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LIGHTS FOR THE MONTH OF
S
ONS (PREVIOUS MONTH):
RAMETERS
ACHIEVED PARAMETERS
GHTS
d 100% availability factor during the month.
d zero Sp. Oil Consumption during the month, surpassing previous minimum
f 0.01 ml/kWh during May'09.
maximum continuous running for 237.35 days (5696.50 hrs.) from 23.12.2008
passing previous continuous running for 232.65 days (5583.48 hrs.) from 28/11
inuous Running :
IGHLIGHTS DURING THE MONTH :
own :
ken under planned shut down at 00:45 hrs. on 18/08/2009, for Boiler Licence
t synchronised at 15:38 hrs. on 21/08/2009 (Outage hrs.=86.88, 3.62 days).
taken under planned shut down at 23:47 hrs. on 31/08/2009, for Capital
(Outage hrs.=0.22).
tor :
il Consumption :
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ATION
as per performance evaluat ion m atr ix to be provided.
APR MAY JUN JUL AUG SEP OCT NOV DEC
PARAMETERS
Unit
Actual
(CurrentMonth)
Value Month Value
MU 815.4160 Dec.'07 778.9640
% 104.40 Feb.'09 99.71
r) % 100.00 Feb.'08 95.87
% -4.53 Dec.'07 -4.01
Kcal/Kwh 2376.00
Dec.'08 &
Feb.'09 2387
ved during the month was 4,49,487.30 MT (122 Rakes).
Best achieved(Till Date)
al) for Stage-I , Stage-II, Stage-III & Station (Comml.) were 97.98%, 99.81%,
7% respectively during the month.
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ml/Kwh 0.02 Feb.'08 0.22
Kg/Kwh 0.61 Feb'09 0.644
% of MCR 0.47 Feb.'09 0.78
EST ACHIEVED PARAMETERS (Update as and when the base value is improved
Value Month Value Month Value Month Value Month
MU 634.1910 Jan.'05 634.5440 Dec.'05 635.4480 Dec.'06 761.6880 Jan.'07
%101.97 Mar.'99 102.34 Feb.'06 102.76 Nov.07 104.38 Dec'07
r) %100.00 Mar.'05 100.00 Feb.'06 100.00 Feb.'09 100.00 July'09
%0.00 Feb.'05 -2.34 Feb.'06 -4.01 Aug'09
Kcal/Kwh2440 Mar.'05 2433 Oct'05 2423 Nov'05 2413 Dec'05
ml/Kwh
0.08 Feb.'04 0.04 Mar.'06 0.02 Feb.'08
Kg/Kwh0.673 Oct.'02 0.665 Mar.'06 0.662 Jul-07 0.662 Feb-08
% of MCR 0.55 Dec.'04 0.47 Feb'09
Best achieved(Base Value)
Best achieved(Next) Bestachieved(Next)
Bestachieved(Next)
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Fin. Year
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Month Value Month Value Month Value Month Value Month Value Month Value
Aug.'07 794.3600 Oct.'07 815.4160 Dec.'07
Feb'06 2405 Jan'07 2402 Feb'07 2398 Mar'07 2394 Oct.'07 2392 Nov.07 2388
Feb'09
Bestachieved(Next)
Bachiev
Bestachieved(Next)
Bestachieved(Next)
t(Next)
Bestachieved(Next)
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ue Month Value Month Value Month
383 FEB.'08 2376 DEC.'08 2376 Feb.'09
Bestachieved(Next)
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ORMANCE W.R.T. MOU TARGET (YEAR):
TARGET WITH ACTION PLAN:
ETERS
OU TARGET WITH ACTION PLAN :
MOU
TARGET (R0)
MOU
TARGET ACTUAL
FINANCIAL YEAR) R1 R2 R3 R4 Pro rata TILL
Aug-09
8414 -- -- -- -- 3586.6706 3818.1610
5.37 -- -- -- -- 3.79 3.34
1.50 -- -- -- -- 1.53 1.17
0.50 -- -- -- -- 0.51 0.01
2392 -- -- -- -- 2399 2391
0.25 -- -- -- -- 0.28 0.16
8.34 -- -- -- -- 8.39 8.05
70.00 -- -- -- -- 75.00 75.24
RAMETERS WITH RETRIEVAL PROGRAM
Apr-09 May-09 Jun-09 Jul-09 Aug-09 Sep-09 Oct-09 Nov-09 Dec-09 Jan-10 Feb-10 Mar-10
Target 732.1104 721.2341 666.4392 756.2016 710.6854 586.0512 629.1079 660.7944 756.5141 756.0454 682.8797 756.0454
Actual 773.6130 756.4340 698.9800 810.1700 778.9640 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000
Deviation (+/-) 41.5026 35.19992 32.5408 53.9684 68.27864 -586.0512 -629.10792 -660.7944 -756.51408 -756.04536 -682.87968 -756.04536
Program for Balance
Period
Target 0.00 4.52 8.67 0.00 5.81 20.00 16.13 9.33 0.00 0.00 0.00 0.00
MOU TARGET (Fin. Yr.)
(Revision) VARIATION
REASON FOR
VARIATION
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Apr-09 May-09 Jun-09 Jul-09 Aug-09 Sep-09 Oct-09 Nov-09 Dec-09 Jan-10 Feb-10 Mar-10
Actual 0.00 4.51 9.96 0.00 2.34 #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0!
Deviation (+/-) 0 -0.004032 1.2894444 0 -3.465053763 #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0!
Program for Balance
Period #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF!
Target 1.52 1.52 1.54 1.54 1.54 1.20 1.54 1.52 1.52 1.52 1.52 1.52
Actual 1.86 1.33 0.88 0.00 1.79 #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0!
Deviation (+/-) 0.33888889 -0.185323 -0.662778 -1.54 0.249784946 #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0!
Program for Balance
Period
Target 0.50 0.50 0.50 0.52 0.54 0.40 0.52 0.50 0.50 0.50 0.50 0.50
Actual 0.00 0.00 0.00 0.02 0.04 #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0!
Deviation (+/-) -0.5 -0.5 -0.5 -0.504293 -0.498230927 #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0!
Program for Balance
Period #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF!
Target 8.30 8.32 8.37 8.48 8.48 8.48 8.41 8.30 8.26 8.24 8.24 8.26
Actual 7.58 8.01 8.15 8.22 8.28 #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0!
Deviation (+/-) -0.72577556 -0.311262 -0.217218 -0.257798 -0.203826707 #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0!
Program for Balance
Period #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF!
Target 0.17 0.17 0.44 0.22 0.41 0.24 0.43 0.44 0.16 0.12 0.12 0.12
Actual 0.13 0.06 0.39 0.03 0.22 #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0!
Deviation (+/-) -0.0374635 -0.112523 -0.042038 -0.184864 -0.192843287 #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0!
Program for Balance
Period #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF!
Target 2388 2395 2396 2409 2406 2400 2402 2394 2383 2379 2379 2380
Actual 2387 2391 2396 2392 2387 0 0 0 0 0 0 0
Shortfall/
Excess -0.92028088 -3.618105 0.0769871 -16.81364 -18.74675171 -2400.00645 -2401.5284 -2394.074441 -2382.948162 -2378.924365 -2378.924365 -2379.933871
Program for Balance
Period #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF! #REF!
Target 0 0 0 0 0 0 0 0 0 0 0 0
Actual 70 70 74 75 75 0 0 0 0 0 0 0
Deviation (+/-) 70 70 74.28 75.23 75.24 0 0 0 0 0 0 0
Program for BalancePeriod 0 0 0 0 0 0 0 0 0 0 0 0
ess (+) in the above parameters should be highlighted in red & green colour respectively.
N OF ROPR TARGETS :
ROPR
TARGET (R0)
(FIN. YEAR) R1 R2 R3 R4
ROPR TARGET (Fin. Yr.)
EXPEXTD FY(Revision)
ACTUALTILL
DATE
EXPEXTD FOR
BALANCE
PERIOD
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Apr-09 May-09 Jun-09 Jul-09 Aug-09 Sep-09 Oct-09 Nov-09 Dec-09 Jan-10 Feb-10 Mar-10
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N
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TREND
ION PERFORMANCE (TREND)
TION PERFORMANCE (TREND)
2001-02 2002-03 2003-04 2004-05 2005-06 2006-07 2007-08 2008-09
urren
Year(Cumul
ative)
6560.9920 6148.8330 6450.9290 6781.0900 7041.2050 7467.2270 9010.0690 8620.9160 3818.1610
89.16 83.56 87.43 92.15 95.69 95.59 97.69 93.73 99.03
92.10 87.60 89.94 92.25 94.70 94.69 95.05 91.46 95.49
92.10 87.60 89.94 92.25 94.70 94.69 95.16 91.46 95.49
3.19 4.61 2.79 0.11 -1.05 -0.95 0.48 0.70 0.25
0.69 1.40 0.87 0.38 0.20 0.19 0.10 0.24 0.01
0.60 0.64 0.50 0.43 0.36 0.27 0.24 0.27 0.16
8.51 8.76 8.93 8.58 8.37 8.18 8.05 8.07 8.05
0.68 0.68 0.69 0.68 0.67 0.67 0.66 0.64 0.617
1.23 1.06 0.99 0.88 1.00 1.03 0.87 0.77 0.61
ION PERFORMANCE DATA (MONTH WISE / CUMULATIVE):
E IN BI ANALYTICS IN ESS : COAL STATION PERFORMANCE
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:
IN BI ANALYTICS IN ESS : COAL STATION PERFORMANCE
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R STATIONS UNDER ABT)
DEVIATION IN ABT GAP ANALYSIS:
F DC GAP
AP
o bta ined from the tab le given under sect ion 4.4
S (FOR STATIONS UNDER ABT):
r)
A
SG %
of DC bar
AG %
of DC bar DC (installed)-DC (bar) break up (%)
2198212-3.822353736-4.472992863-2.549716565
100 100 100 100 100
MAY JUNE JULY AUG SEPT OCT NOV DEC JAN
Trending of DC GAPDifference of DC (Installed) - Planned & Forced Outage (Ex bus) and DC on bar (%)]
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Planned Forced Equpt.
