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POWER HOLDING COMPANY OF NIGERIA PLC
NATIONAL CONTROL
CENTRE
OSOGBO
GENERATION
AND
TRANSMISSION
GRID OPERATIONS
2009
(ANNUAL TECHNICAL REPORT)
ISSUED BY:
GENERAL MANAGER (S/O)
NATIONAL CONTROL CENTRE
OSOGBO
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TABLE OF CONTENTS
PAGES
INTRODUCTION 1
1.0 GRID OPERATIONS IN 2009 1
1.1 Hydrology and Lake Operation. 2
1.2 Thermal Generation 91.3 Generation Ordering and Load Dispatching 91.4 Frequency Control 91.5 Voltage Control 91.6 Outage Planning 211.7 Energy Production 25
2.0 CONSTRAINTS TO GRID OPERATIONS 49
2.1 Constraints to Grid vis-a-vis System Communication 492.2 Generation Constraints 522.3 Transmission Constraints 52
3.0 REINFORCEMENT AND REHABILITATION OF
NATIONAL GRID 63
4.0 SYSTEM DISTURBANCES 65
4.1 Transmission System faults 65
4.2 Generation System faults 65
5.0 ACCIDENTS AND MISHAPS 66
6.0 CONCLUSIONS AND RECOMMENDATIONS 67
7.0 APPENDICES 71
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NO. LIST OF TABLES PAGE
1A. HYDROLOGICAL SUMMARY 3
1B COMPUTEDAVERAGE INFLOW AND TURBINE DISCHARGE 6
2 AVERAGE MONTHLY MW AVAILABILITY 17
3 SUMMARY OF GENERATION CAPABILITIES OF NIGERIAPOWER 18
STATIONS AS OPERATED IN 2009
4. NIGERIAPOWER SYSTEM FREQUENCY 22
5A. 2009OUTAGES STATISTICAL SUMMARY 330KV LINE 23
5B. 2008OUTAGES STATISTICAL SUMMARY 330KV LINE 23
6A. 2009OUTAGES STATISTICAL SUMMARY 132KV LINE 24
6B. 2008OUTAGES STATISTICAL SUMMARY 132KV LINE 24
7A & 7B. ENERGY GENERATED/ SENT OUT(MWH) 31-32
8. HYDRO & THERMAL ENERGY GENERATED(MWH) 33
9. ENERGY GENERATION & POWER CONSUMPTION RECORDS 38
10. MONTHLY ENERGY BALANCE SUMMARY 40
11 ENERGY AVAILABLE FOR SALES PLUS DISTRIBUTION LOSSES
IN EACH REGION (MW) 41
12 QUANTITY OF GAS CONSUMED 42
13 COST OF GAS (NAIRA) AGAINST ENERGY GENERATED 2009 43
14 OPERATING FUEL COST (NAIRA/KWh) 44
15 MONTHLY MAXIMUM DEMAND/GENERATION ANALYSIS (MWH) 73
16 SYSTEM GENERATION PEAK LOAD (FORECAST & ACTUAL) 7417 SUMMARY OF OCCURRENCE OF MAXIMUM PEAK LOAD 75
18 SUMMARY OF SYSTEM DISTUBANCES 93
19A-C SUMMARY OF SYSTEM DISTUBANCES OF INTEGRATED GRID 94-96
19D DAILY/MONTHLY ANALYSIS SUMMARY OF SYSTEM DISTURBANCE 97
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NO. CHARTS PAGE
1. KAINJI AVERAGE MONTHLY TOTAL DISCHARGE AND INFLOW 4
2. KAINJI HYDROGRAPH 4
3. JEBBA AVERAGE MONTHLY TOTAL DISCHARGE AND INFLOW 7
4. JEBBA HYDROGRAPH 7
5. SHIRORO AVERAGE MONTHLY TOTAL DISCHARGE AND INFLOW 8
6. SHIRORO HYDROGRAPH 8
GENERATION AVAILABILITY IN 2009 10-15
7. 2009 AVERAGE MONTHLY MW AVAILABILITY 16
8. POWER STATIONS AVAILABILITY FACTOR 16
9 POWER STATION AVERAGE MW AVAILABILITY 19
10 POWER STATIONS INSTALLED CAPACITIES 19
11 ANNUAL ENERGY GENERATED. 20
12 SIMULTANEOUS NATIONAL PEAK DEMAND (MW 20
13 330KV FORCED OUTAGES (2008 & 2009) 26
14 132KV FORCED OUTAGES (2008 & 2009) 26
15 COMBINED 2008 & 2009 330KV OUTAGES 27
16 COMBINED 2008 & 2009 132KV OUTAGES 27
17 330KV PLANNED, URGENT AND EMERGENCY OUTAGES 28
18 132KV PLANNED,URGENT & EMERGENCY OUTAGES 28
19 PERCENTAGE ENERGY USED IN POWER STATIONS 34
20 HYDRO, THERMAL AND TOTAL ENERGY GENERATED 34
21 ENERGY GENERATED IN HYDRO POWER STATIONS 37
22 ENERGY GENERATED IN THERMAL POWER STATIONS 37
23 AVAILABLE ENERGY FOR SALES 39
24 TOTAL MONTHLY ENERGY AVAILABLE FOR SALE 39
25 TRANSMISSION REGIONS: MONTHLY ENERGY AVAILABLE FOR SALE 45
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NO. CHARTS PAGE
26 REGIONAL ENERGY AVAILABLE FOR SALE 45
27 MAJOR THERMAL STATIONS FUEL COSTS 46
28 MONTHLY UNIT PRODUCTION COST 47
29 STATIONS AVERAGE PRODUCTION COSTS 48
30 MONTHLY PEAK DEMAND FORECAST AND ACTUAL 76
31 WEEKLY PEAK TOTAL MW GENERATION HISTOGRAM 76
32 KAINJI G.S USABLE GEN.CAP.SPECTOGRAPH PLOT AVAILABLE 77
33 JEBBA G.S. USABLE GEN. CAP. SPECTOGRAPH PLOT AVAILABLE 77
34 SHIRORO P.S. USABLE GEN. CAP. SPECTOGRAPH 78
35 EGBIN P.S. USABLE GEN. CAP. SPECTOGRAPH 78
36 DELTA P.S. USABLE GEN. CAP. SPECTOGRAPH 79
37 AFAM 1-V P.S. USABLE GEN. CAP. SPECTOGRAPH 79
38 SAPELE P.S. USABLE GEN. CAP. SPECTOGRAPH 80
39 AFAMVI / IBOM P.S. USABLE GEN. CAP. SPECTOGRAPH 80
40 OLORUNSOGO P.S. USABLE GEN. CAP. SPECTOGRAP 81
