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LINKSLINKSNECESSITY
POWERGRIDMISSION
DEVELOPMENT OFNATIONAL GRID
IR LINKS WITHSR
TYPES OF IR& DETAILS
DEFENCE MECHANISM
EXPERIENCE OF OPERATION IN SR
IR LINKSLOSS IN HVDC
PRIORITY ANDCURTAILMENT
CHEAPER GENERATIONVARIABLE COST
IR UI IRE-ACCOUNT
STATES UI
MERIT ORDERTALCHER STAGE2SCHEDULE & ACCOUNT
COMMERCIAL POINTS
PROCEEDURE FOR BIDDING
DIVERSITY &DISTURBANCE
NECESSITY OF IR NECESSITY OF IR EXCHANGESEXCHANGES
FORMATION OF NATIONAL GRID – FORMATION OF NATIONAL GRID – POWERGRID MISSIONPOWERGRID MISSION
MERIT ORDERMERIT ORDER CHEAPER GENERATION IN ER/WRCHEAPER GENERATION IN ER/WR DIVERSITY OF LOADSDIVERSITY OF LOADS BACKUP DURING GRID BACKUP DURING GRID
DISTURBANCEDISTURBANCE OVERALL ECONOMYOVERALL ECONOMY
POWERGRID MISSIONPOWERGRID MISSION
Establishment and operation Establishment and operation of Regional and National of Regional and National Power Grids to facilitate Power Grids to facilitate transfer of power transfer of power across the across the regionsregions with Reliability, with Reliability, Security and Economy on Security and Economy on sound commercial principles. sound commercial principles.
SOUTHERN REGION
WESTERNREGION
EASTERN REGION
NORTHERN REGION
NORTH-EASTERN REGION
SOUTHERN REGION
WESTERNREGION
EASTERN REGION
NORTHERN REGION
NORTH-EASTERN REGION
‘ELECTRICAL’
REGIONS1
2
3
SAME FREQUENCY FROM GUJARAT TO ARUNACHAL PRADESH WITH EFFECT FROM MARCH 2003
ABOUT 2800 KMS! APART
WITH COMMISSIONING OF TALA PROJECT INDIA WOULD HAVE ONLY TWO GRIDS!!!
6
DEVELOPMENT OF NATIONAL GRID
NER
ER
NR
WR
SR
EXISTING
500MW
MW1000
MW500
GAZUWAKA
CHANDRAPUR
VINDHYACHAL
SASARAM
UNDERCONST.
EXISTING
400 kV
220 kV
BONGAIGAONBIRPARA
MALDA
KORBA BUDHIPADAR
KOLHAPUR
BELGAUM
U.SILERU
BALIMELA
DEHRISAHUPURI
MALANPUR
AURAIYA
PHASE-I(By 2002)
HVDC STATION
KOLAR
(KARNATAKA)
TALCHER
ORISSA)
TALCHER KOLAR HVDC LINE
LENGTH:1400 KMS
13450 MW
1000 MW6450 MW
4600 MW
1300 MW3200 MW
30,000 MW OF INTER-REGIONAL POWER BY 2012
EASTERN REGION
SOUTHERN REGION
WESTERNREGION
NORTHERN REGION
NORTH-EASTERN REGION
INTER-REGIONAL TRANSFER BY END OF 11th PLAN (2012)
TOWARDS A NATIONAL TOWARDS A NATIONAL GRIDGRID
INVESTMENTS IN CENTRAL INVESTMENTS IN CENTRAL SECTOR TRANSMISSION SECTOR TRANSMISSION PROJECTS ENVISAGED FOR 10PROJECTS ENVISAGED FOR 10thth AND 11AND 11tHtH PLAN: PLAN: 71,000 CRORES71,000 CRORES
INTER REGIONAL TRANSFER INTER REGIONAL TRANSFER CAPACITY ENVISAGED BY 2012 : CAPACITY ENVISAGED BY 2012 : 30,000 MW30,000 MW
POWERGRID SRLDC
T
A.P
KAR
T.N
KER
MAH
ORISSA
RAMAGUNDAM
NEYVELI
MAPS
GOA
PONDICHERRY
CHANDRAPUR
JEYPORE
GAZUWAKA
KOLHAPUR
BELGAUM
U.SILERUL.SILERU
BALIMELA
BARSURCSEB
AMBEWADI
INTER REGIONAL LINKS FROM INTER REGIONAL LINKS FROM SRSR
HVDC BI POLEHVDC B2B STATION
CENTRAL GEN.STATION
220 kV LINE
400 kV LINE
110 kV HVDC LINE
KOLAR
TALCHAR
KAIGA
MERIT ORDER : UNITS BOXED UPMERIT ORDER : UNITS BOXED UPPOWER STATION STATE CAPACITY(MW) FUEL
VARIABLE COST
TATA DIESELKARNATAK
A 79 DIESEL 308
RAYALSEEMA DGPP
KARNATAKA 27 DIESEL 360
YELEHANKA DIESEL
KARNATAKA 128 DIESEL 314
THANRBHAVIKARNATAK
A 220 NAPTHA 325
SUB-TOTAL 454
BRAHAMPURAM DPP KERALA 107 DIESEL 275
BSES KERALA 157 NAPTHA 308
KASARGODE PCL KERALA 22 NAPTHA 298
KAYAMKULAM KERALA 360 NAPTHA 322
SUB-TOTAL 646
BASIN BRIDGETAMIL NADU 120 NAPTHA 584
P.P.NALLURTAMIL NADU 330 NAPTHA 415
SUB-TOTAL 450
TOTAL 1550
OPTIMAL RESERVOIR UTILISATIONOPTIMAL RESERVOIR UTILISATIONIDUKKI IN KERALAIDUKKI IN KERALA
KERALA SAVED RS 50 CRORES BY EFFICIENT UTILISATION OF THE RESERVOIRS AT IDUKKI!
