availability based tariff and scheduling mechanism
DESCRIPTION
AVAILABILITY BASED TARIFF AND SCHEDULING MECHANISM. LONG TERM BENEFICIARY CAPACITY ALLOCATION. POWER PURCHASE AGREEMENTS CAPACITY COMMITTMENT. SHORT TERM AGREEMENTS DAY-AHEAD SCHEDULING. REAL-TIME SPOT/BALANCING MARKET. REAL TIME 15 MT BLOCKS. > 5 YEARS. 1-5 YEARS. - PowerPoint PPT PresentationTRANSCRIPT
AVAILABILITY BASED TARIFF
AND
SCHEDULING MECHANISM
THE INDIA ELECTRICITY THE INDIA ELECTRICITY MARKETMARKET
TIME LINETIME LINE
REAL TIME15 MT BLOCKS
LONG TERMBENEFICIARY
CAPACITY ALLOCATION
> 5 YEARS
POWER PURCHASEAGREEMENTS
CAPACITY COMMITTMENT
1-5 YEARS
SHORT TERMAGREEMENTS
DAY-AHEAD SCHEDULING
DAY AHEAD - 3 MONTHS
Components of inter-utility tariffComponents of inter-utility tariff(Pre – ABT Mechanism i.e. the (Pre – ABT Mechanism i.e. the
mechanism used to exist about 5 mechanism used to exist about 5 years back)years back)
Tariff used to consist of the following Tariff used to consist of the following built-in components: built-in components:
Fixed chargesFixed charges- Interest on loans- Interest on loans- Depreciation- Depreciation- O & M charges- O & M charges- Return on equity- Return on equity- Interest on Working Capital- Interest on Working Capital
Energy charges (fuel cost)Energy charges (fuel cost) IncentivesIncentives Surcharge & other leviesSurcharge & other levies No charge for reactive energyNo charge for reactive energy
TENTATIVE COST FOR NTPC THERMAL STATIONS FOR THE MONTH OF JUNE TENTATIVE COST FOR NTPC THERMAL STATIONS FOR THE MONTH OF JUNE 20042004
StationStationFixed Fixed Cost Cost Rs. Rs.
Cr/yrCr/yr
(1)(1)
Average Average Fixed Fixed
Cost Rs. Cost Rs. Cr/dayCr/day
(2)(2)
Average Average Fixed Fixed
Cost P / Cost P / KWhKWh
(3)(3)
Variable Variable Base Base
Cost P / Cost P / KWhKWh
(4)(4)
Variable Variable FPA FPA P / KWh P / KWh
(5)(5)
Total Total Variable Variable
Base Base Cost P / Cost P / KWh (6)KWh (6)
ComposiComposite Cost te Cost
P / P / KWhKWh
(3) + (6)(3) + (6)
RamagundaRamagundamm
486.12486.12 1.3321.332 26.4326.43 82.1482.14 1.061.06 83.2083.20 109.63109.63
Talcher Talcher Stage IIStage II
564.72564.72 1.5471.547 42.9842.98 42.2642.26 3.213.21 45.4745.47 88.4588.45
SingrauliSingrauli 364.59364.59 0.9960.996 28.2728.27 67.9867.98 7.867.86 75.8475.84 104.11104.11
RihandRihand 478.74478.74 1.3301.330 65.8365.83 106.03106.03 44.7044.70 78.9978.99 137.41137.41
Unchahar – Unchahar – II
195.91195.91 0.5350.535 73.3573.35 55.8355.83 6.746.74 112.77112.77 186.12186.12
Anta GPS*Anta GPS* 92.9292.92 0.2580.258 47.1347.13 60.5560.55 84.1184.11 144.66144.66 139.47139.47
Auraiya Auraiya GPS*GPS*
160.20160.20 0.4450.445 42.1742.17 61.9261.92 92.8892.88 154.80154.80 169.73169.73
DadriGPS DadriGPS G)G)
210.96210.96 0.5760.576 37.2037.20 95.1495.14 0.240.24 95.3895.38 132.58132.58
Dadri (T)Dadri (T) 416.78416.78 1.1581.158 76.9776.97 90.5690.56 55.5755.57 146.13146.13 229.24229.24
Unchahar – Unchahar – II II
------ ------ ------ 103.28103.28 6.986.98 110.26110.26 473.75473.75
Dadrigas(L)Dadrigas(L) ------ ------ ------ 356.34356.34 71.2171.21 436.55436.55
*Rates for mixed fuel (gas+ liquid fuel, naphtha)