41 DAILY TOTAL GRID GEN. AVAILABILITY STATUS 81
42 AES P.S. USABLE GEN. CAP. SPECTOGRAPH 82
43 OKPAI P.S. USABLE GEN. CAP. SPECTOGRAPH 82
44 GEREGU P.S. USABLE GEN. CAP. SPECTOGRAPH 83
45 OMOTOSHO P.S. USABLE GEN. CAP. SPECTOGRAPH 83
46 OMOKU P.S. USABLE GEN. CAP. SPECTOGRAPH 84
47 AJAOKUTA P.S. USABLE GEN. CAP. SPECTOGRAPH 84
48 AFAM VI P.S. USABLE GEN. CAP. SPECTOGRAPH 85
49 IBOM P.S. USABLE GEN. CAP. SPECTOGRAPH 85
50-51 GRAPHICAL REPRESENTATION OF SYSTEM COLLAPSE (MONTH) 98
53 TOTAL LOSS DUE TO SYSTEM DISTURBANCE 99
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INTRODUCTION
T
his Technical Report is an annual publication of Power Holding Company Nigeria Plc
(PHCN). It addressed the National Generation and Tranmission Grid Operations in 2009as collated from the electronic databank of theNational Control Centre (NCC), Osogbo.
Significant headings covered are:
1.0 Grid Operationsin 2009
2.0 Constraints to Grid Operations in 2009
3.0 Reinforcements to the National Grid in 2009
4.0 System Disturbances 5.0 Accidents and Mishaps 6.0. Conclusions and Recommendations
Grid Operations in 2009arecompared with the previous year 2008 through tables and
graphs.
Comprehensively analyzed are plant and equipment outages, energy generated,
transmitted and available for sales to the distribution network.
Supplementary charts, graphs and other important details enhancing assimilation of the
report are displayed.
1.0. GRID OPERATIONS IN 2009The plant average availability at Kainji Station in 2009 was 445.8MW. This was
6.5MW higherthan 2008figure of 438.9MW.
Jebba's plant availability ranged between 578.4MW and 376.2MW in 2009 with averageavailability of 458MW. This was lower than 2008 average availability of 529.4MW by
71.4MW.
At Shiroro Power Station, plant availability throughout the year was less than 2008,
varying between 450MW and 300MW with an average of 404.6MW. This was 84.2
MW less than 2008figure of 488.8MW.
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1.1 HYDROLOGY AND LAKE OPERATIONS
1.1.1. Kainji Lake
The average computed inflow of the 2008/2009 black flood yield into the Kainji Lake was lowerthan the average forecast inflow by 18.34%.
When the average black flood inflow was compared with the figures of immediate past five
years, the 2008/2009 black flood was higher than the 2007/2008 by 13.274%, higher than
2006/2007 by 21.23%, higher than 2005/2006 by 12.45%, lower than 2004/2005 by 6.4%.
The good flood yield, brought the head water elevation to 140.94 meters corresponding to 11.05
billion cubic metres by the beginning of the hydro year, January 1st 2009.
The black flood inflow peaked on 2nd February 2009, with a value of 1834 cubic metres per
second (m3/sec).
This was (4.6%) higher than the peak daily computed inflow of 2007/2008.
At the Joint Operations/Generation Planning meeting held at the National Control Centre, NCC,
Osogbo between 11th and 13th March, 2009, the planned turbine releases and the expected
inflow into the Kainji Lake from the months of March through August were as in the Table1B.
The aim of the meeting was to agree on the draw down trajectory of the Lake in such a manner
that will optimize the utilization of the stored water, till the next flood season, taking into
consideration the safety of the dam structures.
Kainji which started with elevation 140.94 metres (11.05 b.cu. metres) on 1st January, 2009,
dropped to minimum elevation of 130.39 metres (1.6 b.cu. metres) in July 25th 2009. During the
filling, an elevation of 141.39 metres (11.6 b.cu. metres) was attained in December 31st 2009.
Average inflow in 2009 was 9.7% higher than the average inflow of 2008. While average
discharge in 2009 was 11.88% lower than 2008. There was water spillage throughout the year
except in September and October 2009. Average spillage at Kainji in 2009 was 42.63% higher
than 2008s. (table 1A). A comparison between forecast and actual inflows; forecast and actual
discharges during the year was depicted in table 1B. The overall Kainji MW availability was
lower (1.5%) than the previous year (see chart 1&2).