POWERGRIDs 400 KV MADURAI-TRIVANDRUM LINE WILL HELP KERALA
SAVE EVEN MORE ENERGY IN THE COMING
YEAR
PLANT OPERATORS AT IDUKKI THINK OF THE RESERVOIR LEVEL IN RUPEES RATHER
THAN IN FEET!!!
Rs. Rs.
Rs.
Rs.
Rs.
Rs.Rs.
Rs.
Rs.
Rs.
Rs.
Rs.
Rs.
Rs.
Rs.Rs.
KADAMPARAI PUMP KADAMPARAI PUMP OPERATIONOPERATION
-300
-200
-100
0
100
200
300
400
5000:
001:
002:
003:
004:
005:
006:
007:
008:
009:
0010
:00
11:0
012
:00
13:0
014
:00
15:0
016
:00
17:0
018
:00
19:0
020
:00
21:0
022
:00
23:0
00:
00
TIME ---->
IN M
W --
-->
48.50
49.00
49.50
50.00
50.50
51.00
FREQ
UENC
Y IN
HZ
---->
GENERATOR MODE
PUMP PUMP
SAVINGS OF RS 40 LAKHS EVERY DAY
INVESTMENT OF 1600 CRORES SAVED
47.50
48.00
48.50
49.00
49.50
50.00
50.50
51.00
25 26 27 28 29 30 31
DAYS ----->
FR
EQ
UE
NC
Y IN
HZ
---
->FREQUENCY PROFILEFREQUENCY PROFILE
2002, 2003 & 2004
HARNESSING DIVERSITYHARNESSING DIVERSITYAN EXAMPLE IN CENTRAL AN EXAMPLE IN CENTRAL
GRIDGRID
WESTERNREGION
NORTH-EASTERN REGION
EASTERN REGION
WESTERNREGION
NORTH-EASTERN REGION
EASTERN REGION
AT 1830 HRS
AT 2000 HRS
600 MW
1200 MW
EASTERN REGION HELPS
WESTERN REGION
WESTERN REGION HELPS
EASTERN REGION
ER TO WR FLOW: TYPICAL DAYHARNESSING DIVERSITY
500
600
700
800
900
1000
1100
1200
1300
1400
1500
0:00
1:00
2:00
3:00
4:00
5:00
6:00
7:00
8:00
9:00
10:0
0
11:0
0
12:0
0
13:0
0
14:0
0
15:0
0
16:0
0
17:0
0
18:0
0
19:0
0
20:0
0
21:0
0
22:0
0
23:0
0
HOUR
MW
MAJOR AND MINOR DISTURBANCES SINCE MAJOR AND MINOR DISTURBANCES SINCE 19941994
0
1
2
3
4
5
6
7
8
9
10N
UM
BE
R O
F D
IST
UR
BA
NC
ES
---
----
->
1994
-95
1995
-96
1996
-97
1997
-98
1998
-99
1999
-00
2000
-01
2001
-02
2002
-03
2003
-04
2004
-05
YEAR ->
MAJOR MINOR
NO DISTURBANCES DESPITE LOSING NO DISTURBANCES DESPITE LOSING ENTIRE SUPER GENERATING PLANTS LIKEENTIRE SUPER GENERATING PLANTS LIKE
RAMAGUNDAM,VIJAYAWADA,KOTHAGUDEM, NORTH RAMAGUNDAM,VIJAYAWADA,KOTHAGUDEM, NORTH CHENNAI, SHARAVATHY ETCCHENNAI, SHARAVATHY ETC
VARIABLE COST(Ps) OF POWER STATION IN SR AS ON JUNE 2004
0
2000
4000
6000
8000
10000
12000
14000
16000
18000P
ON
DY
PC
L (3
2.5
MW
)(19
.61
PS
)
NE
YV
ELI
-II S
TG 1
**(
630
MW
)(67
.99
PS
)
KO
VIL
KA
LAP
PA
L *(
105
MW
)(68
PS
)
JEG
UR
UP
AD
U (G
AS
)(21
6 M
W)(
82 P
S)
SP
EC
TRU
M (G
AS
)(20
8 M
W)(
83 P
S)
VIJ
JES
WA
RA
M -I
(100
MW
)(84
PS
)
VIJ
JES
WA
RA
M -I
I(172
.5 M
W)(
86 P
S)
B S
E S
(AP
)(G
AS
)(14
0 M
W)(
87 P
S)
RE
INS
CA
LCIN
ING
LTD
.(41
MW
)(90
PS
)
RA
MA
GU
ND
AM
(210
0 M
W)(
90 P
S)
LAN
CO
(350
MW
)(91
.48
PS
)
NE
YV
ELI
-II S
TG-II
**(
840
MW
)(94
.61
PS
)
SIM
HA
DR
I(100
0 M
W)(
96 P
S)
RA
MA
GU
ND
AM
-B(6
2.5
MW
)(96
PS
)
VIJ
AY
AW
AD
A T
.P.S
.-1&
2(10
50 M
W)(
101
PS
)
VIJ
AY
AW
AD
A T
.P.S
.-3(2
10 M
W)(
101
PS
)
KO
THA
GU
DE
M(B
)(21
0 M
W)(
108
PS
)
RA
ICH
UR
.T.P
S. *
*(12
60 M
W)(
110
PS
)
KO
THA
GU
DE
M(A
)(24
0 M
W)(
110
PS
)
KO
THA
GU
DE
M(C
)(22
0 M
W)(
123.