Fuel
quality
Fuel
supply Others* Grid
21521 99.31997998 100.02411 0 1.546499 0 0 0 -5.34865 0.68002
46066 98.3757022 99.02376 4.088106016 1.326632 0 0 0 -4.1622 1.62305
26979 99.64371998 100.06963 10.62333313 0.035751 0 0 0 -3.82235 0.35628
29929 99.44649609 100.01367 0 0 0 0 0 -4.47299 0.5535
30571 99.92425951 100.53122 2.346438847 0.328972 0 0 0 -2.54972 0.07574
.03 99.34 99.93 3.39 0.65 0.00 0.00 0.00 -4.06 0.89
ge wise ,please add additional formats/graphs
Y DEVIATION IN ABT GAP ANALYSIS:
ResponsibilityReasons Action Plan
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NG OF DC GAP
Planned & Forced
Outage (Ex-bus)
%of A (B)
Installed-
%-Planned
& Forced
DC (bar)
%of A
(D)
erenc
e
(C)- (D)-
%
1.546498894 98.453501 103.8021521 -5.34865
5.41473755 94.585262 98.74746066 -4.1622
10.65908395 89.340916 93.16326979 -3.82235
0 100 104.4729929 -4.47299
2.675410852 97.324589 99.87430571 -2.54972
0 100 0 100
0 100 0 100
0 100 0 100
0 100 0 100
0 100 0 100
LOW SHEDULE&HIGH FREQUENCY
NA
0%
from SIIS from time to time
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0 100 0 100
0 100 0 100
100.03 -4.064.03
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Equivalen
t
Availabilit
y (%)
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Fuel
upply Others*
0 0.016746 103.8022
0 -0.52507 98.74746
0 0.12936 93.16327
0 0.214243 104.473
0 0.340282 99.87431
0.00 -0.34 100.03
status
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MONTH Difference (C)- (D)-%
APRIL -5.34865
MAY -4.1622
JUNE -3.82235
JULY -4.47299
AUG -2.54972
SEPT 100
OCT 100
NOV 100
DEC 100
JAN 100
FEB 100
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MAR 100
CUM. -4.06446
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AG/DC PLOT AGAINST FREQUENCY)-MONTH WISE
RIX (FOR STATIONS UNDER ABT):
AG/DC PLOT AGAINST FREQUENCY)-MONTH WISEere month wise
Scatter Diagram for the Month of April Scatter
inst Average Frequency:
90%DC)
70
80
90
100
110
50 50.5 51 51.5quency (Hz)
BEF, 50.3Hz
AG/SG(%)
urple trace
90% of DC for illustration purposes
o left of 50Hz axis
ht of 50Hz axis
be 80% of DC
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1111 0.659722222 0 1.180555556 1.111111111 0.451388889 0 0
es good performance
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onth of May Scatter Diagram for the Month of June Scatter Diagram for the Month of J
Freq. VS AG % of DC (Unchaha
70.00
75.00
80.00
85.00
90.00
95.00
100.00
105.00
110.00
4 8.50 48 .75 49.00 4 9.25 49.5 0 49.75
Freq.(H
AG%o
fDC(%)
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Scatter Diagram for the Month of Nov Scatter Diagram for the Month of D
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EVING 105% DC
NERAL):
n the unit generated at 105% DC
Y
to be f i l led in the table given un der sect ion 4.10
ACHIEVING 105% RATED CAPACITY
May June July Aug Sept Oct Nov Dec Jan Feb
No. of Time blocks unit operated at 105% DC
it-12 Unit-11 Unit-10 Unit-9 Unit-8 U
it-6 Unit-5 Unit-4 Unit-3 Unit-2 U
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Action Plan
Boiler & Aux. Mills
Nil
Action Plan
Nil Nil
Turbine & Aux.
Resp
Constraints Responsibility
Nil
Elec
Constraints
me plate rat ing of the un i t .
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Action PlConstraints
Nil
me plate rat ing of the un i t .
C&I BoP Others
Nil Nil
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OCUREMENT AS PER ACTION PLAN
onent Indent
No. &
Date
Estimated
Cost
Status of any
CC/RHQ approval
,if required
Bid
Evalua
tion
Expected Actual Expected Actual
NERAL):
ur April May June July Aug Sept Oct Nov
eak
age DC
a day 99.70 100.26 99.58 100.026 100.49
Enquiry /NIT Date Bid Received date
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g forced
uld not
ame time
DC (no.)
tation
R
(no.)tation
e DC on
when the unit generated at 105% DCfor each unit for establishing 105% DC capability.
ur April May June July Aug Sept Oct Nov
2680 1899 2484 2227 1788
2680 1899 2484 2227 1788
2421 1959 634 1081 1357
2421 1959 634 1081 13572421 1959 634 1081 1357
when
at 105%
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Present statusrget Date
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te Actual Expected Actual
Fin-Year
100.01
Implementation/
Installation Datelivery Date
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Fin-Year
11078
11078
7452
74527452
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S ANALYSIS:
OSS (STATION) FOR LAST 9 YEARS (%):
Y LOSS BREAK UP(STATION)-MONTH WISE:
MONTH AND ACTION PLAN
TY LOSS (STATION) FOR LAST 9 YEARS (%):
01-02 2002-03 2003-04 2004-05 2005-06 2006-07 2007-08 2008-09
2009-10 Till
Date
2008-09
(Same
Period)
.40 7.25 6.07 6.21 4.02 0.00 3.17 5.84 3.34 9.82
.12 3.57 0.00 0.07 0.00 0.00 0.00 0.00 0.00 0.00
.76 2.94 1.73 0.62 0.39 0.00 0.00 0.00 0.00 0.00
.00 0.00 0.00 0.00 0.00 1.45 1.77 2.52 1.17 1.56
.00 0.00 0.00 0.00 0.00 1.45 1.79 2.52 1.17 1.56
BILITY LOSS BREAK UP(STATION)-MONTH WISE:
E MONTH AND ACTION PLAN
Unit
Target
date
Nil
UTAGE-% -UNIT WISE-FIN. YEAR- CUMULATIVE
Y LOSS BREAK UP(STATION)-MONTH WISE:
OSS BREAK UP:
LOSS BREAK UP DUE TO EQUIPMENT(UNIT WISE & MONTH WISE):
NG (%) FOR THE LAST 9 FIN. YEARS (STATION)
OADING--CUMULATIVE-CURRENT FIN. YEAR (%)
NG PARTIAL LOADING
OADING (%) FOR LAST 9 FIN. YEARS (STATION)
DATA AVAILABLE IN ERP : ORT/ZOPNOUTREP
Reason for major Av Loss Present statuResponsibilityCorrective Action
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7/27/2019 Eemg Part 1 (Mou Abt Perf Avf Pl Outage)
88/570
2001-02 2002-03 2003-04 2004-05 2005-06 2006-07 2007-08 2008-09
2009-10 Till
Date
2008-09
(Same
Period)
3.45 4.33 2.60 1.00 0.55 0.31 0.65 0.69 0.25 1.10
2.76 2.94 1.73 0.62 0.39 0.27 0.20 0.33 0.15 0.59
0.69 1.40 0.87 0.38 0.16 0.20 0.11 0.24 0.01 0.39
0.00 0.00 0.00 0.00 0.00 0.00 0.02 0.02 0.00 0.00
0.00 0.00 0.00 0.00 0.00 0.36 0.32 0.11 0.05 0.00
IAL LOADING- MONTHWISE & CUMULATIVE (CURRENT FIN. YEAR (%))
Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar Cum
% % % % % % % % % % % % %
0 0 0 0.016 0.021 0.007
0 0 0 0.105 0.021
0 0 0 0 0
0 0 0 0.009 0.002
0 0 0 0 0
0 0 0 0 0
0 0 0 0 0
0 0 0.002 0.036 0 0.0080.084 0.619 0.052 0.008 0 0.154
0 0 0 0 0
0.033 0.057 0.166 0 0.051
0 0 0 0 0
0 0 0 0 0
-4.305 -3.352 -3.512 -3.767 -3.979 -3.781
0.033 0.057 0.166 0.016 0.135 0 0 0 0 0 0 0 0.081
0 0 0.002 0.036 0 0 0 0 0 0 0 0 0.008
0.084 0.619 0.052 0.008 0 0 0 0 0 0 0 0 0.154
0 0 0 0 0 0 0 0 0 0 0 0 0
MONTH & ACTION PLAN FOR REDUCING PARTIAL LOADING
Unit
Target
date
LOADING (STATION) MONTHWISE,%:
NT PARTIAL LOADING UNITWISE-MONTHWISE (%)-