1.1.2 Jebba Lake
Jebba Lake, located downstream of the Kainji Lake, depended largely on Kainji Station turbine
discharges especially during the dry months when the lateral inflows had ebbed out. At the
beginning of the hydro year, 1st January 2009, the head water was at 101.0 metres,
corresponding to 3.30 billion cubic metres of water. This volume was 1.7% lower than the
storage balance of 3.82 billion cubic metres recorded at the beginning of the hydro year, 1st
January 2009. During the year, the minimum head water recorded, was 99.04metres which
occurred on July 31st, 2009. The lateral inflow peaked on September 3, with a value of 1225
m3/sec. It was however 26.69% lower than the peak lateral inflow of 2008.
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AVE.TURB.DISCH.
(CUB.M/SEC)
(CUB.M/
SEC)
(CUB.M/SEC)
RATE(CUB.M/SEC)
(MWH)
MONTH
KAINJI
JEBBA
SHIRORO
KAINJI
JEBBA
SHIRORO
KAINJI
JEBBA
SH
IRORO
KAINJI
JEBBA
SHIRORO
KAINJI
JEBBA
SHIRORO
JAN.
1199.42
1258.40
271.45
157.19
0.00
0.00
1356.60
1258.40
271.45
1479.40
1362.30
40.65
9671.97
7238.35
5988.10
FEB.
1101.89
1343.36
231.50
208.00
0.00
0.00
1309.89
1343.36
231.50
1441.96
1278.50
34.36
8872.43
7748.50
4963.71
MAR.
1102.52
1465.94
258.61
297.84
0.00
0.00
1400.35
1465.94
258.61
652.03
1379.74
12.55
8859.26
8334.39
5394.68
APR.
924.33
1277.83
219.47
366.57
0.00
0.00
1290.90
1277.83
219.47
367.67
1278.57
17.97
7072.00
7026.77
4429.30
MAY.
803.81
1223.40
256.26
419.19
0.00
0.00
1223.00
1223.40
256.26
240.10
1192.20
62.23
5623.87
6738.74
4803.10
JUN.
654.80
1141.80
145.87
375.83
0.00
0.00
1030.63
1141.80
145.87
258.33
1070.83
120.23
4455.03
6144.77
2567.63
JAN-JUN
TOTAL
5786.77
7710.73
1383.16
1824.62
0.00
0.00
7611.37
7710.73
13
83.16
4439.49
7562.14
287.99
44554.56
43231.52
28146.52
JAN-JUN
AVERAGE
964.46
1285.12
258.87
304.10
0.00
0.00
1268.56
1285.12
230.53
739.92
1260.36
48.00
7425.76
7205.25
4691.09
JUL.
437.13
895.65
258.87
336.39
0.00
0.00
773.52
895.65
258.87
607.97
888.19
278.94
2884.84
4801.74
4564.40
AUG.
490.23
1125.61
464.10
376.48
0.00
0.00
866.71
1125.60
464.10
1859.20
1268.60
1431.40
3262.58
5991.58
9216.40
SEP.
956.80
1576.40
435.60
0.00
0.00
0.00
956.80
1576.40
435.60
3062.87
1803.63
1130.00
6880.33
9200.00
10030.20
OCT.
936.42
1539.00
362.03
0.00
0.00
0.00
936.42
1539.00
362.03
1659.60
1401.40
500.39
7296.52
8948.26
8461.10
NOV.
1071.23
1368.40
322.97
181.50
0.00
7.80
1252.73
1368.40
322.97
1287.4
1407.33
147.79
8443.60
8245.43
7352.33
DEC.
1131.23
1341.81
309.29
66.52
0.00
0.00
1197.70
1341.80
309.29
1270.97
1223.70
61.61
9244.10
7679.94
7132.10
JUL-DEC
TOTAL
5023.04
7846.87
2152.86
960.89
0.00
7.80
5983.88
7846.85
21
52.86
9748.01
7992.85
3550.13
38011.97
44866.95
46756.53
JUL-DEC
AVERAGE
837.17
1307.81
358.81
160.15
0.00
1.30
997.31
1307.81
358.81
1624.67
1332.14
591.69
6335.33
7477.83
7792.76
ANNUAL
TOTAL
10809.81
15557.60
3536.02
2785.51
0.00
7.80
13595.25
15557.58
35
36.02
14187.50
15554.99
3838.12
82566.53
88098.47
74903.05
AVERAGE
ANNUAL
900.82
1296.47
294.67
232.13
0.00
0.65
1132.94
1296.47
294.67
1182.29
1296.25
319.84
6880.54
7341.54
6241.92
TABLE1A:H
YDROLOGICAL
SUMMARY.JANUA
RY-DECEMBER2009
AVE.SPIL
LAGE
STATIONAVE.TOT.DISCH
COMP.AVE.INFLOW
AVE.DAILYENERGY
3
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0
400
800
1200
1600
2000
2400
2800
3200
JAN. FEB. MAR. APR. MAY. JUN. JUL. AUG. SEP. OCT. NOV. DEC.
FLOWI
NCUBICMETRES/SEC
MONTHS
KAINJI AVE.MONTHLY TOT. DISCHARGE & INFLOWJANUARY-DECEMBER 2009CHART 1 (SEE TABLE 1)
DISCHARGE INFLOW
129.5
131.5
133.5
135.5
137.5
139.5
141.5
143.5
JAN. FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC
HEADWATERELEVATIONINMETRES
MONTHS
KAINJI HYDROGRAPH1994-2009 CHART 2
2009ACTUAL 2008ACTUAL 2007ACTUAL 2006ACTUAL 2005ACTUAL 2004ACTUAL 2003ACTUAL 2002ACTUAL
2001ACTUAL 2000ACTUAL 1999ACTUAL 1998ACTUAL 1997ACTUAL 1996ACTUAL 1995 ACTUAL 1994 ACTUAL
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Despite threat of spillage at Jebba in the year when the head water elevation attained 103.10 metres, this
was averted due to cooperation between the stake holders including NCC, Kainji and Jebba Managements..
