section 7.5 –4 – ii of indian electricity grid code (iegc): “the summation of station-wise...
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Section 7.5 –4 – ii of Indian Electricity Grid code (IEGC): “The summation of station-wise ex-power plant drawal schedules for all ISGS after deducting the apportioned transmission losses (estimated), shall constitute the state-wise drawal schedule.”
The need for estimation of losses
Importance
• Wide difference in estimated & actual transmission losses would lead to huge mismatch in Un-scheduled Interchange (UI) payable & receivable.
• Losses also assume importance while scheduling open access customers.
Estimation of transmission losses for scheduling including inter-regional exchanges
Estimation of transmission losses for scheduling including inter-regional exchanges
• Transmission loss signifies the power lost while transferring the same from the
generator(s) to the load.
• In the context of scheduling under the Availability Based Tariff (ABT), generators above would mean the Inter- State Generating Stations (ISGS) while the load would mean the State drawals at their respective peripheries.
Estimation of transmission losses for scheduling (contd/-)
Region Peak ISGS generation (typical)
MW (% of peak)
Peak demand met
MW
North 9800 (46.7) 21000
East 3000 (35.3) 8500
West 5600 (25.5) 22000
South 3500 (18.4) 19000
Estimation of Transmission losses for scheduling (contd/-)
1. Through power flow studies (one day in advance)
- Accurate but complex as different conditions have to be envisaged. Further state level generation/load data required.
2. Based on average actual pooled losses calculated from net drawal of constituents & net injection of ISGS for previous weeks using Special Energy Meter (SEM) data.
- Simple and easy to implement.
Following to be kept in mind:
• Changes in load & Generation pattern over the time. (averaged actual losses will be more realistic if pattern does not change drastically)
Estimation of Transmission losses for scheduling (contd/-)
• In the Northern Region, the transmission losses for the ISGS portion varies by as
much as 1 to 1.5% within the day on account of variations in BBMB and ISGS hydro stations.
• However, the average transmission losses day-wise does not vary much during the
entire week except in situations like closure of hydro stations due to flushing of reservoir or forced outages.
Estimation of Transmission losses for scheduling (contd/-)
• It is suggested that we gradually move to the power flow study method to estimate the
losses for the purpose of day-ahead scheduling as it is more scientific.
• In case a clear pattern of losses is noticed in the course of the entire day, we could go in for a time block-wise figure of estimated losses.
Estimation of Transmission losses for scheduling (contd/-)
• Inter-regional exchanges through an intervening region
What should be the approach followed for the transmission losses in the intervening region?
Should it be the pooled loss percentage or the incremental loss approach?
Estimation of Transmission losses for scheduling (contd/-)
• Inter-regional exchanges through an intervening region (contd/-)
Incremental loss method, although scientific is not desirable as the base case itself varies from time to time.
In case of open access customer, the last set of customers may be at a disadvantage, if incremental transmission losses are levied.
Estimation of transmission losses for scheduling (contd/-)
• Inter-regional exchanges through an intervening region (contd/-)
• Pooled loss approach would be more simpler initially and more transparent.
• Later as we move to the system study method for loss estimation and as we
gain experience in respect of open access customers, we could move to the
incremental loss approach.
NRLDC Charges and Fees -Status
Annual Amount Approved by CERC for 2003-04
Rs. 652.70 Lacs
Monthly bill raised Rs. 54.766 Lacs
Payment Received from All constituents except J&K *
*J&K has opened LC for Rs. 5 Cr/ month while its average transmission & RLDC (4.5 Lacs) bills are in range of 7.0 Cr.
• For April & May 2002 Bills (Rs. 1437050 +Interest) raised on DVB, are not realised (time of unbundling of DVB)
Sl.No. Head Budgeted (2003-04)
Rs.
Actual (upto 30 Sep 2003) Rs.
1. Employee Cost 293.25 150.10
2. R&M 56.55 9.87
3. Power Charges 62.04 25.12
4. Training & Rect. - -
5. Print & Stationery 2.00 1.50
6. Rent - -
7. Misc. 7.50 2.81
8. Insurance 0.07 -
9. Share of Office Exp. - -
10. Communication Exp. 52.35 4.79
11. Traveling Charges 20.00 10.60
12. Hiring of Vehicle 8.62 3.97
13. Depreciation & Corporate Expense allocation.
Percentage of time frequency remained within the IEGC band (49.0-50.5 Hz) in Northern Region
81.7 80.8
72.4 72.5
77.8
70.468.8
71.7
80.679.3
83.4
88.0
79.3
84.481.7
85.888.8 88.7
82.5
91.489.5
97.5
60
65
70
75
80
85
90
95
100
Perc
enta
ge o
f tim
e
pre-ABT
post-ABT
Bilateral trading of power in Northern Region
7 11
2927.97
4483.73
0
500
1000
1500
2000
2500
3000
3500
4000
4500
5000
Pre-ABT(Dec 01-Sep 02) Post-ABT(Dec02-Sep 03)
Nu
mb
er o
f b
ilat
eral
ag
reem
ents
/ E
ner
gy
Tra
ded
Average no.of Agreements/monthTotal Energy Traded (million units)
FREQUENCY PROFILE OF NORTHERN REGION
48.0
48.5
49.0
49.5
50.0
50.5
51.0
51.5
52.0
0:00
:00
1:00
:00
2:00
:00
3:00
:00
4:00
:00
5:00
:00
6:00
:00
7:00
:00
8:00
:00
9:00
:00
10:0
0:00
11:0
0:00
12:0
0:00
13:0
0:00
14:0
0:00
15:0
0:00
16:0
0:00
17:0
0:00
18:0
0:00
19:0
0:00
20:0
0:00
21:0
0:00
22:0
0:00
23:0
0:00
24:0
0:00
Time
29-Oct-2002
48.0
48.5
49.0
49.5
50.0
50.5
51.0
51.5
52.0
29-Oct-2003
Fre
qu
ency
(H
z)
Energy traded in Northern Region
ABT: Availability Based TariffThe Unscheduled Interchange (UI) market is also of the order of 500 MU every month
Generation above schedule by NTPC Stations in NR for freq. > 50.3 Hz
70741
10767
138319
7580
38806
2508
2468013637
0
20000
40000
60000
80000
100000
120000
140000
160000
Pre-ABT(Dec01-Oct02) Post-ABT(Dec02-Oct03)Ext
ra g
ener
atio
n a
bo
ve 5
0.3
Hz
(MW
h) Pit head
Unchahar-1&2Dadri (T)Combined Cycle
Backing down by NTPC Stations in NR for freq. > 50.3 Hz
29247
46521
19552 1982214736
18858
60348
35839
0
10000
20000
30000
40000
50000
60000
70000
Pre-ABT(Dec01-Oct02) Post-ABT(Dec02-Oct03)
Bac
kin
g d
ow
n a
bo
ve 5
0.3
Hz
(MW
h) Pit head
Unchahar-1&2Dadri (T)Combined Cycle
Generation above schedule by NTPC Stations in NR for freq. < 49.5 Hz
120759
20617
72462
18258
390962679026371
92153
0
20000
40000
60000
80000
100000
120000
140000
Pre-ABT(Dec01-Oct02) Post-ABT(Dec02-Oct03)
Ext
ra g
ener
atio
n b
elo
w 4
9.5
Hz
(MW
h)
Pit headUnchahar-1&2Dadri (T)Combined Cycle