L PARTIAL LOADING UNITWISE-MONTHWISE (%)-
AVAILABLE IN ERP : ORTZOPNLOSS
AVAILABLE IN ERP : ORTZOPNLOSS
Corrective Action Responsibility
AS
DISTURBANC
Present statuReason for major Partial Loading
RICAL SYSTEM
ARIES
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al M-MU Total M-% Total Y-MU Total Y-%
STAGE3 M-
MU
STAGE3 M-
%
STAGE3 Y-
MU
STAGE3 Y-
%
UNIT05 M-
MU
UNIT05 M-
%
UNIT05 Y-
MU
UNIT05 Y-
%
STAGE2 M-
MU
STAGE2 M-
%
781.200 0.000 3855.600 0.000 156.240 0.000 771.120 0.000 156.240 0.000 771.120 0.000 312.480 0.000
778.964 99.714 3818.157 99.029 163.044 104.355 798.998 103.615 163.044 104.355 798.998 103.615 309.860 99.162
2.236 0.286 37.443 0.971 -6.804 -4.355 -27.878 -3.615 -6.804 -4.355 -27.878 -3.615 2.620 0.838
32.274 4.131 173.901 4.510 0.000 0.000 0.924 0.120 0.000 0.000 0.924 0.120 13.325 4.264
-30.038 -3.845 -136.458 -3.539 -6.804 -4.355 -28.802 -3.735 -6.804 -4.355 -28.802 -3.735 -10.705 -3.426
0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000
0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000
0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000
0.162 0.021 0.285 0.007 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.061 0.019
0.819 0.105 0.819 0.021 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.257 0.082
0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000
0.067 0.009 0.067 0.002 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.0000.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000
0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000
0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000
0.000 0.000 0.297 0.008 0.000 0.000 0.033 0.004 0.000 0.000 0.033 0.004 0.000 0.000
0.000 0.000 5.923 0.154 0.000 0.000 1.548 0.201 0.000 0.000 1.548 0.201 0.000 0.000
0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000
0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000
0.000 0.000 1.949 0.051 0.000 0.000 0.130 0.017 0.000 0.000 0.130 0.017 0.000 0.0000.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000
0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000
-31.085 -3.979 -145.797 -3.781 -6.804 -4.355 -30.513 -3.957 -6.804 -4.355 -30.513 -3.957 -11.022 -3.527
VAILABLE IN ERP : ORTZOPNLOSS
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M- UNIT04 M-
%
UNIT04 Y-
MU
UNIT04 Y-
%
UNIT03 M-
MU
UNIT03 M-
%
UNIT03 Y-
MU
UNIT03 Y-
%
STAGE1 M-
MU
STAGE1 M-
%
STAGE1 Y-
MU
STAGE1 Y-
%
UNIT02 M-
MU
UNIT02 M-
%
UNIT02 Y-
MU
240 0.000 771.120 0.000 156.240 0.000 771.120 0.000 312.480 0.000 1542.240 0.000 156.240 0.000 771.120
720 94.547 654.278 84.848 162.140 103.776 792.507 102.773 306.060 97.945 1572.374 101.954 162.505 104.010 790.678
520 5.453 116.842 15.152 -5.900 -3.776 -21.387 -2.773 6.420 2.055 -30.134 -1.954 -6.265 -4.010 -19.558
279 8.499 138.089 17.908 0.046 0.029 4.624 0.600 18.949 6.064 30.265 1.962 0.704 0.450 12.019
759 -3.046 -21.247 -2.755 -5.946 -3.805 -26.011 -3.373 -12.529 -4.010 -60.399 -3.916 -6.969 -4.460 -31.577
000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000
000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000
000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000
061 0.039 0.167 0.022 0.000 0.000 0.001 0.000 0.101 0.032 0.117 0.008 0.002 0.001 0.002
138 0.088 0.138 0.018 0.119 0.076 0.119 0.015 0.563 0.180 0.563 0.036 0.141 0.090 0.141
000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000
000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.067 0.021 0.067 0.004 0.027 0.017 0.027000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000
000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000
000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000
000 0.000 0.009 0.001 0.000 0.000 0.009 0.001 0.000 0.000 0.246 0.016 0.000 0.000 0.104
000 0.000 0.345 0.045 0.000 0.000 1.695 0.220 0.000 0.000 2.335 0.151 0.000 0.000 1.072
000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000
000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000
000 0.000 0.826 0.107 0.000 0.000 0.501 0.065 0.000 0.000 0.492 0.032 0.000 0.000 0.492000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000
000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000
958 -3.173 -22.732 -2.948 -6.064 -3.881 -28.335 -3.675 -13.259 -4.243 -64.217 -4.164 -7.137 -4.568 -33.414
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93/570
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94/570
-
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M- UNIT01 Y-
MU
UNIT01 Y-
%
000 771.120 0.000
881 781.696 101.372
119 -10.576 -1.372
678 18.246 2.366
559 -28.822 -3.738
000 0.000 0.000
000 0.000 0.000
000 0.000 0.000
064 0.115 0.015
270 0.422 0.055
000 0.000 0.000
026 0.040 0.005000 0.000 0.000
000 0.000 0.000
000 0.000 0.000
000 0.142 0.018
000 1.263 0.164
000 0.000 0.000
000 0.000 0.000
000 0.000 0.000000 0.000 0.000
000 0.000 0.000
918 -30.803 -3.995
-
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96/570
2002-03 2003-04 2004-05 2009-10 Till Date
427 7.2482306 6.0715505 6.2095605 3.3407952
196 3.5681507 0 0.0694635 0
477 2.9365229 1.7282412 0.6236529 0
0 0 0 0 1.1695534
0 0 0 0 1.1695534
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97/570
-
7/27/2019 Eemg Part 1 (Mou Abt Perf Avf Pl Outage)
98/570
SIS & RESTORATION
AGES (STATION) FOR LAST 5 YEARS (No.):
ZERO FORCED OUTAGE".
CUREMENT AS PER ACTION PLAN
N PLAN OF LAST FINANCIAL YEAR:
TRIPPING:
ES:
ERS:
R OF OUTAGES (STATION) FOR LAST 5 YEARS (No.):
2009-10
Till Date
(Same
Period)
15 23
12 19
CHIEVE 'ZERO FORCED OUTAGE".
or action points for each section/ category
IAL PROCUREMENT AS PER ACTION PLAN
quipment
closed File
gese
s
Present status
15
12
0
5
10
15
20
25
30
2009-10 Till Date
No.
TREND OF NUMBER OF OUTAGES FOR LAST 5 FIN.YEAR
Total ForcedOutages
Click to go
DATATABLE
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99/570
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100/570
6/7/2009
Unit Running
Normal
8/21/2009
Unit Running
Normal
8/9/2009
Unit Running
Normal
8/31/2009
Unit Under Planned
Shut Down
8/1/2009
Unit Running
Normal
8/29/2009
Unit Running
Normal
HE ACTION PLAN OF LAST FINANCIAL YEAR:
Outage
No./ Date
Target
Date
Present
Status
OF UNITS *
Outage
no./Date
Responsibility
1/14.04.2009
2/23.04.2009 TMD
Problems faced
during restoration
1.DR16 in operative2.EF 1 atomising v/v LS not making
3.EF4 HONV LS not making
d sheet (Trip committee Recommendations)
1.point no:1&2-TMD to attend in unit overhaul.
2.point 3 attended .
1.In ATRS mode, trip oil pressure coming down while
opening stop valves.
2. HPSV 2,IPSV 2 not opening from UCB.
3.MS 101,105 Jamming.