1 P
S)
KO
THA
GU
DE
M(D
)(50
0 M
W)(
124
PS
)
RA
YA
LAS
EE
MA
TP
P(4
20 M
W)(
126
PS
)
NO
RTH
MA
DR
AS
.T.P
.S(6
30 M
W)(
130.
98 P
S)
TUTU
CO
RIN
.T.P
.S(1
050
MW
)(13
3.5
PS
)
ME
TTU
R.T
.P.S
(840
MW
)(15
0 P
S)
V S
P *
(120
MW
)(16
9.11
PS
)
ST-
CM
S(2
50 M
W)(
171
PS
)
NE
YV
ELI
-I(60
0 M
W)(
185.
86 P
S)
EN
NO
RE
.T.P
.S(4
50 M
W)(
190.
2 P
S)
L V
S(3
7.8
MW
)(20
0 P
S)
YE
LEH
AN
KA
DE
ISE
L(12
7.92
MW
)(20
3.36
PS
)
NA
VB
HA
RA
T(35
MW
)(20
5 P
S)
BR
AH
MA
PU
AM
D P
P(1
06.5
MW
)(21
4 P
S)
NE
LLO
RE
(30
MW
)(22
5 P
S)
B S
E S
(KE
RA
LA)(
165.
5 M
W)(
225
PS
)
THA
NN
EE
RB
AV
I(235
MW
)(22
8 P
S)
JIN
DA
L(26
0 M
W)(
247
PS
)
BA
LAJI
(SA
MA
YA
NA
LLU
R)(
105
MW
)(24
7 P
S)
KO
ZHIK
OD
E D
PP
(128
.8 M
W)(
250
PS
)
GM
R V
AS
AV
I(196
MW
)(25
4 P
S)
SA
MA
LPA
TTY
IPP
(105
MW
)(26
3 P
S)
TATA
DE
ISE
L(81
.3 M
W)(
280
PS
)
KA
YA
MK
ULA
M N
TPC
(350
MW
)(29
0 P
S)
KA
SA
RG
OD
P C
L(2
1 M
W)(
300
PS
)
RA
YA
LAS
EE
MA
(37.
8 M
W)(
330
PS
)
PP
NA
LLU
R(3
30.5
MW
)(41
5 P
S)
BA
SIN
BR
IDG
E(1
20 M
W)(
468
PS
)
CU
MU
LATI
VE
INS
TALL
ED
CA
PA
CIT
Y IN
MW
0
50
100
150
200
250
300
350
400
450
VA
RIA
BLE
CO
ST
IN P
s/U
NIT
VARIABLE COST
CUMULATIVEINSTALLE
ABOUT 7000 MW OF CAPACITY IS BELOW 100 Ps
ABOUT14200 MW OF CAPACITY IS BELOW 200 Ps
ABOUT 16000 MW OF CAPACITY IS BELOW 300 Ps
CUM. INS. CAP.
