &
3 Nos 230 kV line
8. Installed capacity of Southern Region
as on 30-04-2007
Sector
State Private Central
Total
Hydro
10956.3 55.45
11011.7
Coal
7572.5
510
8090 16172.5
Gas
735.8 2500.5
350 3586.3
Diesel
362.52 576.8
939.32
Thermal total
8670.82 3587.3
8440 20698.1
Nuclear
1100
1100
Renewable
557.5 4414.1
4971.55
Total
20184.6 8056.8
9540 37781.4
17.
Load Generation Balance(LGB) preparation
Demand Forecasting
Scheduling of Central share
Power Purchase
Outage Planning
Preparation of Daily System Statistics
Functions of LD centers
18. Constraints in merrit order
Availability from hydal restricted on
account of water availability
Naphtha based generation – Technical
limits are stringent.
Minimum generation from hydro.
Time required for bringing in thermal
generation.
Advantage of KSEB – Higher hydro.
19. Major problems existed in Indian grid
operation
Low frequency during peak load hours, with frequency going down
to 48.0-48.5 Hz for many hours every day.
High frequency during off peak hours, with frequency going up to
50.5 to 51 Hz for many hours every day.
Rapid and wide changes in frequency – 1 Hz change in 5 to 10
minutes, for many hours every day.
Very frequent grid disturbances, causing tripping of generating
stations, interruption of supply to large blocks of consumers, and
disintegration of the regional grids.
One important reason attributed to the situation was the absence
of direct incentives or penalties for the individual utilities
responsible for the problems.
21. Introduction to ABT
Availability based tariff is implemented in the
Southern Region with effect from 1-1-2003.
Implementation of ABT can be considered as a
landmark in the process of power sector
reforms in the country.
Concept of performance based rate making
and bench marking of operational standards.
This approach helped to induce the regulated
entities under this regime to significantly
improve their performance and reduce
operational costs.
22.
The earlier bulk tariff system recognised the
total cost as consisting of two elements,
namely capacity cost and energy cost. Both
the fixed cost and the variable cost of a
generating station were charged to the
beneficiaries in proportion to the actual
energy drawn by them during that period.
The ABT enables dispatch of power in
relation to a schedule, given by every
beneficiary based on the availability of
allocated shares of Central generating
stations, and other power that might be
available. It enables penal tariffs to be
charged when any utility or generating
company acts against the grid discipline.
23.
ABT is a three part tariff
◦ Capacity charges (Fixed cost)
◦ Energy charges (Variable cost)
◦ UI charges
Capacity charges and energy charges are settled
monthly as per the Regional energy Account.
UI charges are settled weekly
Energy accounts are prepared and issued by the
Southern Regional Power Committee Secretariat
TARIFF STRUCTURE
24. Capacity Charges
The capacity charge is paid for the
entitlement from each generating station.
The entitlement includes the share allotted to
each constituent, as per the Gadgil formula,
special allocations and allocation by the
ministry of power issued time to time from
the unallocated portion.
This payment is affected by the availability of
the generating station. If the availability is
lesser than the target availability fixed, the
capacity charges payable will also be less.
25. Energy Charges
The energy charge is for the energy
scheduled from the generating station.
CERC has fixed the heat rate and the
variable cost for each generating station
under central sector.
Whether the constituent has drawn the
entire scheduled energy or whether the
generating station has generated as per
the schedule does not matter in this case.
26. Unscheduled Interchange (UI)
The UI is the difference between the
schedule
and
the
actual
drawal/
generation.
After
many deliberations in various
forums, CERC has admitted a time block
consisting of 15 minutes as the basis for
energy accounting.
In contrast to the capacity charges and
energy charges, the UI bills are issued
and settled weekly.
27. What is UI?
UI – Unscheduled interchange
Demand of the grid is not constant
Frequency of the grid is not constant
Depending on various conditions, the
tie
line flow varies from instant to instant
Thus UI is unavoidable in an integrated
network
UI can be harnessed effectively to the
advantage of the constituents if system
permits
Rate depends on frequency
28. UI Rate corresponding to different
frequencies from 07.01.2008
Frequency
Less than
49.12
49.22
49.32
49.42
49.52
49.62
49.72
49.82
49.92
50.02
50.12
50.22
50.32
50.42
Abov
e
49.0
49.1
49.2
49.3
49.4
49.5
49.6
49.7
49.8
49.9
50.0
50.1
50.2
50.3
50.4
50.5
Rate Rs.