Availability Based Tariff Availability Based Tariff (ABT)(ABT)
the presently followed mechanismthe presently followed mechanism
Tariff is split into the following Tariff is split into the following separate components:separate components:
Capacity chargesCapacity charges Energy chargesEnergy charges Unscheduled Interchange (UI)Unscheduled Interchange (UI)
AVAILABILITY BASED TARIFFAVAILABILITY BASED TARIFF
(A)(A) CAPACITY CHARGECAPACITY CHARGE
(B)(B) ENERGY CHARGEENERGY CHARGE
(C)(C) ADJUSTMENT FOR DEVIATIONS ADJUSTMENT FOR DEVIATIONS
(U I CHARGE)(U I CHARGE)
(A) = a function of the Ex-Bus MW (A) = a function of the Ex-Bus MW availability of Power Plant for the day availability of Power Plant for the day declared before the day starts x declared before the day starts x SEB’s % allocation from the plantSEB’s % allocation from the plant
(B) = MWh for the day as per Ex-Bus drawal (B) = MWh for the day as per Ex-Bus drawal schedule for the SEB finalised before schedule for the SEB finalised before the day starts x Energy charge ratethe day starts x Energy charge rate
(C) = (C) = Σ Σ (Actual energy interchange in a 15 (Actual energy interchange in a 15 minute time block – scheduled energy minute time block – scheduled energy interchange for the time block) x UI rate interchange for the time block) x UI rate for the time block for the time block
TOTAL PAYMENT FOR THE DAY = (A) + (B) TOTAL PAYMENT FOR THE DAY = (A) + (B) ± ± (C) (C)
FEATURES :FEATURES :
((A) and (B) do not depend on actual plant A) and (B) do not depend on actual plant generation / drawal. No metering required generation / drawal. No metering required for this as they are based on off-line for this as they are based on off-line figures. All deviations taken care of by (C)figures. All deviations taken care of by (C)
No complication regarding deemed No complication regarding deemed generation.generation.
Perpetual incentive for maximizing Perpetual incentive for maximizing generation and reducing drawal during generation and reducing drawal during deficit, but no incentive to over generate deficit, but no incentive to over generate during surplus.during surplus.
VARIABLE COST(Ps) OF POWER STATION IN SR AS ON JANUARY 2006
0
2400
4800
7200
9600
12000
14400
16800
19200
21600
24000K
UT
TA
LAM
(101
MW
) (7
3 P
S)
NE
YV
EL
II-S
TG
1 *
*(63
0 M
W)(
75 P
S)
TA
LCH
ER
ST
G I
I (2
000M
W)
(79
PS
)
KO
VIL
KA
LAP
PA
L *(
105
MW
)(80
PS
)
VA
LAT
HU
R(9
4MW
) (8
2 P
S)
AB
AN
PO
WE
R (
113M
W)
(88
PS
)
KO
TH
AG
UD
EM
(D)(
500
MW
)(96
PS
)
RA
MA
GU
ND
AM
(210
0 M
W)(
98 P
S)
NE
YV
ELI
-II
ST
G-I
I **
(840
MW
)(10
0 P
S)
JEG
UR
UP
AD
U (
GA
S)(
216
MW
)(10
2 P
S)
SP
EC
TR
UM
(G
AS
)(20
8 M
W)(
104
PS
)
RA
MA
GU
ND
AM
ST
III
(500
MW
) (1
04 P
S)
SIM
HA
DR
I(10
00 M
W)(
104
PS
)
RA
MA
GU
ND
AM
-B(6
2.5
MW
)(10
5 P
S)
VIJ
JES
WA
RA
M -
II(1
72.5
MW
)(10
7 P
S)
RE
INS
CA
LCIN
ING
LT
D.(
41 M
W)(
110
PS
)
KO
TH
AG
UD
EM
(B)(
210
MW
)(11
1 P
S)
KO
TH
AG
UD
EM
(A)(
240
MW
)(11
1 P
S)
KO
TH
AG
UD
EM
(C)(
220
MW
)(11
1 P
S)
VIJ
AY
AW
AD
A T
.P.S
.-1&
2(10
50 M
W)(
121
PS
)
VIJ
AY
AW
AD
A T
.P.S
.-3(
210
MW
)(12
1 P
S)
LAN
CO
(350
MW
)(12
5 P
S)
RA
ICH
UR
.T.P
S.