-atteded
Corrective actions
-
7/27/2019 Eemg Part 1 (Mou Abt Perf Avf Pl Outage)
101/570
-
7/27/2019 Eemg Part 1 (Mou Abt Perf Avf Pl Outage)
102/570
3/28.04.2009 19:45 23:16 21:30 22:58 23:09 23:36
4/10.05.2009 11:46 14:55 13:45 15:46 15:55 16:10
5/06.06.2009 19:33 20:00 19:34 21:04 21:07 21:20
6/07.06.2009 4:40 5:44 4:41 7:56 8:00 8:10
7/25.04.2009 21:37 2:50 23:55 15:17 16:38 22:25
8/19.06.2009 18:03 19;42 19:00 20:25 20:38 21:16
9/24.06.2009 23:37 00;07 23;38 0:54 00;54 1:0310/26.06.2009 12:13 12:50 12:14 13:12 13:13 13:28
11/01.08.2009 20:45 23:10 21:50 23:30 23:33 23:59
12/09.08.2009 14:17 15:15 14:18 15:42 15:49 16:07
13/18.08.2009 4:50 8:00 6:59 8:36 8:51 15:38
14/29.08.2009 1:09 2:23 2:00 3:27 3:32 4:10
ARAMETERS
Unit DESIGNVALUE
After Boiler
Light Up
Before HP-LP
Bypass charging
Before Turbine
Rolling
After Unit
Synchronisation
60% load
:Cold warm
ature Deg C 113.28 113.28 249 250 316
Ksc 10.5 10.5 10.5 10.5 10.5
oC 110 110 110 110 110
Ksc 11 11 11 11 11
TPH 307 307 399 485 610
% 19 19 13 7.7 3.3
KSC 0.66 0.66 44.19 56 96
temp 0 C 63.72 63.72 171 178 230
15.04.2009
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7/27/2019 Eemg Part 1 (Mou Abt Perf Avf Pl Outage)
103/570
0C 74.22 74.22 198 190 298
0C 36.38 36.38 70 75 113
mp 0 C 65.43 65.43 168 175 240
0C 72.02 72.02 194 198 295
0C 36.87 36.87 67 72 95
mp 0 C 58.5 58.5 129 146 235
mp 0 C 55.5 55.5 154 160 236
0C - - 450/450 465 515/515
(blr 0 C - - 434/434 472 514/515
ppm
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104/570
old HOT
ure Deg C 330 330 318 330 330
Ksc 11.7 11.7 10.5 10.5 10.5
oC 109 109 10.53 10.53 10.53
Ksc 10.5 10.5 109 10.73 10.73
TPH 401 401 396 600 600
% 10.44 10.44 10.4 6 6
KSC 98 98 109 115 115
mp 0 C 229 229 227 267 267
0C 249 249 251 305 305
0C 105 105 103 129 129
mp 0 C 226 226 225 301 301
0 C 249 249 250 308 308
0C 97 97 95 129 129
mp 0 C 238 238 233 310 310
mp 0 C 240 240 233 308 308
0C 508 508 512 525/528 525/528
(blr 0 C 488 488 489 530/530 530/530
ppm
-
7/27/2019 Eemg Part 1 (Mou Abt Perf Avf Pl Outage)
105/570
r 0 C 119 119 125 220 220
w 0 C 175 175/388 247/578 434/440 434/440
0C 388 750 750 780 780
tph 26 26 26 95 95
mp. 0 C 508/489 508/489 512/489 523/543 523/543
RAMETERS
Unit DESIGNVALUE
After Boiler
Light Up
Before HP-LP
Bypass charging
Before Turbine
Rolling
After Unit
Synchronisation
60% load
old warm
ure Deg C 107 107 286 312 312
Ksc 11 11 11 11 11
o C 110 110 110 110 110
Ksc 12 12 12 12 12
TPH 304 304 368 523 523
% 19.6 19.6 17 3 3
KSC 0.9 0.9 55 116 116
mp 0 C 65 65 166 229 229
0C 74 74 186 263 263
29.04.2009
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7/27/2019 Eemg Part 1 (Mou Abt Perf Avf Pl Outage)
106/570
0C 44 44 80 98 98
mp 0 C 69 69 170 234 234
0C 75 75 190 273 273
0C 43 43 80 96 96
mp 0 C 47 47 118 216 216
mp 0 C 47 47 148 226 226
0C -/- -/- 435/435 467/467 467/467
(blr 0 C -/- -/- 415/415 484/484 484/484
ppm
-
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107/570
ure Deg C 116 150 235 301 301
Ksc 12 11 11 11 11
oC 98 97.4 97.4 97.4 97.4
Ksc 13.5 12 12 12 12
TPH 300 350 400 573 573
% 11.3 11.3 11 5 5
KSC 0.4 8.8 47 99.7 99.7
mp 0 C 63 156 207 237 237
0C 77 193 255 274 274
0C 33 56 80 98 98
mp 0 C 68 162 212 236 236
0C 77 190 257 277 277
0 C 36 62 86 102 102
mp 0 C 37 60 198 237 237
mp 0 C 41 73 202 241 241
0C - - 384/376 450/450 450/450
(blr 0 C - - 380/380 430/430 430/430
ppm
-
7/27/2019 Eemg Part 1 (Mou Abt Perf Avf Pl Outage)
108/570
w 0 C 0 50/58 100/100 521/472 521/472
mm of wc 0 0 780 805 805
tph 0 0 17 85 85
mp. 0 C 94/85 240/111.5 390/400 459/436 459/436
RAMETERS
Unit DESIGNVALUE
After Boiler
Light Up
Before HP-LP
Bypass charging
Before Turbine
Rolling
After Unit
Synchronisation
60% load
old Hot
ure Deg C 305 305 298 318 318
Ksc 10 10 10 10 10
oC 105 105 105 105 105
Ksc 11 11 11 11 11
TPH 442 442 420 542 542
% 11.5 11.5 11 8/6 8/6
KSC 28 28 80 100 100
mp 0 C 210 210 250 280 280
0C 260 260 288 320 320
0C 80 80 102 105 105
06.06.2009
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109/570
-
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110/570
Ksc 11.5 11.5 11.5 11.5 11.5
oC 105 105 105 105 105
Ksc 12.2 12.2 12.2 12.2 12.2
TPH 319 319 350 530 530
%9.9 9.9 9.98 4.5 4.5
KSC 70 70 98 106 106
temp 0 C 210 210 212 226 226
p 0 C 238 238 211 279 279
mp 0 C 95 95 29 98 98
temp 0 C 205 205 231 221 221
0C 234 234 205 278 278
p 0 C 91 91 29 98 98
temp 0 C 250 250 228 231 231
temp 0 C 246 246 225 231 231
0C 350/350 350/350 390/390 537/537 537/537
HS (blr 0 C 357/357 357/357 405/405 530/530 530/530
ppm
-
7/27/2019 Eemg Part 1 (Mou Abt Perf Avf Pl Outage)
111/570
mm of wc 588 588 700 740 740
tph 0 0 15 82 82
mp. 0 C 338/317 338/317 375/399 531/537 531/537
RAMETERS
Unit DESIGNVALUE
After Boiler
Li ht U
Before HP-LP
B ass char in
Before Turbine
Rollin
After Unit
S nchronisation
60% load
old Cold
ure Deg C 92 92 244 292 292
Ksc 10 10 10 10 10
oC 110 110 11 110 110
Ksc 12 12 12 12 12
TPH 294 294 279 562 562
% 17 17 17 6.58 6.58
KSC 2.49 2.49 32 96 96
mp 0 C 73 73 159 245 245
0C 86 86 177 274 274
0C 54 54 80 109 109
mp 0 C 73 73 159 243 243
15.06.2009
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112/570
0C 89 89 174 281 281
0C 45 45 82 109 109
mp 0 C 52 52 125 235 235
mp 0 C 41 41 121 241 241
0C 132/132 132/132 357/357 455/455 455/455
(blr 0 C 36/36 36/36 357/357 465/465 465/465
ppm
-
7/27/2019 Eemg Part 1 (Mou Abt Perf Avf Pl Outage)
113/570
oC 112 112 110 110 110
Ksc 13 13 13 13 13
TPH 372 372 370 623 623
% 18.2 18.2 17 6 6
KSC 5.3 5.3 60 95 95
mp 0 C 110 110 220 241 241
0C 135 135 270 298 298
0C 43 43 85 104 104
mp 0 C 105 105 221 232 232
0C 134 134 271 295 295
0C 52 52 86 94 94
mp 0 C 74 74 200 241 241
mp 0 C 70 70 200 232 232
0C 356/356 356/356 455/460 526/526 526/526
(blr 0 C 298/298 298/298 450/460 515/515 515/515
ppm
-
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114/570
-
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115/570
0C 93 93 90 99 99
mp 0 C 238 238 218 242 242
mp 0 C 234 234 215 238 238
0C 451/451/ 451/451/ 520/520 530/530 530/530
(blr 0 C 437/437 437/437 515/515 530/530 530/530
ppm
-
7/27/2019 Eemg Part 1 (Mou Abt Perf Avf Pl Outage)
116/570
-
7/27/2019 Eemg Part 1 (Mou Abt Perf Avf Pl Outage)
117/570
tph 17 17 42 98 98
mp. 0 C 367/342 367/342 500/498 524/526 522/523
RAMETERS
Unit DESIGNVALUE
After Boiler
Light Up
Before HP-LP
Bypass charging
Before Turbine
Rolling
After Unit
Synchronisation
60% load
old warm
ure 120 175 227 283 283
12 12 12 12 12
110 110 110 110 110
12.5 12.5 12.5 12.5 12.5
300 300 423 637 637
18 18 14.27 4.98 4.98
0.78 8.5 39.62 117.87 117.87
01.08.2009
-
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118/570
-
7/27/2019 Eemg Part 1 (Mou Abt Perf Avf Pl Outage)
119/570
Unit DESIGNVALUE
After Boiler
Light Up
Before HP-LP
Bypass charging
Before Turbine
Rolling
After Unit
Synchronisation
60% load
old HOT
ure 325 325 312.5 318.3 318.3
11 11 10.5 10.5 10.5
100 100 96 100 100
12 12 12.1 12 12
320 320 392 517 517
11.3 11.3 11.3 3 3
61 61 96 86 86
mp 234 234 240 244 244
275 275 287 299 299
95 95 104 129 129
mp 243 243 242 259 259
265 265 285 298 298
129 129 100 119 119
mp 277 277 242 249 249
mp 277 277 244 282 282
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7/27/2019 Eemg Part 1 (Mou Abt Perf Avf Pl Outage)
120/570
378/377 378/377 514/502 529/516 529/516
(blr 420/420 420/420 487/478 510/522 510/522
0.1 0.1 0.15 0.25 0.25
r 108 108 133 139 139
w - - 185/190 441/409 441/409
- - 80 770 770
- - 32 87 87
mp. NA/428 NA/428 NA/500 NA/548 NA/548
RAMETERS
Unit DESIGNVALUE
After Boiler
Light Up
Before HP-LP
Bypass charging
Before Turbine
Rolling
After Unit
Synchronisation
60% load
old Warm
ure 122 232 234 310 310
10 10 10 10 10
108 108 108 108 108
13 13 13 13 13
318 395 342 690 690
10.23 10.59 10.59 5 5
21.08.2009
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4.5 30 30 107 107
mp 135 193 192 288 288
145 226 219 319 319
50 92 90 122 122
mp 140 176 175 275 275
145 225 215 318 318
52 79 85 127 127
mp - 140 148 320 320
mp - 159 159 287 287
153/154 335/342 335/336 540/535 540/535
(blr 69/68 329/330 335/336 501/525 501/525
0.18 0.186 0.186 0.18 0.18
r 78 80 80 151 151
w -/'- 78/85 78/85 614/540 614/540
- - 800 830 830
- - - 123 123
mp. 160/119 440/363 440/364 540/530 540/530
RAMETERS
30.08.2009
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Unit DESIGNVALUE
After Boiler
Light Up
Before HP-LP
Bypass charging
Before Turbine
Rolling
After Unit
Synchronisation
60% load
old Hot
ure 226 226 317 317 317
10.75 10.75 10.4 10.3 10.3
104.7 104.7 107 108 108
12.3 12.3 12.3 12.06 12.06
281 281 387 552 552
19.3 19.3 10.6 2.92 2.92
8 8 85.8 102.6 102.6
mp 128 128 199 238 238
144 144 227 267 267
56 56 86.9 101 101
mp 132 132 195 235 235
28 28 230 284 284
68 68 70 95 95
mp 112 112 132 221 221
mp 108 108 191 232 232
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25/343 25/343 509/499 515/515 515/515
(blr - - 490/488 518/518 518/518
0.068 0.068 0.068 0.029 0.029
r 110 110 110 173 173
w - - 179/262 403/438 403/438
- - 675 708 708
- - 17 97 97
mp. 180/171 180/171 502/479 515/518 515/518
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126/570
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127/570
-
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128/570
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N1
(RPM)
N2
(RPM)
Full Load REMARKS
ld/warm /
ed on
r (RPM)
600 3000 3000
am
/Cm2)
88 85 150
Stage
ure
12 15 147
team
/Cm2)
12 12 36
e -De C
510 508 540
e-Deg C
322 335 339
e-Deg C
503 502 537
id wall 499 501 519
45 52 22
acuum- 0.1 0.1 0.11
NS:16/17/27/1
9/741//37/37
/23/4663/74/34/52/14
NS:
1/0/1/0/0/0
/6
2/3/4/2/3
/1/15
5/2/11/8/2/7/11
EMP.