By December 31st2009, the head water elevation in Jebba was 100.82 metres corresponding to 3.25 billion
cubic metres. This was 0.1% lower than the head water elevation of the Lake at the same period in 2008.
1.1.3 Shiroro Lake
At the beginning of the hydro year, January 1st 2009, the reservoir elevation was 374.20 metrescorresponding to storage balance of 3.8225 billion cubic metres. This volume was higher (2.7%) than the
storage balance at the same time 2008.
During the period, it was difficult to actualize the draw down plan because of the grid demand. Each timethere was System disturbance, Shiroro was always islanded to feed the Federal Capital Territory pending
System restoration.
Unstable gas supply to thermal stations often necessitated running additional units than planned in order to
maintain grid integrity and stability.
In the year, Shiroro lake was drawn down to 54.8 metresby June 7th, 2009 -the lowest ever- due toavailability of only two of the Shiroro generating units. That was to create enough space for white flood
and consequently avert spillage as much as possible.
Lake filling commenced on July 31st, 2009 when the average computed inflow was 562 m3/sec.
The maximum head water elevation in Shiroro Lake was 382.37 metres which occurred on 1 stNovember
2009, corresponding to 5.80 billion cubic metres. Draw down of the lake to the minimum level ever paidoff as prolonged spillage was averted..
Overall ,Shiroro MW availability throughout 2009 dropped by 20.81% when compared with 2008 figure.
By December 31st2009, the head water elevation in Shiroro stood at 378.24 meters, corresponding to a
storage balance of 4.69 billion cubic metres.
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MON
TH
PLANINF.
ACTUAL
INF.
PLAN
DISC.
ACTUAL
DISC.
PLAN
INF.
ACTUAL
INF.
PLAN
DISC.
AVER.
LATERAL
INF
ACTUAL
DISC.
PLAN
INF.
ACTUAL
INF.
PLAN
DISC.
ACTUAL
DISC.
JAN.
2100.00
1479.40
1300.00
1199.42
1299.00
1362.30
1300.00
0.76
1258.40
30.00
40.65
200.00
271.45
FEB.
1300.00
1441.96
1200.00
1101.89
1204.00
1278.50
1179.00
26.46
1343.36
25.00
40.08
200.00
231.50
MAR.
573.00
652.03
1200.00
1102.52
1127.00
1379.74
1450.00
21.90
1465.94
32.00
12.55
250.00
258.61
APR.
210.00
367.67
1200.00
924.33
1380.00
1278.57
1350.00
16.10
1277.93
40.00
19.25
250.00
219.47
MAY.
125.00
240.10
1000.00
803.81
1203.00
1192.20
1180.00
26.45
1223.40
62.00
62.23
200.00
256.26
JUN.
237.00
258.33
600.00
654.80
720.00
1070.83
700.00
25.10
1141.80
210.00
120.23
250.00
145.87
JUL.
830.00
607.97
900.00
437.13
1105.00
888.19
1090.00
102.00
895.65
360.00
278.94
250.00
258.87
AUG.
1900.00
1859.20
840.00
490.23
1256.00
1268.60
1250.00
393.55
1125.60
900.00
1431.40
400.00
464.10
SEP.
2400.00
3062.87
750.00
956.80
1400.00
1803.63
1300.00
862.34
1576.40
1500.00
1130.00
450.00
435.60
OCT.
1900.00
1659.60
900.00
936.42
1300.00
1401.40
1300.00
465.28
1539.00
500.00
500.39
450.00
362.03
NOV.
1300.00
1287.40
1110.00
1071.23
1176.00
1407.33
1159.00
160.86
1368.40
90.00
147.79
300.00
315.17
DEC.
1397.00
1271.00
1110.00
1131.20
1128.00
1223.70
1265.00
21.24
1341.81
65.00
61.61
450.00
309.29
TABLE
1B:PLAN/ACTUALCOMP.AVE.INFLOWAND
AVE.TURB.DISCH.(CUB.M/SEC).JANUARY
-DECEMBER2009.
KAINJI
JEBBA
SHIROR
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0
200
400
600
800
1000
1200
1400
1600
1800
2000
JAN. FEB. MAR. APR. MAY. JUN. JUL. AUG. SEP. OCT. NOV. DEC.
FLOWI
NCUBICMETRES/SEC
MONTHS
JEBBA AVE. MONTHLY TOTAL DISCHARGE & INFLOWJANUARY-DECEMBER 2009 CHART 3 (SEE TABLE 1)
DISCHARGE INFLOW
99
99.5
100
100.5
101
101.5
102
102.5
103
103.5
104
JAN. FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC
HEADWATERELEVATIONINMETRES
MONTHS
JEBBA HYDROGRAPH1994-2009 CHART 4
2009ACTUAL 2008ACTUAL 2007ACTUAL 2006ACTUAL 2005ACTUAL 2004ACTUAL 2003ACTUAL 2002ACTUAL
2001ACTUAL 2000ACTUAL 1999ACTUAL 1998ACTUAL 1997ACTUAL 1996ACTUAL 1995 ACTUAL 1994 ACTUAL
7
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0
100
200
300
400
500
600
700
800
900
1000
1100
1200
1300
1400
1500
JAN. FEB. MAR. APR. MAY. JUN. JUL. AUG. SEP. OCT. NOV. DEC.