ER,WR AND SR(EXCEPT HYDRO)Variable Cost and Cumulative Installed Capacity of Power Generating Station
2030405060708090
100110120130140150160170180190200210220230240250260270280290300P
ON
DY
PC
L (S
R)(
32.5
MW
)TA
LCH
ER
STP
P(E
R)(1
000
MW
)IB
VA
LLE
Y(E
R)(4
20 M
W)
KS
TPS
(WR
)(21
00 M
W)
KLT
PS
(WR
)(215
MW
)K
orba
(W) -
I(W
R)(
840
MW
)TA
PS
(WR
)(32
0 M
W)
Dah
anu(
BS
ES
)(W
R)(5
00 M
W)
Trom
bay(
TEC
)(WR
)(115
0 M
W)
PA
TRA
TU(E
R)(7
70 M
W)
BO
KA
RO
'A'(E
R)(
175
MW
)B
OK
AR
O'B
'(ER
)(63
0 M
W)
TALC
HE
R (E
R)(4
60 M
W)
Kor
ba(E
) - II
I(WR
)(24
0 M
W)
KA
PP
(WR
)(440
MW
)K
AH
ALG
AO
N(E
R)(8
40 M
W)
Ura
n(W
R)(9
12 M
W)
M.A
.P.S
KA
LPA
KA
M *
*(S
R)(3
40 M
W)
KO
VIL
KA
LAP
PA
L *(
SR
)(10
5 M
W)
Kor
ba(E
) - II
(WR
)(16
0 M
W)
FAR
AK
KA
(ER
)(16
00 M
W)
NE
YV
ELI
-II S
TG 1
**(
SR
)(63
0 M
W)
VS
TPS
I &
II(W
R)(
2260
MW
)U
tran(
WR
)(135
MW
)C
hand
rapu
r(W
R)(
2340
MW
)C
HA
ND
RA
PU
RA
(ER
)(75
0 M
W)
ICC
L(E
R)(
40 M
W)
NA
LCO
(ER
)(15
0 M
W)
Am
arka
ntak
(WR
)(290
MW
)JE
GU
RU
PA
DU
(Gas
)(SR
)(21
6 M
W)
KO
LAG
HA
T(E
R)(
1260
MW
)S
PE
CTR
UM
(Gas
)(SR
)(20
8 M
W)
VIJ
JES
WA
RA
M -I
(SR
)(100
MW
)V
IJJE
SW
AR
AM
-II(S
R)(1
72.5
MW
)K
hape
rkhe
da(W
R)(8
40 M
W)
B S
E S
(AP
)(G
as)(
SR
)(14
0 M
W)
BU
DG
E-B
UD
GE
(ER
)(50
0 M
W)
TEN
UG
HA
T(E
R)(
420
MW
)R
ains
Cal
cina
ting
Ltd.
(SR
)(41
MW
)R
.S.T
.P.S
(SR
)(210
0 M
W)
LAN
CO
(SR
)(35
0 M
W)
Bhu
saw
al(W
R)(
478
MW
)B
irsin
ghpu
r(WR
)(840
MW
)N
EY
VE
LI-II
STG
-II *
*(S
R)(8
40 M
W)
DU
RG
AP
UR
(ER
)(350
MW
)S
IMH
AD
RI(S
R)(1
000
MW
)R
AM
AG
UN
DA
M-B
(SR
)(62.
5 M
W)
Kor
adi (
WR
)(108
0 M
W)
ME
JIA
(ER
)(63
0 M
W)
SO
UTH
ER
N(E
R)(
135
MW
)TI
TAG
AR
H(E
R)(
240
MW
)G
AN
DH
AR
(WR
)(657
MW
)V
IJA
YA
WA
DA
T.P
.S.-1
&2(
SR
)(10
50 M
W)
VIJ
AY
AW
AD
A T
.P.S
.-3(S
R)(2
10 M
W)
SA
NTA
LDIH
(ER
)(48
0 M
W)
Par
as(W
R)(5
8 M
W)
Sat
pura
- I(W
R)(3
12.5
MW
)S
atpu
ra -
II &
III(W
R)(8
30 M
W)
KO
THA
GU
DE
M(B
)(S
R)(2
10 M
W)
RA
ICH
UR
.T.P
S. *
*(S
R)(1
260
MW
)K
OTH
AG
UD
EM
(A)(
SR
)(240
MW
)B
AN
DE
L(E
R)(
530
MW
)P
arli(
WR
)(69
0 M
W)
DP
PS
(ER
)(390
MW
)B
AR
AU
NI(E
R)(3
10 M
W)
TUTU
CO
RIN
.T.P
.S(S
R)(1
050
MW
)U
kai(W
R)(
850
MW
)N
asik
(WR
)(910
MW
)M
UZA
FFA
RP
UR
(ER
)(220
MW
)K
OTH
AG
UD
EM
(C)(S
R)(2
20 M
W)
KO
THA
GU
DE
M(D
)(SR
)(500
MW
)R
AY
ALA
SE
EM
A T
PP
(SR
)(420
MW
)S
LPP
(WR
)(25
0 M
W)
WTP
S-7
(WR
)(210
MW
)M
ETT
UR
.T.P
.S(S
R)(
840
MW
)G
TPS
-5(W
R)(2
10 M
W)
Dhu
vara
n (W
R)(5
34 M
W)
Dhu
vara
n (L
SH
S)(W
R)(2
7 M
W)
GP
EC
(WR
)(65
5 M
W)
Wan
akbo
ri(W
R)(1
260
MW
)N
OR
TH M
AD
RA
S.T
.P.S
(SR
)(630
MW
)V
S P
*(S
R)(
120
MW
)G
andh
inag
ar(W
R)(
660
MW
)S
ikka
(WR
)(24
0 M
W)
N.C
OS
SIP
OR
E(E
R)(1
30 M
W)
NE
YV
ELI
-I(S
R)(6
00 M
W)
Ess
ar(W
R)(5
15 M
W)
EN
NO
RE
.T.P
.S(S
R)(4
50 M
W)
MU
LAZO
RE
(ER
)(60
MW
)L
V S
(SR
)(37
.8 M
W)
YE
LEH
AN
KA
DE
ISE
L(S
R)(
127.