/2/3/4
51/51/63/5
5
65/60/81/
80/
67/59/87/81
5/6/7 30/49/48 73/74/65 /74/74/64
FT: -0.22 -0.22 -0.2
VE EXP.: -0.12 0.01 -0.76
VE EXP.: 2.5 2.97 5.6
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ld/warm /
warm
ed on
r (RPM)
600 3000 3000
am
/Cm2)
51 51 149
Stage
ure
6.9 8.9 138
team
/Cm2)
10 10 35
e -De C
380 390 535
e-De C
262 265 340
e-Deg C
390 395 535
id wall 284 288 509
50 70 30
acuum- 0.075 0.075 0.09
NS:
54/12/16/
19
39/26/7/6
2
24.8/37.5/9.6/72
.4
NS:2/0.5/2/3/
8/182/3/6/13/
22/40 4/1/6/12/14/35
EMP.
/2/3/4
44/46/58/
55
55/65/78/
73 61/66/88/80
5/6/7 57/58 77/65 82/66
FT: -0.16 -0.15 -0.34
VE EXP.: -0.83 -0.63 0.46
VE EXP.: 0.23 0.39 4.59
VE EXP.: 3.01 1.91 11.87
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EXP: AT 24.1 24.1 23.6
EXP: IP 5.6 5.4 9.8
ART UP PARAMETERS
N1
(RPM)
N2
(RPM)
Full Load REMARKS
ld/warm /
Hot
ed on
r (RPM)
600 3000 3000
am
/Cm2)
96 96 147
Stageure
10.8 12 137
team
/Cm2)
12 12 36
e -Deg C
505 505 540/540
e-De C
313 313 342
e-De C
500 500 532/533
id wall 491 491 511
- - -
GN
UE
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acuum- 0.09 0.09 0.08
NS:
35/45/12/5
0
35/48/12/
58
22/48/8/72
NS:
1.5/0.5/2.1/
5.3/12
3/2/5/14/
26.4/24.5 3/3/8/10/18/35
EMP.
/2/3/4
48/49/58/5
6
51/47/73/
65 62/51/90/75/
5/6/7 55/58 73/63 81/65
FT: -0.3 -0.36 -0.37
VE EXP.: -0.47 -1.36 0.4
VE EXP.: 0.8 0.97 4.61
VE EXP.: 6.7 8.92 11.9
EXP: AT 23 23.1 23.5
EXP: IP 9.6 9.8 10
ART UP PARAMETERS
N1
(RPM)
N2
(RPM)
Full Load REMARKS
ld/warm /
Hot
GN
UE
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NS:
7/12/18/2
0/9
87/32/36/
27/33
62/25653741
NS:
2.64/0.93/1/2/0.
2/0.4/0.29
7/3/3/10/1/10/
24/8/3/15/3/22/10
EMP.
/2/3/4
44/44/57/
52/
58/58/78/
75/ 61/64/88/81
5/6/7 51/51/46 67/69/49 74/73/82
FT: -0.14 -0.16 -0.39
VE EXP.: 1.11 2.8 -0.65
VE EXP.: 2.33 2.6 8.44
VE EXP.: 7.62 7.76 13.63
EXP: AT 4.65 6.33 25.14
EXP: IP 0.31 0.35 8.67
ART UP PARAMETERS
N1
(RPM)
N2
(RPM)
Full Load REMARKS
ld/warm /
warm
ed on
r (RPM)
600 3000 3000
GN
UE
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ART UP PARAMETERS
N1
(RPM)
N2
(RPM)
Full Load REMARKS
ld/warm /
Hot
ed on
r (RPM)
600 3000 3000
am
/Cm2)
80 80 145
Stage
ure
15 15 142
team
/Cm2)
11 11 33.8
e -Deg C510 510 537
e-Deg C
335 335 341
e-Deg C
515 515 538
id wall 510 510 502
45 42 80
acuum- 0.1 0.1 0.085
NS:
125/20/33/
20
106/33/31
/43/24
69/26/65/35/42
GN
UE
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NS:
6/3/2/10/2/
8/1
7/3/1/11/1
/11/1
5/3/2/22/2/25/
9
EMP.
/2/3/4
47/47/62/5
7
58/60/83/
81
60/65/87/81
5/6/7 55/55/58 76/74/52 72/72/52
FT: -0.49 -0.45 -0.38
VE EXP.: -1.08 -1.1 -0.44
VE EXP.: 2.83 2.69 5.01
VE EXP.: 11.14 11.03 13.34
EXP: AT 25.14 25.1 25.14
EXP: IP 8.67 8.69 8.57
ART UP PARAMETERS
N1
(RPM)
N2
(RPM)
Full Load REMARKS
ld/warm /
Hot
ed on 600 3000 3000
GN
UE
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am
/Cm2)
90 91 146
Stage
ure
14 19 143
team
/Cm2)
11 12 34
e -Deg C
500 500 538
e-Deg C
335 339 342
500 500 537
id wall 509 509 505
44 49 77
acuum- 0.1 0.1 0.09
NS:
120/19/31/
21
113/31/2
7/50/27
70/25/64/34/42
NS:
5/2/2/9/2/9
/28/3/1/9/
1/11/2
5/3/2/21/2/24/
10
EMP.
/2/3/4
48/48/63/5
7
53/55/7
0/65
60/65/86/80
5/6/7 54/55/57 64/64/49 72/71/52
FT: -0.48 -0.45 -0.37
VE EXP.: -1.04 -0.65 -0.44
VE EXP.: 2.87 2.01 5.01
VE EXP.: 11.1 11.31 1.25
EXP: AT 25.1 25.14 25.12
EXP: IP 8.3 8 8.6
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ART UP PARAMETERS
N1
(RPM)
N2
(RPM)
Full Load REMARKS
ld/warm /
warm
ed 650 3000 3000
am
/Cm2)
40 40 145.8
Stage
ure
5.66 8.98 143
team
/Cm2)
8 7.56 33.7
e -Deg C
380 380 537
e-Deg C
282 282 341
GN
UE
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e-Deg C
370 370 537
id wall 244 248 508
61.62 48.55 69
acuum- 0.076 0.08 0.09
NS:
16/19/20/2
2/9
73/33/37/
28/30
69/25/65/34/41
NS:
2/1/0/3/0/0
/0
5/6/3/13
/1/9/1
5/3/2/21/2/24/
10
EMP.