FLOWIN
CUBICMETRES/SEC
MONTHS
SHIRORO AV. MONTHLY TOT. DISCHARGE & INFLOWJANUARY - DECEMBER 2009 CHART 5 (SEE TABLE 1 )
DISCHARGE INFLOW
350
355
360
365
370
375
380
385
JAN. FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC
HEADWATERELEVATIONINMETRES
MONTHS
SHIRORO HYDROGRAPH1994-2009, CHART 6
2009ACTUAL 2008ACTUAL 2007ACTUAL 2006 ACTUAL 2005 ACTUAL 2004 ACTUAL
2003ACTUAL 2002ACTUAL 2001ACTUAL 2000ACTUAL 1999ACTUAL 1998ACTUAL
1997ACTUAL 1996ACTUAL 1995ACTUAL 1994ACTUAL
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1.2. THERMAL GENERATION
1.2.0. GENERATION AVAILABILITY
The plants average MW availability for year 2009 is contained in table 2. Monthly average MWavailability was computed by averaging the daily actual generation output in the month.
Thermal plants average availability was 3194.3MW in 2009. Of this,1104.3MW was from
A.E.S, Okpai, Afam VI, Ibom and Omoku (Independent Power Producers) while 2090MW was
from PHCN. The thermal availability was 70.95.12% of the total hydro and thermal availability
of 4502.3MW in the year. It was 7.78% higher than 2008 average thermal and hydro availability
of 4177.0MW. (section 1.2.1. to 1.2.12).
1.3. GENERATION ORDERING AND LOAD DISPATCH
An integrated grid was operated in 2009, pooling generation from Kainji, Jebba and Shiroro
Hydro Power Stations and Egbin, Delta, Afam(1-V), Afam V1, Sapele, AES, Okpai, Omotosho,
Ajaokuta, Omoku, Geregu, Olorunsogo and IBOM thermal Stations. Inadequate gas supply from
the Nigerian Gas Company (NGC) and incessant low gas pressure militated against full thermal
capacity generation into the grid. Among the affected Stations were: Egbin and AES which,
although capable of an average generation of 1217.3MW, was frequently confined between 200
and 800 MW. Geregu, Omotosho and Olorunsogo plants were idle for several months in 2009
due to lack of gas. Since generation availability was grossly inadequate to meet the ever
increasing load demand, load shedding continued through out the year in order to maintainpower balance.
1.4 FREQUENCY CONTROL
Due to generation shortage, the grid was operated outside the frequency control policy of 50Hz
+ 0.40% i.e. 49.80Hz to 50.20Hz, resulting in frequency excursions outside the operational
limits. Most of the gas turbines on the grid were operated on temperature control mode. Hence
they were often insensitive to vagaries of system frequency. The automatic voltage regulator
(AVRs) and governor system of KainjiKaplan units (variable blades) were not functional. All
the other machines in the system were considered base load, except Jebba units that regulate
occasionally. It is however noteworthy that the underfrequency relays installed in some stations
obviated system collapses on several occasions.
1.5. VOLTAGE CONTROL
In 2008, the voltage control policy of 330kV + 5% and 15% on the 330kV buses and 132kV
+10% and -15% for the 132kV buses was frequently maintained. The Area Control Centres
efforts in this regard were commendable. Diverse Engineering techniques of voltage control
were applied in the year. Among them were reactive power generation/absorption by generators
in the proximity of the controlled bus; use of reactive compensators and as a last resort ,switching
of 330kVcircuits.
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JAN
FEB
MAR
APR
MAY
JUN
JUL
AUG
SEP
OCT
NOV
DEC
GT1
GT2
GT3
GT4
GT5
GT6
GT7
GT8
KEY:
Units
Available
GT1
-
wasav
ailablefromJanuarytofebruary,3rdMay2009.
GT2
-
wasav
ailablefromJanuarytofebruaryand22ndNovember2009.
GT3
-
wasav
ailablepartofJanuary,throughoutFebruary;partofApril2009.
GT4
-
wasav
ailablefrom
Januarytofeb;29thto30thApril2009.
GT5
-
wasav
ailablefromJanuarytoFebruary2009.
GT6
-
wasavailablefromJanuarytoFebruary;18thto26thApril;4thto7thMay2009.
GT7
-
wasav
ailablefrom1stto14january;Feb;19to20thMarch200
9.
GT8
-
wasav
ailablefromJanuarytoFebruary;19to21stmarch;23rd
to27thApril;3rdmay2009.
GT1,2,3,6&8
wereon
outageasindicatedonthechartabove
UNITS
JANUARY
F
EBRUARY
MARCH
APRIL
MAY
JUNE
JULY
AUGUST
SEPTEMBER
OCTOBER
NOVEMBER
DECEMBER
GT11
GT12
GT13
KEY:
Units
Available
GT11
-
wasavaila
blepartofJanuary,MarchtoMay;throughoutFebruary
,SeptembertoNovember2009.
GT12
-
wasavaila
blethroughoutJanuary;partofSeptembertoDecembe
r2009
GT13
-
wasavai
lablefromJanuaryto16thMay2009.
GT11,12&ST1
wereonout
ageasindicatedonthechartabove.
()
1.2.8
GENERATIONAVAILABILITY-
GEREGUPOWERSTAT
ION(2009)
LowgasPressure
3
LowgasPressure
LowgasPressure
LowgasPressure
22
DCground
fault
8
LowgasPressure
LowgasPressure
29
22
18
30
Low
gas
Press
LowgasPressure
29
LowgasPressure
Lowg
asPressure
LowgasPressure
18
Lowgas
Pressure
26
4
LowgasPressure
7
Speedpanel
problem
14
Awaiting
spareparts
LowgasPressure
Lowgas
Pressure
19
20
Lowgas
Pressure
LowgasPressure
3
LowgasPressure
21
19
Lowgas
Pressure
27
23
Shutdown
4
On
stand
b
4
LGP
SHUTDOWN
LG
P
Vibrati
ontest
parts
16
Outongen
winding
19
16
24
1
6
LGP
25
22
20
23
LGP
19
LG
13
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UNITS
JANUARY
FEBRU
ARY
MARCH
APRIL
MAY
JUNE
JULY
AUGUST
SEPTEMBER
OCTOBER
NOVEMBER
DECEMBER
ST1
ST2
KEY:
UnitsAvailable
ST1
-
wasnotavailablethroughouttheyear.