10.00
9.10
8.20
7.30
6.40
5.50
4.60
3.70
2.80
2.40
2.00
1.60
1.20
0.80
0.40
0.00
18ps/0.02Hz for freq less than 49.8
8ps/0.02Hz for freq more than 49.8
33. Merit order Dispatch 2
UI
Rs.2.50
300MW
Rs.7.50
Hydel
280MW
900MW
Rs.1.50
220MW
300MW
Reduced
generation
from hydro
200MW
Rs.6.50
900MW
Load
1700MW
Technical
minimum
Hydel reduced when frequency increased
34. Merit order Dispatch 3
UI
Rs.8.50
300MW
Rs.7.50
Hydel
550MW
150MW
220MW
-120MW
Maximum
generation
possible
900MW
Rs.1.50
200MW
Rs.6.50
900MW
Load
1700MW
Technical
limitations
in change
of
generation
Export when frequency reduces
35. Merit order Dispatch 4
UI
Rs.8.50
300MW
Rs.7.50
Hydel
550MW
150MW
300MW
-200MW
Maximum
generation
possible
900MW
Rs.1.50
200MW
Rs.6.50
900MW
Load
1700MW
Continuous
low
frequency
expected
Export when frequency reduces
36. Merit order Dispatch 5
UI
Rs.0.50
300MW
Rs.7.50
Hydel
200MW
200MW
Rs.6.50
900MW
Rs.1.50
700MW
220MW
580MW
Minimum
generation
possible
Load
1700MW
Surrendere
d to
Technical
minimum
Technical
minimum
Maximum import at very high frequency
37. VAR Rates
Payable @5 ps/KVARH For
. VAR injection at Voltages above
103% of rated voltage
.VAR drawal at Voltages below 97%
of rated voltage
Receivable @5 ps/KVARH For
. VAR drawal at Voltages above 103%
of rated voltage
. VAR injection at Voltages below
97% of rated voltage
38. Mechanism of ABT
The commercial mechanism of the ABT contemplates
the disciplining of all three entities in the grid viz., the
generator, transmitter and the beneficiaries.
The commercial mechanism is a self regulated
discipline and binding on all concerned, as opposed to
a regulator-imposed discipline.
The UI charges in the ABT mechanism combined with
payment of capacity cost on availability basis,
facilitates the marketing of both capacity and energy
on a continuous basis, and enforcement of grid
discipline.
The term "Availability Based Tariff" is appropriate, as
it reflects all elements of capacity made available as
well as capacity utilised.
39. FREQUENCY COMPARISION OF 2003 AND 2002 ( 18TH WEEK)
2002
2003
51.50
51.00
50.00
49.50
49.00
48.50
48.00
DAY OF THE WEEK
Sun:00:00
Sat:00:00
Fri:00:00
Thu:00:00
Wed:00:00
Tue:00:00
47.50
Mon:00:00
FREQUENCY IN HZ
50.50
40. Jan-02
TIME IN HRS ---->
Jan-03
23:00
22:00
21:00
20:00
19:00
18:00
17:00
16:00
15:00
14:00
13:00
12:00
11:00
10:00
9:00
8:00
7:00
6:00
5:00
4:00
3:00
2:00
1:00
0:00
VOLTAGE IN KV --->
COMPARISON OF BANGALORE VOLTAGE FOR 14TH JAN
420
410
400
390
380
370
360
350
340
330
320
41. 30th and 31st July 2012-northern grid-620
million people (9% of world population)22 states out of 28 were out-32 GWrailways, roadways and airports.
MEERWAD not affected-solar-off grid14kW
Effects of summer-over drawal
Political speculations
BIGGEST OUTAGE AFTER ABT
IMPLEMENTATION (after 2001)
42.
Inadequate response of SLDCs to instructions
of the RLDC to reduce the drawal.
High loading of the 400kV Bina-Gwalior-Agra
link.
Weak inter regional power transmission
corridors due to multiple outages.
Encourage off grid operations-Micro grids –
Renewables
More peak load power stations
HVDC links – asynchronous operation
Spot settlement of UI
Distribution and transmission privatization.
BIGGEST OUTAGE AFTER ABT
IMPLEMENTATION (INVESTIGATIONS)
43. Nuclear
power Plants to be brought
under ABT
Timely UI payment to be enforced
Formation of Power Exchange
Implementation of Intra state ABT
IPPS, SEB, DISCOMs and Captives
ABT-FUTURE