/2/3/4
44/456/48/
53
51/55/5
6/80
60/64/85/79
5/6/7 65/58/47 72/60/50/ 72/71/53
FT: -0.24 -0.26 -0.37
VE EXP.: -0.03 -0.09 -0.4
VE EXP.: 1.13 0.84 4.8
VE EXP.: 6.31 4.53 12
EXP: AT 11.66 11.34 25
EXP: IP 4.47 4.45 8
ART UP PARAMETERS
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FT: -0.3 -0.34 -0.25
VE EXP.: -1.2 -0.9 0.8
VE EXP.: 1.2 1 4.4
VE EXP.: 8.5 6.8 11.2
EXP: AT 23.6 23.4 23.2
EXP: IP 10.1 10.1 9.9
ART UP PARAMETERS
N1
(RPM)
N2
(RPM)
Full Load REMARKS
warm
ld/warm /
ed on
r (RPM)
600 3000
am
/Cm2)
30 30 146
Stage
ure
3.9 8 138.5
team
/Cm2)
5 3.45 35
e -Deg C
335 352 538
GN
UE
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e-Deg C
250 218 342
e-Deg C
335 350 530
id wall 234 235 538
- - -
acuum- 0.13 0.1 0.07
NS:
2.7/25.4/20
.4
83/23/76/
23
105/25/70/33
NS:
4/2.3/5/6/2
23/23
6/5/16/1
0/21/12/
7/17
10/13/16/15/1
5/15
EMP.
/2/3/4
52/45/56/5
676/65/9
5/80
73/70/98/82
5/6/7 56/55 80/69 84/73
FT: 0.214 0.3 -0.13
VE EXP.: -0.6 -0.154 -1.6
VE EXP.: 0.39 0.94 3.15
VE EXP.: 14.64 14.654 14.65
EXP: AT 4.64 4.53 21.22
EXP: IP 2.12 2.21 8.76
ART UP PARAMETERS
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N1
(RPM)
N2
(RPM)
Full Load REMARKS
Hot
ld/warm /
ed on
r (RPM)
600 3000
am
/Cm2)
86 74 144
Stage
ure
10.55 13.4 144
team
/Cm2)
9.72 10.7 34.5
e -Deg C
422 454 535
e-Deg C
284 282 338
e-Deg C
456 467 542
id wall 420 419 472
53 41 112
acuum- 0.128 0.128 0.095
NS:
18.75/41/2
9/28
80/31/47/
38/34
59/30/71/39/36
NS:
2/3/4/5/0.2/
2.4/1.177/2/2/6/
2/12/4
4/5/2/21/2/22/
11
EMP.
/2/3/4
48/46/61/5
664/60/8
7/7
64/65/88/82
5/6/7 54/55/48 73/73/52 74/73/53
GN
UE
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FT: -0.31 -0.28 -0.22
VE EXP.: -0.41 -0.41 0.89
VE EXP.: 0.95 1.11 5.25
VE EXP.: 9.36 9.24 13.3
EXP: AT 21.64 21.21 22.05
EXP: IP 8.5 8.5 8.09
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ed
aebareli
NG RECOMMENDATIONS SUMMERY(2008-2009)
)
. :
:
RIPPING :
RIPPING :
site) :
RECOMMEND
ATIONS (By
site) :
Action taken /
To be taken by
Present status
RECOMMEND
ATIONS (By
OS NR)
Action to be
taken by
Present status
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ed
aebareli
NG RECOMMENDATIONS SUMMERY(2008-2009)
)
. :I/08-09/02
: 0702
RIPPING 14/05/2008
RIPPING : 15:29 Hrs.
site) : Unit was running normal with mill A, B,C & D in service without oil suppor
as found that all feeders connected to 220 KV Main Bus II (GT I, ST-I and trans
wing in the system (because of storm) resulted in overvoltage of Raebareli III line of generator breaker at full load resulted in tripping of turbine on electrical oversp
RECOMMEND
ATIONS (By
site) :
Action taken /
To be taken by
Present status
PSL of
Numerical relay
should be part of
approved relay
setting and
should befactory tested
during PDI.
PE ( Electrical) Letter given to
AGM ( COS) by
AGM (O&M)
RECOMMEND
ATIONS (By
OS NR)
Action to be
taken by
Present status
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PSL of
numerical relay
should be
configured by
electrical
maintenance
group at site as
per approved
protection
scheme and
tested by
simulation
before putting
the numerical
relay in
operation
ed
aebareli
NG RECOMMENDATIONS SUMMERY(2008-2009)
)
. :I/08-09/06
: 1108
RIPPING 06/09/2008
RIPPING :13:21 Hrs.
site) : Unit was running at 200 MW with mill A,B,C,D in service without oil supp
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On checking it
was found that
BFP-A tripped
on Negative
Phase Sequence
due to reverse
connection of
one CT of BFP-
A.
RECOMMEND
ATIONS (By
site) :
Action taken /
To be taken by
Present status
BFP discharge
Pressure Very
low Protection
to be removed inline with st-II &
st-III.
DGM ( C& I) Implemented
RECOMMEND
ATIONS (By
OS NR)
Action to be
taken by
Present status
ed
aebareli
NG RECOMMENDATIONS SUMMERY(2008-2009)
)
. :I/08-09/07
: 0509
RIPPING 11/10/2008
RIPPING : 17:13 Hrs
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site) : Unit was running at 218 MW with mill ABCD in service, without oil suppor
Hrs. Mill- F and all oil guns were taken out. Load increased to 218 MW at 17:04
continuous high FW flow of around 800 T / Hr drum level started increasing and
ysis it was found that with the increase of firing, load increased to 218 MW from 1
RECOMMEND
ATIONS (By
site) :
Action taken /
To be taken by
Present status
Tuning of Drum
level control
loop to be done,
till such time
during
disturbance
drum level
controller may
be taken inmanual.
C&I Implemented
RECOMMEND
ATIONS (By
OS NR)
Action to be
taken by
Present status
Legible SOE and
related
parameters color
trends needs to
be attached with
trip report for
better tripanalysis.
Reason for mill-
B tripping is not
established. All
the alarm points
for the mill
tripping needs to
be properly
checked for all
the units of unit#1
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Bearing capable
of high variable
dynamic load
and axial
displacement
suitable to fan
needs to be used
RECOMMEND
ATIONS (By
OS CC)
Action to be
taken by
Present status
Both ID fan A &
B bearings were
replaced during
the last OH.
Bearing damage
of both fanswithin two
months of
completion of
overhaul
indicates that the
quality of work
done on ID fans
during OH was
not OK.
As given in site
recommendation( Separately
annexed in trip
analysis report
,only genuine
bearings from
OEM are to be
procured.
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One Fan was
under shutdown
and other fan
was running
with abnormal
condition. In
such a situation,
the loading of
the fan should
have been
regulated
keeping a close
watch on bearing
temp. Operating
staff have to be
instructed
accordingly
ed
aebareli
NG RECOMMENDATIONS SUMMERY(2008-2009)
)
. :I/08-09/09
: 0502/0601
RIPPING : 02/11/2008
RIPPING : 13:18 Hrs.
site) : Unit was running at 210 MW with mills A, B, C & D in service without oil s
king it was found that BFP C Discharge pressure very low protection was earlie
RECOMMEND
ATIONS (By
site) :
Action taken /
To be taken by
Present status
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BPF
recirculation
valve should be
in open
condition along
with discharge
valve in auto
standby mode as
provided in Unit
#2 logic
DGM ( C& I) Implemented
RECOMMEND
ATIONS (By
NR OS)
Action to be
taken by
Present status
Whenever
normalization of
protection is
being carried out
by C&Imaintenance
person should
ensure whether
any trip
condition persist
,or not .A
documented
procedure
should be made
available for
working of critical
equipments.
Site
recommendation
for review of
protection may
please be seen
by OS-CC and if
found in order
may please be
concurred by PECC
RECOMMEND
ATIONS (By
OS CC)
Action to be
taken by
Present status
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The bypassing
and
normalization of
protection shall
be done by C& I
only after
ensuring that no
trip command is
present .such
bypassing or
normalising
should be
recorded in
register.
Tripping
analysis report
should contain
one trip codeonly based on
root cause
analysis. In this
case , human
error code is
Any proposal for
modification of
protection
should be sent
separately to CC
OS after approval of
station head.
Bypassing /
normalizing of
protection
should be
defeated in OWS
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RECOMMEND
ATIONS (By
site) :
Action taken /
To be taken by
Present status
DGM ( C & I )
DGM ( EMD)
PE
(Elect / C & I)
RECOMMEND
ATIONS (By
OS NR)
Action to be
taken by
Present status
HT breaker ON
status is to beused in logic and
interlock after
ANDing with
service remote
status in
DDCMIS.
ited
ebareli
ONS SUMMERY(2008-2009)
13/03/2009)
II
HT breakerOn
status is to be
used in logic andinterlock after
ANDing with
service remote
status. Necessary
modification is
to be done in
DDCMIS.
Implemented
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13/03/2009)
II
. : III/ 08- 09/04
: 0119
1 DATE OF TRIPPING : 06/09/2008
2 TIME OF TRIPPING :. 9:47 Hrs
Analysis (By
site)
: Unit was
running at 197
MW with mill
AB, EF in
service without
oil support. FRS
control valve
FW-01 was in
service .Gland
leakage was
observed in this
valve.
was
ut the
etween
creased
eakage
took
sitioner
l valve
ve got
ding to
water
boiler
m Level
4 RECOMMEND
ATIONS (By
site) :
Action taken /
To be taken by
Present status
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ebareli
ONS SUMMERY(2008-2009)
13/03/2009)
II
. : III/ 08- 09/ 05
: 0113
1 DATE OF TRIPPING : 13/11/2008
2 TIME OF TRIPPING : 19:05:18
Analysis (By
site)
running normal
with mill -AB
and CD in
service. At 18:28
hrs feeder C
Discharge
plugged and
No coal Flow
alarm appeared.