92 M
W)
Nav
bhar
at(S
R)(3
5 M
W)
GS
EG
(WR
)(15
6 M
W)
Bra
hmap
uam
D P
P(S
R)(
106.
5 M
W)
NE
LLO
RE
(SR
)(30
MW
)K
AIG
A A
.P.S
**(
SR
)(440
MW
)B
S E
S (K
ER
ALA
)(SR
)(165
.5 M
W)
THA
NN
EE
RB
AV
I(SR
)(23
5 M
W)
JIN
DA
L(S
R)(
260
MW
)K
OZH
IKO
DE
DP
P(S
R)(1
28.8
MW
)P
P N
ALL
UR
(SR
)(330
.5 M
W)
KA
WA
S(W
R)(
656
MW
)TA
TA D
EIS
EL(
SR
)(81
.3 M
W)
BA
LAJI
(Sam
ayan
allu
r)(S
R)(1
05 M
W)
KA
YA
MK
ULA
M N
TPC
(SR
)(350
MW
)G
MR
VA
SA
VI(S
R)(1
96 M
W)
Kas
argo
d P
C L
(SR
)(21
MW
)S
AM
ALP
ATT
Y IP
P(S
R)(1
05 M
W)
RA
YA
LAS
EE
MA
(SR
)(37.
8 M
W)
BA
SIN
BR
IDG
E(S
R)(
120
MW
)
Var
iabl
e C
ost (
Ps/
U)
0150030004500600075009000105001200013500150001650018000195002100022500240002550027000285003000031500330003450036000375003900040500420004350045000465004800049500510005250054000555005700058500
Cum
ulat
ive
inst
alle
d C
apac
ity o
fER
,WR
&S
R in
MW
Cum.Capacity
Variable Cost
Types of Inter-Types of Inter-connectionsconnections
AC links (Synchronous mode)AC links (Synchronous mode) DC Links (Asynchronous DC Links (Asynchronous
mode) mode)
throughthrough
- HVDC line and - HVDC line and Convertors/InvertorsConvertors/Invertors
- HVDC Back to Back system - HVDC Back to Back system
Features of AC linksFeatures of AC links Low cost (up to some distance)Low cost (up to some distance) Increased Fault level and InertiaIncreased Fault level and Inertia Synchronous operation (same Synchronous operation (same
frequency)frequency) No control on Power flowNo control on Power flow Fault in one Region may affect other Fault in one Region may affect other
RegionRegion Over voltage problemsOver voltage problems Huge Power is lost in Equalizing the Huge Power is lost in Equalizing the
frequencies thereby loosing the frequencies thereby loosing the advantage in Differential frequencyadvantage in Differential frequency
No run back schemesNo run back schemes
Features of DC Features of DC LinksLinks
Higher capital cost Higher capital cost Asynchronous operationAsynchronous operationImmunity from faults in both Immunity from faults in both RegionsRegionsControl on Power flowControl on Power flowOptimization through Optimization through frequency frequency DifferentialDifferential
High lights of various High lights of various HVDC linksHVDC links
Bypass arrangement Bypass arrangement (ex.Bhadrawati,Gazuwaka)(ex.Bhadrawati,Gazuwaka)
Power order setting Power order setting Minimum Power for deblockingMinimum Power for deblocking Ramping rate variationRamping rate variation Run Back systems / Power Demand Run Back systems / Power Demand
Overrides (PDOs)Overrides (PDOs) Automatic Filter switching for Reactive Automatic Filter switching for Reactive
power requirementpower requirement
TALCHER KOLAR LINKTALCHER KOLAR LINK ONE OF THE LONGEST HVDC LINES IN THE ONE OF THE LONGEST HVDC LINES IN THE
WORLDWORLD DESIGNED TO EVACUATE DESIGNED TO EVACUATE 2000 MW2000 MW COMMISSIONED IN ADVANCE TO UTILISE NON-COMMISSIONED IN ADVANCE TO UTILISE NON-
PEAK SURPLUS POWER OF EASTERN REGIONPEAK SURPLUS POWER OF EASTERN REGION COMMISSIONED 9 MONTHS AHEAD OF COMMISSIONED 9 MONTHS AHEAD OF
SCHEDULESCHEDULE COST INCURRED COST INCURRED Rs 3,100 CRORES Rs 3,100 CRORES AGAINST AGAINST
APPROVED COST OF APPROVED COST OF Rs 3,866 CRORESRs 3,866 CRORES:- SAVING OF :- SAVING OF NEARLY NEARLY 800 CRORE RUPEES800 CRORE RUPEES