ST2
-
wasnotavailablethroughouttheyear.
ST1&2-
wereonoutageasindicatedonthechartabove.
UNITS
JANUARY
FEBRU
ARY
MARCH
APRIL
MAY
JUNE
JULY
AUGUST
SEPTEMBER
OCTOBER
NOVEMBER
DECEMBER
GT11
GT12
GT13
KEY:
UnitsAvailable
GT11
-
wasavailablep
artofJanuarytoJuly,SeptembertoNovember;throughoutAugustandDecember.
GT12
-
wasavailablep
artofJanuarytoFebruary,Apriltonovember;throughoutDecember.
GT13
-
wasavailablep
artofMarchtoApril,July,SeptembertoNovember;throughoutDecember.
GT11,12&13-
wereonoutageasindicatedonthechartabove.
UNITS
JANUARY
FEBRUARY
MARCH
APRIL
MAY
JUNE
JULY
AUGUST
SEPTEMBER
OCTOBER
NOVEMBER
DECEMBER
GT1
KEY:
UnitsAvailable
GT1
Wasavailablefrom
16thto
17th,thenfrom18thto27thDecember2009
1.2.13
GENE
RATIONAVAILABILITY
-IBOMPOWERSTATIO
N(2009)
1.2.12
GENERATIONAVAILAB
ILITY-AFAMVIPOWERSTATION(2009)
1.2.11
GENERATIONAVAILABILITY-ASCOP
OWERSTATIONPOWERSTATION(2009)
OUTDUETOFIREOUTBREAKON
THEGENERATOR
SIDE
OUTDUETOHYDROGEN
PROBLEM
undergoi
ng
check
15
system
collapse
14
15
outon
wash
No
gas
Gas
maint
enan
low
Gas
pres
5
7
19
20
9
8
13
27
low
Gas
pres
7
mtc
e
3
low
Gas
pres
syst
e sy
ste
m
shut
do
no
gas
17
8
65
ins
pe
cti
loa
dlimi
7
13
25
23
devi
ce
prot
2
3
lgp
7
shut
do
26
22
low
Gas
pres
mtc
e
low
Gas
pres
shutdownchecks
shutdow
nfortes
t
4
4
15
18
shutdownchecks
29
2
3
Atypeof
inspection
5
lo
w
G
as
5
low
Gas
load
limitatio
n
21
25
29
4
loadlim
13
lowga
lowga
lowga
7
161
8
202
1
Che
cks
20
16
shut
dow
n
nog
Trip
ped
s
5
8
27
26
20
820
lowGaspressure
OutforfurtherCheck
lowG
26
30
loadlim
loadlim
4
7
14
16
sh
utd
ow
26
lowga
7
7
Atypeof
inspection
insp
ecti
on
low
Gas
9
22
21
16
Tripped
17
27No
genera
tion
15
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0
500
1000
1500
2000
2500
J F M A M J J A S O N D
MONTHLYAVAILABILITY
MONTHS
2009 AVE. MONTHLY MW AVAILABILITYJANUARY-DECEMBER 2009 CHART 7(SEE TABLE2)
KAINJI JEBBA SHIRORO SAP.TOT AFAM EGBIN
DELTA IJORA CALABAR AES OKPAI AJAOKU
THMAL PHCN THMAL IPP #REF! #REF! OMOKU
0.00
0.20
0.40
0.60
0.80
1.00
1.20
AVAILABILITY
FACTOR
POWER STATIONS
POWER STATIONS AVAILABILITY FACTORJANUARY-DECEMBER 2009, CHART 8(SEE TABLE 3)
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MONTHS
KAINJI
MW
JEBBA
MW
S
HIRORO
MW
EGBIN
MW
ASCO
MW
A.E.S
MW
SAPELE
MW
OKPAI
MW
AFAM(I-V)
MW
AFAMIV
MW
DELTA
MW
GEREGU
MW
OMOKU
MW
OMOTOSHO
MW
PAPALANTO
MW
IBOMMW
THERMAL
TOTAL
(PHCN)MW
THERMAL
TO
TAL(IPP)
MW
THERMAL
TOTALMW
HYDRO
TOTAL
MW
GRAND
TOTAL
MW
JAN.
545.8
578.4
440.3
1000.6
0.0
225.5
120.0
469.7
30.6
115.0
254.1
300.0
75.0
287.5
282.7
0.0
2275.5
770.2
3045.7
1564.5
4610.2
FEB.
527.3
590.4
425.0
1100.0
0.0
257.3
122.3
478.9
82.5
250.4
316.5
300.0
92.6
317.8
290.2
0.0
2529.3
828.7
3358.0
1542.8
4900.8
MAR.
522.2
575.3
425.8
1071.6
0.0
254.9
189.7
414.0
91.2
281.7
272.6
300.0
98.3
294.0
330.1
0.0
2549.2
767.1
3316.3
1523.3
4839.6
APR.
437.7
478.6
450.0
1004.7
0.0
272.7
240.0
438.6
61.8
280.4
269.3
300.0
120.7
255.9
285.2
0.0
2416.8
832.0
3248.8
1366.3
4615.1
MAY.