**(1
260
MW
)(12
5 P
S)
NE
YV
ELI
EX
PA
NS
ION
(42
0MW
) (1
35 P
S)
SR
IVA
TS
A
RA
YA
LAS
EE
MA
TP
P(4
20 M
W)(
153
PS
)
NO
RT
H M
AD
RA
S.T
.P.S
(630
MW
)(15
3 P
S)
VIJ
JES
WA
RA
M -
I(10
0 M
W)(
158
PS
)
ST
-CM
S(2
50 M
W)(
161
PS
)
ME
TT
UR
.T.P
.S(8
40 M
W)(
166
PS
)
B S
E S
(A
P)(
GA
S)(
140
MW
)(16
8 P
S)
TU
TU
CO
RIN
.T.P
.S(1
050
MW
)(18
2 P
S)
NE
YV
ELI
-I(6
00 M
W)(
185
PS
)
V S
P *
(120
MW
)(19
0 P
S)
PO
ND
Y P
CL
(32.
5 M
W)(
200
PS
)
EN
NO
RE
.T.P
.S(4
50 M
W)(
219
PS
)
L V
S(3
7.8
MW
)(22
0 P
S)
NE
LLO
RE
(30
MW
)(22
5 P
S)
NA
VB
HA
RA
T(3
5 M
W)(
240
PS
)
JIN
DA
L(26
0 M
W)(
280
PS
)
TA
TA
DE
ISE
L(81
.3 M
W)(
390
PS
)
RA
YA
LAS
EE
MA
(37.
8 M
W)(
390
PS
)
KO
ZH
IKO
DE
DP
P(1
28.8
MW
)(42
0 P
S)
GM
R V
AS
AV
I(19
6 M
W)(
444
PS
)
BA
LAJI
(SA
MA
YA
NA
LLU
R)(
105
MW
)(45
6 P
S)
BR
AH
MA
PU
AM
D P
P(1
06.5
MW
)(47
0 P
S)
KA
SA
RG
OD
P
C L
(21
MW
)(47
0 P
S)
SA
MA
LPA
TT
Y I
PP
(105
MW
)(47
4 P
S)
TH
AN
NE
ER
BA
VI(
235
MW
)(50
0 P
S)
PP
NA
LLU
R(3
30.5
MW
)(55
0 P
S)
B S
E S
(K
ER
ALA
)(16
5.5
MW
)(56
0 P
S)
KA
YA
MK
ULA
M N
TP
C(3
50 M
W)(
580
PS
)
YE
LEH
AN
KA
DE
ISE
L(12
7.92
MW
)(60
0 P
S)
BA
SIN
BR
IDG
E(1
20 M
W)(
863
PS
)
STATION, IC IN MW
CU
MU
LA
TIV
E IN
ST
AL
LE
D C
AP
AC
ITY
IN M
W
0
100
200
300
400
500
600
700
800
900
1000
VARIABLE COST
CUMULATIVE INSTALLED CAPACITY(MW)
IN SR 17935 MW OF THERMALS OUT OF 19227
MW (93%) HAS VARIABLE COST THAT FALLS
IN THE RANGE OF 60PAISE TO 400 PAISE
DETAILS>400 Ps/uCAP N D
ESC TO EXIT
DAY AHEAD SCHEDULING
• Schedules are made for each 15 minute time
block wise on day ahead basis i.e. 96 time
blocks in a day.