THE PROJECT HAS USED THE PROJECT HAS USED APPROXIMATELY 90,000 TONNES OF APPROXIMATELY 90,000 TONNES OF STEEL AND 16,000 KM OF CABLES STEEL AND 16,000 KM OF CABLES
TALCHER-KOLARTALCHER-KOLAR IMPORT OF 12728MUs FROM ER THROUGH TALCHER-KOLAR UPTO OCT-04
YEAR ---YEAR --->>
20022002 20032003 20042004
MONTHMONTHSS
TOTAL TOTAL ENERGY ENERGY (IN MU)(IN MU)
MAX MAX FLOW FLOW
(IN MW)(IN MW)
TOTAL TOTAL ENERGENERGY (IN Y (IN MU)MU)
MAX MAX FLOW FLOW
(IN (IN MW)MW)
TOTAL TOTAL ENERGY ENERGY (IN MU)(IN MU)
MAX MAX FLOW FLOW
(IN (IN MW)MW)
JANJAN ------ ------ 311311 850850 805805 15281528
FEBFEB ------ ------ 273273 10101010 701701 15081508
MARMAR ------ ------ 491491 13161316 837837 16001600
APRAPR ------ ------ 473473 11831183 923923 15001500
MAYMAY ------ ------ 172172 10261026 652652 13851385
JUNJUN ------ ------ 277277 994994 688688 14161416
JULJUL ------ ------ 319319 10751075 759759 14901490
AUGAUG ------ ------ 346346 10881088 628628 13411341
SEPSEP 66 200200 512512 15331533 742742 15521552
OCTOCT 5858 500500 508508 1458 1458 829829 15501550
NOVNOV 7777 500500 470470 1048 1048
DECDEC 241241 750750 630630 1383 1383
TOTALTOTAL 382382 47824782 75647564
MAXMAX 750750 15331533 16001600
Defense MechanismDefense Mechanism
Run Back scheme in Gazuwaka HVDC Run Back scheme in Gazuwaka HVDC Power level reduces to 250MW ,Power level reduces to 250MW ,
- If Gazuwaka East bus Voltage - If Gazuwaka East bus Voltage <320kV <320kV
- If Gazuwaka ICT O/L alarm actuates- If Gazuwaka ICT O/L alarm actuates- If Jeypore ICT trips- If Jeypore ICT trips- If Jeypore-Indravati Line trips- If Jeypore-Indravati Line tripsPower level reduces to 150MW,Power level reduces to 150MW,- If East side frequency <49Hz and - If East side frequency <49Hz and if df/dt>=-0.3 Hz./sec. if df/dt>=-0.3 Hz./sec.
Defense Mechanism for Defense Mechanism for Talcher Kolar HVDC linkTalcher Kolar HVDC link
In case of any pole tripping, Inter-trip signal In case of any pole tripping, Inter-trip signal generated to trip associated AC lines at generated to trip associated AC lines at
Yerraguntla(AP), Yerraguntla(AP), Kolar, Hoody, Somanahalli(Karnataka)Kolar, Hoody, Somanahalli(Karnataka)Sriperambadur, Salem and Hosur (TN)Sriperambadur, Salem and Hosur (TN)
Mode of Oprn. Mode of Oprn. Power Level for Inter-trip Power Level for Inter-tripMono polar >400MW and pole tripsMono polar >400MW and pole tripsBi-polar >800MW/pole and one pole trips Bi-polar >800MW/pole and one pole trips Bi-polar >200MW/pole and both pole tripBi-polar >200MW/pole and both pole trip
contd..contd..
Defense Mechanism forDefense Mechanism for Talcher Kolar HVDC link Talcher Kolar HVDC link
Further PDOs at HVDc Kolar, Further PDOs at HVDc Kolar,
Condition Power reduced Condition Power reduced toto
If only 2 lines are available 500MWIf only 2 lines are available 500MW
If only 3 lines are available 1000MWIf only 3 lines are available 1000MW
If only 4 lines are available 1500MWIf only 4 lines are available 1500MW
Experience of SR Experience of SR in operation of IR linksin operation of IR links
Congestion in associated AC network in Congestion in associated AC network in (ex. 1)Over loading of Raipur-Rourkela, (ex. 1)Over loading of Raipur-Rourkela,
Raipur-Bhadravati, Chandrapur-Bhadravati Raipur-Bhadravati, Chandrapur-Bhadravati in case of more import from WR.in case of more import from WR.