Mill CD to EF
change over
started at 18:38
hrs. After taking
mill EF End-E
in service, mill-
CD End-C
shutdown
command wasgiven at 19:02
hrs. At 19:05:17
Mill AB and CD
Seal air to mill
DP low and
Transmitter
disturbed alarm
appeared in
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it was
all of
D End
ressure
1031
495
End-
re also
412
166
d outlet
nd C
in the
header
also
ased tom 823
e next
the
essures
reased,
down.
d fall of
primary
ight be
aneous
thein the
of CD.
urbance
the
header
tuation
ressure
tection
ng of
of all
4 RECOMMEND
ATIONS (By
site) :
Action taken /
To be taken by
Present status
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Screw conveyor
vibration
monitoring is to
be done on trial
basis in one mill
to detect
breakage of
helix and tie rod.
DGM ( C & I) Is being
implemented in
mill-3CD
DGM (OPN)/
DGM ( BMD )
Mill coal level
measurement
transmitter
impulse line auto
purging to be
ensured to avoid
false level sensing
resulting in lean
air mixture
leading to
explosion.
In case of no coal
flow ,PA flow
reduction
commensurate
to other end coal
flow as mill outlet
temp control to
be done to avoid
any
instantaneous
combustion
/Explosion
6 RECOMMEND
ATIONS (By OS-
CC ) :
Action to be
taken by
Present status
Other
possibilities are
to be explored to
avoid such
conditions.( with
other stations
also)
Consulted with
other projects
5 RECOMMEND
ATIONS (By OS-
CC ) :
Action to be
taken by
Present status
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The
recommendation
given by site done
not match with
analysis of
tripping. Site to
give their
recommendationbased on the trip
analysis
Unit was not
stabilized
following feeder
C discharge
pluggedalarm.Oil
guns cut in to
stabiles the mill
were cut out
quickly
Mill CD was run
for half an hour
with one side
feeder. Such
operation should
be minimized as
this increases the
risk of a mill Fire
ited
ebareli
ONS SUMMERY(2008-2009)
( 13/03/2009)
II
. :
:
1 DATE OF TRIPPING :
OF TRIPPING :
Analysis (By
site) :.
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sis (By
: Unit was
running at 205
MW with mill
A,B,C,D & E in
service, without
oil support. Allof sudden unit
load became
zero and turbine
controller
changed to speed
from load
controller. At
13:53:28 Hrs.
generator,
turbine and
boiler tripped onAnti motoring
Protection (Class
A Protection).
nalysis
at all of
the 4
s of
closing.
he load
demand
controled fully
ed on
otoring
ction.
4 RECOMMEND
ATIONS (By
site) :
Action taken /
To be taken by
Present status
NIL
RECOMMENDATIONS (By
OS-NR ) :
Action to betaken by
Present status
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Oil support
should be taken
during mill
changeover to
stablise the
flame during
poor coal quality
regimes and
withdrawn
gradually after
ensuring flame
stability.
Being followed
ited
ebareli
ONS SUMMERY(2008-2009)
( 13/03/2009)II
. : II/08-09/4
: 0509
1 DATE OF TRIPPING : 09/07/2008
OF TRIPPING : 5:33 hrs
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Analysis (By
site)
: Unit was
running normal
at 217 MW with
mill A,B,C,D
and E in service
without oil
support. All of
sudden all the
mills tripped on
PA header
pressure Very
Low Protection
and unit tripped
in Loss of All
Fuel.
ressure
unningFrom
s found
A fans
ing at
Hrs.
ecrease
ressure
mit. All
mills
header
lowd unit
of all
hrs.
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ping it
hat at -
furnace
D fan-B
,FRS
became
scoops45 %
approx)
ons of
me non
But on
no
was
any
All
foundon for
uld not
Earth
pected,
in any
4 RECOMMENDATIONS (By
site) :
Action taken /To be taken by
Present status
Nil
RECOMMEND
ATIONS (By
OS-NR ) :
Action to be
taken by
Present status
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The control
supply extended
for field
instrumentation
should have
individual
isolation( fuse
provision )so
that the earth
fault in the field
gets isolated on
its own and dose
not cause overall
disruption in the
supply bus.
ited
ebareli
ONS SUMMERY(2008-2009)
( 13/03/2009)
II
. : II/08-09/5
: 0501
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1 DATE OF TRIPPING : 14.07.2008
OF TRIPPING : 14:29:27 hrs.
Analysis (By
site)
: Unit was
running normal
at 213 MW with
coal mill
A,B,C,D and Ein service
without any oil
support. All of a
sudden both the
PA fans got
unloaded .All
mills tripped on
PA Header
Pressure Very
Low protection
and unit trippedon Loss of all
Fuel. Just after
unit tripping it
was observed
that all the push
buttons of the
desk became
inoperative.
hecking
s found
Mill-Bdamper
ch was
ance in
ply was
due to
4 RECOMMENDATIONS (By
site) :
Action taken /To be taken by
Present status
Nil
RECOMMEND
ATIONS (By
OS-NR ) :
Action to be
taken by
Present status
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The control
supply extended
for field
instrumentation
should have
individual
isolation( fuse
provision )so
that the earth
fault in the field
gets isolated on
its own and dose
not cause overall
disruption in the
supply bus.
ited
ebareli
ONS SUMMERY(2008-2009)( 13/03/2009)
II
. : II/08-09/06
: 0114
1 DATE OF TRIPPING : 28/07/2008
OF TRIPPING : 01:12 hrs.
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Analysis (By
site)
: Unit was
running normal
at 215 MW with
mill A, B, C,D &
E in service
without oil
support .At 1:10hrs heavy
hunting was
observed in the
current of R C
feeder A and
mill A .
Immediately
Mill F was
taken in service.
But unit tripped
on FlameFailure
Protection.
ion of
ill -A,
temp
leading
hot air
pening
mper on
This
ance inunit
flame
n.
feeder
nalysis
was as
2 %
4 RECOMMENDATIONS (By
site) :
Action taken /To be taken by
Present status
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Full opening of
the cold air
damper in auto
on mill hot air
gate closing
protection to be
modified.
DGM ( C & I) Implemented
5 RECOMMEND
ATIONS (By
OS-NR ) :
Action to be
taken by
Present status
To prevent entry
of big size coal
,stones, foreign
material etc, in
feeders
,preventive
checkes of the
coal crusher breakers plates
,case screens and
& bunker grill
should be
ensured .
Blending of coal
must be resorted
, to over come
the problems
created by the
the low VM coal
Mill changeover
procedure to be
reviewed and
desk operator to
be advised
accordingly.
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r flow
el flow
were
auto
ripping.
gate of
actuale boiler
7 T/Hr
it load
ing but
al coal
flow
not
because
as in
on. To
ad fueldemand
5 T/hr
Hr and
r flow
3 T /hr
T/Hr.
ue gas
/6.9 %
4 RECOMMEND
ATIONS (Bysite) :
Action taken /
To be taken by
Present status
During furnace
disturbance total
air flow should
be maintained
according to
total fuel flow.
DGM ( OPN) Being followed
RECOMMEND
ATIONS (By
OS-CC ) :
Action to be
taken by
Present status
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The trend report
attached
suggested that
the rise in mill
outlet temp of
mill was gradual
.The desk
operator must
investigate the
abnormal rise in
mill outlet temp
and initiate
corrective
actions . the
cause of rise in
temp is
gradually an
interruption in
coal flow which
will be
associated with a
drop in load or
an interruption
in cold air flow
RECOMMEND
ATIONS (By
OS-CC ) :
Action to be
taken by
Present status
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Unit combustion
control systems
like air and fuel
flow were in
auto at the time
of tripping .
closure of hot air
gate has to be
delt very
carefully in a
case mills
remains in
service and
accumulates coal
bed from feeder
.The following
points need to be
taken care while
handling such an
emergency. :---
Hot air gate
closes in a
running mill due
to coal flow
interruption or
improper
response/ Failure
of temp controlsystem. Such
closing will
initiate Mill
outlet Temp Hi
alarm during
such conditions,
control loop like
fuel ,air shall be
taken out of
auto.
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Efforts should
be made to admit
cold air into mill
and reduce the
feeder speed.
This step will
ensure that
minimum load
reduction takes
place in the unit.
Opening of hot
air gate after
normalizing mill
outlet temp has
to be done very
care fully .All
along mill fuelair ratio should
be maintained.
If there is
difficulty in
admitting cold
air damper into
mill, feeder
should be
stopped
temporarily and
unit load shall bebrought down.
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ited
ebareli
ONS SUMMERY(2008-2009)
( 13/03/2009)
II
. : II/08-09/10 : 0112
1 DATE OF TRIPPING : 05/12/2008
2. TIME OF TRIPPING : 16:34:50 hrs.
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Analysis (By
site)
: Unit was
running at 219
MW with mill B,
C,D,E & F in
service . MillA
was being
normalized aftercancellation of
PTW by BMD.
At 16:33:48 Hrs
mill-C tripped
on thermal
overload.