• Participating agencies are ISGS and States.
• Bilaterals/STOAs are also included in the
preparation of schedules.
• RLDC prepares and coordinates the schedules.
• On the day of operation the schedules can be
revised with prior intimation i.e. 4 to 6 time
blocks.
SCHEDULING
Availability Declaration
Entitlements
SLDC
Requisition & Bilateral Agreements
Injection Schedule Drawal Schedule
Revision in DC Revision in Requisition
FinalInjection Schedule
FinalDrawal Schedule
10:00
11:00
15:00
17:00
22:00
23:00
RLDC
ISGS
Time
Revisions duringCurrent day
Revisions duringCurrent day
0 to 24 hours
RLDC
TIME TABLE FOR EXCHANGE OF INFORMATION IN RESPECT OF SCHEDULING
By 10.00 hrs. ISGSs shall advise SRLDC the Station-wise MW and MWh capabilities
By 1100 Hrs. SRLDC shall advise the States / Beneficiaries the Station wise MW & MWh entitlements.
By 1500 hrs. SLDCs/ Beneficiaries shall communicate the Station-wise requisitions and details of bilateral exchanges to SRLDC.
By 1700 hrs. SRLDC shall convey the ex-power plant despatch schedule to each ISGS and net drawal schedule to each State / Beneficiary. The details of unrequisitioned surpluses shall also be intimated.
By2200 hrs. ISGSs / States / Beneficiaries shall inform the modifications, if any, for incorporating in the final schedule
By 2300 hrs. SRLDC shall issue the final despatch and drawal schedule.
ESC TO EXIT
BY 10: 00 HRS
ISGSs shall advise SRLDC the Station-wise
MW and MWh capabilities
Back
SAMPLE DC SHEET
BY 11: 00 HRS
Back
SRLDC shall advise the States / Beneficiaries the
Station wise MW & MWh entitlements.
SAMPLEENT. OF STATES
BY 15: 00 HRS
SLDCs/ Beneficiaries shall communicate the
Station-wise requisitions and details of
bilateral exchanges to SRLDC.
Back
BY 17: 00 HRS
SRLDC shall convey the ex-power plant despatch schedule to each ISGS
SRLDC shall convey the net drawal schedule to each State / Beneficiary
The details of unrequisitioned surpluses shall also be intimated.
Back
SAMPLESCHD OF STATES
SAMPLESCHD OF ISGS
BY 22 00HRS
Back
ISGSs / States / Beneficiaries shall
inform the modifications, if any,
for incorporating in the final schedule
BY 23 00HRS
SRLDC shall issue the final ex-power plant despatch schedule to each ISGS
SRLDC shall issue the final net drawal schedule to each State / Beneficiary
Back
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
UI PRICE CURVE : EXISTING
0
50
100
150
200
250
300
350
400
450
500
550
600
650
700
750
800
48.
7
48.
8
48.
9
49
49.
1
49.
2
49.
3
49.
4
49.
5
49.
6
49.
7
49.
8
49.
9
50
50.
1
50.
2
50.
3
50.
4
50.
5
50.
6
50.
7
50.
8
50.
9
51
FREQUENCY IN HZ
UI
PR
ICE
KNEE POINT210
345
745
KNEE POINT
SHOW TABLE HIDE TABLE
FREQ
UI PRICE EXISTING
48.7 74548.8 74548.9 74549 745
49.1 66549.2 58549.3 50549.4 42549.5 34549.6 30049.7 25549.8 21049.9 18050 150
50.1 12050.2 9050.3 6050.4 3050.5 050.6 050.7 050.8 050.9 051 0
30 Ps
45 Ps
80 Ps