2) Over loading of Chadrapur-Parli 2) Over loading of Chadrapur-Parli in case of more export to WR in case of more export to WR
3) Over loading of Jeypore-Jayanagar, Jeypore-3) Over loading of Jeypore-Jayanagar, Jeypore-Meramundali, Jeypore-Indravati, Talcher-Meramundali, Jeypore-Indravati, Talcher-Banjinagar(220kV), Gajuwaka-Vijayawada in case of Banjinagar(220kV), Gajuwaka-Vijayawada in case of more import from ER through Gazuwakamore import from ER through Gazuwaka
Reduced fault level at JeyporeReduced fault level at Jeypore
4) Reduced Securtiy & Overloading of Lines in case 4) Reduced Securtiy & Overloading of Lines in case Talcher import crosses 1500MWTalcher import crosses 1500MW
contd…contd…
Experience of SR Experience of SR in operation of IR linksin operation of IR links
Problems in Converter transformers at Problems in Converter transformers at Gazuwaka ( HENCE SUGGESTED FOR Gazuwaka ( HENCE SUGGESTED FOR STANDBY CONVERTER TRANSFORMERS AT STANDBY CONVERTER TRANSFORMERS AT ALL THE PLACES)ALL THE PLACES)
Harmonics in neutral of Kolar ICT and flow of Harmonics in neutral of Kolar ICT and flow of the same in associated systemthe same in associated system
Over voltage at Kolar due to Switching of Over voltage at Kolar due to Switching of filtersfilters
High losses in Monopolar- Metallic return High losses in Monopolar- Metallic return mode.mode.
Annual Maintenance of Poles.Annual Maintenance of Poles. CURTAILMENT OF STOA CURTAILMENT OF STOA
LOSSES IN HVDC LOSSES IN HVDC SYSTEMSYSTEM
POWER ORDER IN MW
% LOSS
MAX CAPACITY MIN. CAPACITY (50MW )
Loss optimizationLoss optimization
IR flows can influence SR System IR flows can influence SR System LossLoss
By importing more through KolarBy importing more through Kolar By exporting to WR from By exporting to WR from
Ramagundam-Chandrapur LinkRamagundam-Chandrapur Link During high frequency, More During high frequency, More
import from Gazuwaka preferred.import from Gazuwaka preferred.
Losses applicable Losses applicable for various transactionsfor various transactions
1. 1. For share from ER ISGS- ER+SR lossesFor share from ER ISGS- ER+SR losses2. For Talcher St-II power through 2. For Talcher St-II power through
Kolar, - SR lossesKolar, - SR losses3. For Talcher-St-II power when wheeled3. For Talcher-St-II power when wheeled through Gazuwaka – ER+SR lossesthrough Gazuwaka – ER+SR losses through Bhadravati – ER+WR+SR through Bhadravati – ER+WR+SR
losseslosses4. Wheeling of ER power through SR 4. Wheeling of ER power through SR – – ER+ SR lossesER+ SR losses
Normative % Losses of Normative % Losses of Central sector in various Central sector in various
RegionsRegionsER ~ 3 to 3.5%ER ~ 3 to 3.5%SR ~ 2.8 to 3.8%SR ~ 2.8 to 3.8%WR ~ 6 to 6.5%WR ~ 6 to 6.5%NR ~ 3 to 4%NR ~ 3 to 4%
Priority of Exchanges Priority of Exchanges through IR linksthrough IR links
Long Term transactions Long Term transactions
(ISGS Allocation to Beneficiaries (ISGS Allocation to Beneficiaries of the of the same region)same region)
Wheeling of ISGS share of Wheeling of ISGS share of Beneficiaries in Beneficiaries in other regionsother regions
any other long term transactions any other long term transactions approvedapproved
STOA TransactionsSTOA Transactions
PROCEDURE FOR PROCEDURE FOR CURTAILEMENTCURTAILEMENT
In case of transmission constraint , In case of transmission constraint , if curtailment is necessary then,if curtailment is necessary then,
Short term customers firstShort term customers first Long term customers nextLong term customers next
Within the category,Within the category, OA customers haveOA customers have
curtailment on pro curtailment on pro rata basisrata basis
Commercial AspectsCommercial Aspects
Metering and Scheduling points :Metering and Scheduling points :
SR-WRSR-WR
South Bus of HVDC BhadravatiSouth Bus of HVDC Bhadravati
SR-ERSR-ER
East Bus of HVDC GazuwakaEast Bus of HVDC Gazuwaka
AC Inter connector of Talcher AC Inter connector of Talcher St-I St-I and St-IIand St-II
TSTPP St-II scheduling and TSTPP St-II scheduling and DespactchDespactch
TSTPP St-II furnishes DC to SRLDC with a copy TSTPP St-II furnishes DC to SRLDC with a copy to ERLDC.to ERLDC.