351.0
376.2
333.9
851.6
0.0
221.9
240.0
464.6
73.4
316.0
281.1
300.0
125.0
288.0
291.0
0.0
2325.1
811.5
3136.6
1061.0
4197.6
JUN.
380.0
379.2
300.0
938.7
0.0
284.7
240.0
377.1
75.0
300.3
283.4
300.0
110.7
291.9
301.5
0.0
2430.5
772.6
3203.1
1059.2
4262.3
JAN-JUN
TOTAL
2764.0
2978.1
2375.0
5967.2
0.0
1516.9
1152.0
2642.9
414.4
1543.8
1677.0
1800.0
622.3
1735.0
1780.7
0.0
14526.4
4782.0
19308.4
8117.1
27425.5
JAN-JUN
AVERAGE
460.7
496.4
395.8
994.5
0.0
252.8
192.0
440.5
69.1
257.3
279.5
300.0
103.7
289.2
296.8
0.0
2421.1
797.0
3218.1
1352.8
4570.9
JUL.
372.3
385.6
391.9
1078.7
0.0
251.9
240.0
377.1
57.5
222.6
229.2
300.0
100.0
288.0
336.0
0.0
2529.4
729.1
3258.5
1149.8
4408.3
AUG.
283.2
441.6
450.0
908.4
0.0
258.3
240.0
478.0
72.5
450.0
200.7
300.0
100.0
308.2
335.7
0.0
2365.5
836.3
3201.9
1174.8
4376.7
SEP.
420.7
443.4
450.1
1026.7
0.0
231.5
240.0
480.0
26.7
415.0
172.0
300.0
99.2
335.0
335.0
0.0
2435.3
810.6
3246.0
1314.2
4560.1
OCT.
452.7
435.4
387.1
880.0
0.0
210.0
127.7
480.0
17.5
411.3
230.3
300.0
90.3
326.9
335.0
0.0
2217.5
780.3
2997.8
1275.3
4273.1
NOV.
519.0
388.8
370.0
902.0
0.0
179.1
180.0
472.1
64.8
375.8
254.7
300.0
57.5
302.6
335.0
0.0
2339.2
708.7
3047.9
1277.8
4325.7
DEC.
533.5
422.9
430.6
1007.7
0.0
189.5
209.0
424.8
108.8
455.4
300.0
300.0
83.3
282.0
331.6
34.8
2539.2
732.5
3271.6
1387.1
4658.7
JUL-DEC
TOTAL
2581.4
2517.8
2479.8
5803.5
0.0
1320.3
1236.8
2712.1
347.8
2330.1
1386.9
1800.0
530.3
1842.7
2008.3
34.8
14426.1
4597.6
19023.6
7579.0
26602.6
JUL-DEC
AVERAGE
430.2
419.6
413.3
967.3
0.0
220.1
206.1
452.0
58.0
388.3
231.2
300.0
88.4
307.1
334.7
5.8
2404.3
766.3
3170.6
1263.2
4433.8
ANNUAL
STN.
AVERAGE
445.4
458.0
404.6
980.9
0.0
236.4
199.1
446.2
63.5
322.8
255.3
300.0
96.0
298.1
315.7
2.9
2412.7
781.6
3194.3
1308.0
4502.3
TABLE
2
AVERAGEMONTHLYMWAVAILABILITYJAN.TODEC.2009
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POWER STATIONAVAILABILITY
FACTOR (MW)
AVERAGE
AVAILABILITY
(MW)
INSTALLED CAPACITY
(MW)
KAINJI HYDRO 0.59 445.45 760.00
JEBBA HYDRO 0.79 457.99 578.40
SHIRORO 0.67 404.56 600.00
EGBIN STEAM 0.74 980.89 1320.00
AJAOKUTA 0.00 0.00 110.00
A.E.S (GAS) 0.78 236.44 302.00
SAPELE ST 0.20 199.07 1020.00
OKPAI GAS/ 0.93 446.25 480.00
AFAM (1-V) (GAS) 0.07 63.52 931.60
AFAM IV (GAS) 0.65 322.82 497.25DELTA (GAS) 0.29 255.33 882.00
GEREGU (GAS) 0.72 300.00 414.00
OMOKU GT 0.96 96.05 100.00
OMOTOSHO 0.89 298.15 335.00
IBOM 0.08 2.90 37.00
OLORUNSOGO 0.94 315.75 335.00
TOTAL 0.55 4825.17 8702.25
DEFINITIONS:-
1. AVAILABILITY FACTOR = AVERAGE MW. AVAILABILITY
PI
2. PI = The sum of current site rating of
commissioned units installed in the
station for the year.
3. AVERAGE MW. AVAILABILITY = This is a measure of average
usable MW capacity of each stationputting gas pressure constraints
and other external factors into
consideration.