Immediately
Mill-A was
started and oil
guns tried in AB
elevation .Butguns did not
prove and Flame
Scanners started
flickering .Unit
tripped on
Flame Failure
Protection.
ripped,
urbed (
o -43
A wase. Due
Hot air
ll-A, a
air of
furnace
vation,
upport,
furnace
n and
Flame
n.
4 RECOMMEND
ATIONS (By
site) :
Action taken /
To be taken by
Present status
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Passing of the
Hot air dampers
of mills is to be
arrested.
DGM ( BMD ) Being followed
Thermal
overload relay of
mill-2C is to be
checked.
DGM ( EMD) Checked ,found
O.K
RECOMMEND
ATIONS (By
NR-OS ) :
Action to be
taken by
Present status
when low VM
coal is being
fired ,tripping of
one mill will
result in major
disturbance in
the furnace. Atsuch a point ,it is
advisable to take
oil support and
stabiles the
furnace first
before taking the
other / same
mill in service.
As per
observations
contained in thetrip report of the
shift charge
engineer, mill
C tripped on
thermal overload
while taking 35 -
37 Amp current
which is well
below the trip
value, current
indication errorneeds to be
looked into
along with
checking of
overload relay.
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RECOMMEND
ATIONS (By
OS-CC ) :
Action to be
taken by
Present status
During such
cases of mill
tripping, oil gun
should be proven
first before try to
take another mill
in service. This
will improve the
flame condition
and stabilize the
furnace. Cutting
in of another
new mill will
induce more
disturbance.( A
40 mm
disturbance is
normal and
should not cause
panic)
As per the report
, a passing of 30
T /Hr observed
from mill-A hot
air damper .Thisis very High
level of passing
and it should be
rectified at the
earliest.
mited
ebareli
ONS SUMMERY(2008-2009)
13/03/2009)
V
-
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.
1 DATE OF TRIPPING :
2 TIME OF TRIPPING :
s (By
4 RECOMMEND
ATIONS (By
site) :
Action taken /
To be taken by
Present status
5 RECOMMEND
ATIONS (By
OS-NR) :
Action to be
taken by
Present status
ited
ebareli
ONS SUMMERY(2007-2008)
-
7/27/2019 Eemg Part 1 (Mou Abt Perf Avf Pl Outage)
191/570
02/08/2008)
V
. : IV/ 08-09/01
: 0112
1 DATE OF TRIPPING : 24/05/20082 TIME OF TRIPPING : 00:27 Hrs
Analysis (By
site) : Unit was
running at 175
MW with mill CD
& EF in service
,without oil
support . Due to
low load schedule,while reducing the
load ,furnace got
disturbed and unit
tripped on Flame
Failure
protection.
4 RECOMMEND
ATIONS (By
site) :
Action taken /
To be taken by
Present status
NIL5 RECOMMEND
ATIONS (By
OS-NR) :
Action to be
taken by
Present status
-
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Load reduction
in the boiler
,particularly
during low VM
regimes has to
be done
gradually ,taking
care of all the
parameters
affecting the
combustion , so
that there is
minimum
disturbance to
the flame in the
furnace .if
required , oil
support can be
taken to stabilize
the flame
Being followed
6 RECOMMEND
ATIONS (By
CC-OS)
Action to be
taken by
Present status
ited
ebareli
ONS SUMMERY(2008-2009)
13/03/2009)
V
-
7/27/2019 Eemg Part 1 (Mou Abt Perf Avf Pl Outage)
193/570
. IV/ 08-09/ 2
203
1 DATE OF TRIPPING : 02/07/2008
2 TIME OF TRIPPING : 12:18 Hrs
s (By
running
mill AB
ice and
ort. All
pped on
ry low
On checking at
local it was found
that heavy gland
leakage had
developed in
steam side manual
isolating valve of
drum level
transmitter no. LT
674 D .This
transmitter started
showing very highvalue (False) ,FRS
control valve came
down and came to
manual mode due
to deviation of
transmitters. Due
to sudden and
large amount of
reduction of feed
water flow, unit
tripped on Drum
Level very Low
protection.
4 RECOMMEND
ATIONS (By
OS-NR) :
Action to be
taken by
Present status
-
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In case of auto
control failure,
the desk operator
has to take quick
action for
controlling the
drum level. To
deal with
indication
discrepancies,
Hydrastep is
generally more
dependable since
it gives direct
indication of
both LHS &
RHS.
The reason for
failure of auto
control also
needs to be
investigated and
addressed. Auto
control should
not fail with the
failure of one
transmitter.
-
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Any leakage in
impulse line of
critical
instruments
should be
attended
immediately
after obtaining
permission from
operation by
means of
suitable safety
documents
(LWC/PTW).Ne
cessary
precautions has
to be taken ( like
suspending the
instrument
service) to
prevent unit
?equipment
tripping before
commencing of
repair job.
ited
ebareli
ONS SUMMERY(2007-2008)
19/12/2008)
V
. . IV/ 08-09/ 03
505
1 DATE OF TRIPPING : 09/08/2008
2 TIME OF TRIPPING : 06:46:14 Hrs.
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running
W with
service.
was in
turbine
control
33 Hrs.
cer Lub
High
n event
itself .
lub oil
ken in
tely. In
ng was
second
ped. At
in same
n event
tripped
Furnace
d Flame
and FF
started
6:46:08
ely oil
in EF
tripped
it was
t of tworeducer
was not
rly.
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w master
mand of
aster is
Boiler
al fuel
he two)
ine is in
hen millaux air
d to mill
osed. So
pressure
mmwc ,
the air
box to
ux air
ated to
EF ,FF)
ir flow
d almost
use one
ir flow
master
manual
ith the
lower
me and
4 RECOMMEND
ATIONS (By
site) :
Action taken /
To be taken by
Present status
Mill Reducer
Lubrication Not
OK temp logic to
be modified from
1/2 to 2/3 with
alarm.
Temp logic
modified from
1/2 to 2/3
Implemented
Desk engineer
should control air
flow as per fuel
flow during
emergency to
avoid lean mixture
Instruction to be
given to operation
engineer
Being followed
5 RECOMMEND
ATIONS (By
OS-NR) :
Action to be
taken by
Present status
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Whenever unit is
running on
partial load, it is
better to keep
the gap between
the running mills
at minimum
Any
malfunctioning
of trip devices
should be
immediately
investigated. In
this case , there
was any
opportunity to
check the
malfunctioningtemp switch
when the the
alarm appeared
the first time
Provision for
providing an
alarm with a
setting lower
than trip value
to be explored.
itedebareli
ONS SUMMERY(2008-2009)
13/03/2009)
V
. IV/ 08-09/ 04
103
1 DATE OF TRIP2 TIME OF TRIPPING : 17:09 Hrs.
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s (By
running
mill CD
service
support.f ID fan
pped on
fault.
incomer
6.6 KV
A also
in lock
nd earth
Reserve
ion Bus
come in
g torunning
Bus-A,
F. Mill
on PA
e Very
and unit
of All
-
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200/570
in the
m VFD
eaker to
sformer.
E/F
element
UAT I/C
ated and
was in
er ,it
reverse
from
ch-I
r, but it
sec time
g in its
T2).On
ation it
at one
relay of
oing to
Digital
it was
Digital
r time
sec and
lockout
me
he UAT
ngeover
y from-1 was
pping of
Mill-CD
header
Low
4 RECOMMEND
ATIONS (By
site) :
Action taken /
To be taken by
Present status
Tripping of UAT
incomer Breaker
on E/F from
DDCMIS to be
removed
DGM ( EMD) Implemented
-
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DGM ( EMD)
DGM ( PE- Ele)
itedebareli
ONS SUMMERY(2008-2009)
13/03/2009)
V
. IV/ 08-09/06
104
1 DATE OF TRIPPING : 03/11/20082 TIME OF TRIPPING : 20:42 Hrs.
s (By
was
7 MW
service
upport.
all the
m Unit
nd unit
s of all
Dead bus
changeover, in
case of fast
changeover fails,
is to be provided
in stage-II .
-
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202/570
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site) :
g at 217
B, C, D
without
was in
1:07:37
sudden
ed No
equently
and E
Flame
ed on
Failure
cking no
bserveds except
g and
furnace
r was
gh ash
w VM
sample
ort was
-
sh49
4 RECOMMEND
ATIONS (By
site) :
Action taken /
To be taken by
Present status
Nil
5 RECOMMEND
ATIONS (By
OS-NR) :
Action to be
taken by
Present status
Mill fineness
must bemaintained
within limits as
it exacerbebates
the already poor
flame caused by
low VM
BMD Being followed
-
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Blending of the
coal must be
resorted to
overcome the
problems created
by low VM coal
Being followed
ited
ebareli
ONS SUMMERY(2007-2008)
13/03/2009 )
V
. : V/ 08-09/ 03
:0220
1 DATE OF TRIPPING:03/05/2008
2 TIME OF TRIPPING:18:20:00 Hrs.
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206/570
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with the present
arrangement of
instrumentation,
the checking /
purging of
transmitter must
be done after
taking sufficient
precaution to
avoid unit
tripping.
Unit #5 OH has
not been done
since
commissioning (
short shutdown
was taken in
march 07 for PGtest ). In such
conditions,
opportunity
based purging of
all water
connected
protection
devices , using
compressed air
should be
arranged toensure complete
cleanliness of
pipes.
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7/27/2019 Eemg Part 1 (Mou Abt Pe