SRLDC to carry out rest of the Scheduling SRLDC to carry out rest of the Scheduling processprocess
Talcher/ Gazuwaka set points to be decided in Talcher/ Gazuwaka set points to be decided in consultation with ERLDCconsultation with ERLDC
Talcher HVDC controlled by ERLDC.Talcher HVDC controlled by ERLDC. Gazuwaka HVDC controlled by SRLDC.Gazuwaka HVDC controlled by SRLDC. In case of Talcher Pole tripping TSTPP St-II In case of Talcher Pole tripping TSTPP St-II
Power wheeled through Gazuwaka/BhadrawatiPower wheeled through Gazuwaka/Bhadrawati
TSTPP St-II UI TSTPP St-II UI accounting accounting
TSTPP St-II – a SR ISGS embedded in ER TSTPP St-II – a SR ISGS embedded in ER system system
TSTPP St-II UI @ ER frequency and to pay to TSTPP St-II UI @ ER frequency and to pay to SR poolSR pool
Net injection of TSTPP St-II = (Talcher HVDC Net injection of TSTPP St-II = (Talcher HVDC Energy- flow on I/C betweenTalcher St-I&II)Energy- flow on I/C betweenTalcher St-I&II)
Variation in TSTPPSt-II Generation results in Variation in TSTPPSt-II Generation results in ER-SR UI, if HVDC set point not changedER-SR UI, if HVDC set point not changed
Sometimes –ve UI occurs if ER – SR Sometimes –ve UI occurs if ER – SR SCHEDULE flow is not changed in SCHEDULE flow is not changed in accordance with ER-SR frequency accordance with ER-SR frequency differential.differential.
Inter Regional UI Inter Regional UI settlement settlement IR UI calculated by each REB at IR UI calculated by each REB at
respective frequencyrespective frequency IR UI Payment on 1IR UI Payment on 1stst charge basis charge basis
without pro-rata reduction/averaging without pro-rata reduction/averaging outout
Importing Region to pay on lesser of Importing Region to pay on lesser of the two principle.the two principle.
Differential due to difference in UI Differential due to difference in UI rates on a/c of frequency deposited by rates on a/c of frequency deposited by importing region in their IRE account.importing region in their IRE account.
WR UI ER UI
IRE Settlement IRE Settlement
Such accrued amounts of Such accrued amounts of IRE account to be shared on IRE account to be shared on 50:50 basis between 50:50 basis between Beneficiaries of both RegionsBeneficiaries of both Regions
By way of credit in By way of credit in Transmission charges of Transmission charges of CTUCTU
Status of IRE a/c settlement Status of IRE a/c settlement in SR & other regionsin SR & other regions
100% settled to SR constituents 100% settled to SR constituents except for provision for Revisionsexcept for provision for Revisions
Rs. 5 cr. Released WR Rs. 5 cr. Released WR constituentsconstituents
Release to ER will start next Release to ER will start next week.week.
INTER-REGIONAL EXCHANGES WR A/C INTER-REGIONAL EXCHANGES WR A/C DETAILS UPTO 93 WKSDETAILS UPTO 93 WKS
TILL 10/10/04TILL 10/10/04
1. NET ENERGY TRANSACTION IS 146 MU (IMPORT BY SR).
2. AMOUNT ACCRUED IN SREB – IRE DUE TO DIFF. IN WR A/C = 41.83Crs
3. AMOUNT TO BE ACCRUED IN WREB – IRE DUE TO DIFF. IN SR A/C = 27.71Crs
4. AMOUNT DUE TO SR CONSTITUENTS ON 50:50 BASIS = 34.73Crs
5. AMOUNT ALREADY DISBURSED TO SR CONSTITUENTS = 33.39Crs
Procedure for Bidding RLDC concerned shall invite bids if
transmission capacity reservation sought by short term customer is more than the availability in a particular transmission corridor
The floor price of the bids for short term customer shall be about 1/4 th rate chargeable from long term customer and will be in Rupees per MW per day.
If customer gets the quantum of power he has bid for – he has to pay the price quoted by ‘last’ customer.
If customer gets a quantum lesser than that he has bid for – he gets to pay his bid price
INTER REGIONAL EXCHANGE WITH ERFOR 2004-05
135
222
0
50
100
150
200
250
ER RATE SR RATE
Avg
. R
AT
E (
pa
ise
/Kw
h)
IMPORT BY SR FROM ER (160 MU)
INTER REGIONAL EXCHANGE WITH ERFOR 2004-05
197
314
0
50
100
150
200
250
300
350
SR RATE ER RATE
EXPORT FROM SR TO ER (11 MU)
INTER REGIONAL EXCHANGE WITH WRFOR 2004-05
131
240
0
50
100
150
200
250
300
WR RATE SR RATE
IMPORT BY SR FROM WR (185 MU)
SR IRE = Rs. 41.83 Cr.
WR IRE = Rs. 27.71 Cr.
50% =Rs.34.73 Cr.
DISBURSED =Rs. 33.39 Cr
INTER REGIONAL EXCHANGE WITH WRFOR 2004-05
180
304
0
50
100
150
200
250
300
350
SR RATE WR RATE
EXPORT FROM SR TO WR (107 MU)
UI EXCHANGES BY STATES IN 2004-05
-800
-600
-400
-200
0
200
400
AP KAR KER TN
(9 Mu) 335
(1125 Mu) 194
(208 Mu) 217
207(1197 Mu)
(567 Mu) 220
222(74 Mu)
101(56 Mu)
649(1 Mu)
NOTE: FIGS. IN BRACKETS INDICATE THE ENERGY OVERDRAWN/UNDERDRAWN
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