TABLE 3. SUMMARY OF GENERATION CAPABILITIES OF PHCN POWER
STATIONS AS OPERATED IN THE YEAR 2009( JANUARY - DECEMBER )
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POWER STATIONS AVERAGE MW AVAILABILITY
JANUARY-DECEMBER 2009, CHART 9 (SEE TABLE 3)
0
200
400
600
800
1000
1200
KAINJI JEBBA SHIRORO EGBIN AJAO A.E.S SAPELE OKPAI AFAM V1 AFAM IV DELTA GEREGU OMOKU OMOT IBOM OLORUN
POWER STATIONS
AVERAGEMWA
VAILABILITY(MW
POWER STATIONS INTALLED CAPACITIESJANUARY-DECEMBER 2009, CHART 10 (SEE TABLE3)
0
200
400
600
800
1000
1200
1400
KAINJI JEBBA SHIRORO EGBIN AJAO A.E.S SAPELE OKPAI AFAM V1 AFAM IV DELTA GEREGU OMOKU OMOT IBOM OLORUN
POWER STATIONS
INSTALLEDCAPACITIES(MW)
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2,4932,780
3,3223,750
4,1954,359
5,1515,724
6,7667,102
8,4568,927
10,15510,665
11,14111,471
12,70013,364
14,21215,066
14,61714,557
15,79315,971
15,41616,25316,291
15,22717,637
21,54422,612
24,13224,077
23,30023,187
21,30920,838
0 5000 10000 15000 20000 25000 30000
737475767778798081828384858687888990919293949596979899000102
03040506070809
ENERGY GENERATED (GWH)
YEAR
73 74 75 76 77 78 79 80 81 82 83 84 85 86 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 03 04 05 06 07 08 09
ENERGY(GWH) 24 27 33 37 41 43 51 57 67 71 84 89 10 10 11 11 12 13 14 15 14 14 15 15 15 16 16 15 17 21 22 24 24 23 23 21 20
ANNUAL ENERGY GENERATED (GWH)1973-2009 CHART 11
385457
579708
767887
1,0951,181
1,3231,448
1,4341,532
1,7201,730
1,8551,952
2,0082,219
2,2462,382
2,3302,4462,4522,470
2,4572,4482,458
2,4992,934.49
3,223.4 3,479.3
3,427.53,774.1
3,6823,6003,596
3,710
0 500 1000 1500 2000 2500 3000 3500 4000
73747576777879808182838485868788899091929394959697989900010203
040506070809
PEAK DEMAND (MW)
YEAR
73 74 75 76 77 78 79 80 81 82 83 84 85 86 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 03 04 05 06 07 08 09
PEAK 38 45 57 70 76 88 10 11 13 14 14 15 17 17 18 19 20 22 22 23 23 24 24 24 24 24 24 24 29 32 34 34 37 36 36 35 37
SIMULTANEOUS NATIONAL PEAK (MW)1973-2009 CHART 12
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The last option is seldom applied except all else failed as switching out of a circuit
would weaken the system security.
Since November, 2001 System supervision through the mirrored SCADA facilities of the
supplementary National Control Centre was of a tremendous benefit as voltage profile of
the 330kV buses were lucidly displayed on the Man-Machine-Interface (MMI) monitors.
1.6. Outage Planning
In 2009, Generation and Transmission outage plans were implemented. Following
analyses of each of these outages.
1.6.1 Generation Outage Planning
In fulfilling the requirement of the operational Procedure No. 10 (OP.10), each Power
Station and Transmission Regionforwarded their planned outages schedule for the year asfrom November, 2008.
This was sequel to NCCs memo addressed to the Chief Executive Officers in all the
Power stations and Regional Transmission Managers of the Transmission Regions. TheIndependent Power Producers (IPPs) of AES and Okpai were also included.
A coordinated master programme for 2009 planned outages was drawn mindful of theGrid integrity and security. Compliance with the maintenance plan was monitored in the
year.
1.6.2. Transmission Outage Planning
Prior to the approval of a planned outage for either the 330/132kV Transmission/Subtransmission lines, transformers, reactorsorswitchgears,system integrity, security and
stability were highly considered before conveying approval of the maintenance schedule
to each Station.
1.6.2.1 2009 Forced Outage Analysis
The following analyses were based on the equipment forced outage records kept at NCC.
1.6.2.2 330kV Circuit Forced OutagesNumber of 330kV forced outages in 2009was 440 (Table 5A). This was 29% higherthan 341recorded in year 2008.
21
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TABLE 4
NIGERIAPOWER SYSTEM FREQUENCY CHART
LIST ALLOCATION FREQUENCY REMARKS
NO. (HZ)
1 UPPER STATUTORY LIMIT 50.50
2 UPPER OPERATIONAL LIMIT 50.20
3 NORMAL FREQUENCY 50.00
4 LOWER OPERATIONAL LIMIT 49.80
5 LOWER STATUTORY LIMIT 49.50
6 THREE-STAGE UNDERFREQUENCY RELAY LOAD OPERATION:-
1 49.80HZ
2 49.50HZ
3 49.20HZ
7 1ST STAGE GEN. PROTECTION AFAM I GTS 49.00 0.5 SECS. DELAY
8 2ND STAGE GEN.PROTECTION SAPELE GTS. 48.70 1.0 SECS. DELAY
9 3RD STAGE GEN. PROTECTION:-
(i) AFAM II & III GAS TURBINES 48.50 INSTANTANEOUS.
(ii) AFAM IV GAS TURBINES 48.50 0.15 SECS.DELAY
(iii) SAPELE GAS TURBINES. 48.50 1.0 SECS.DELAY
(iv) GEREGU UNITS 48.50 20.0 SECS.DELAY
(v) AES UNITS 48.50 3.0 SECS.DELAY
(vi) AFAM VI GAS TURBINES 48.50 3.0 SECS.DELAY
10 4TH STAGE GEN. PROTECTION:
(i) DELTA IV GAS TURBINES 48.00 0.25 SECS.DELAY
(ii) OMOTOSHO UNITS 48.00
(iii) OLORUNSOGO UNITS 48.00
11 5TH STAGE GEN. PROTECTION:
SAPELE STEAM TURBINES 47.50 2.0 SECS.DELAY
12 6TH STAGE GEN. PROTECTION:
EGBIN ST.UNITS STAGE 1 47.50 0.5 SECS. DELAY [Fast Call Back]
STAGE 2 47.00 3.0 SECS.DELAY [House Load]
13 7TH STAGE GEN. PROTECTION:
OKPAI UNITS 46.95 0.15 SECS.DELAY
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M
ONTH
FORCED
OUTAGE
FORCED
CUMULATIVE
PLANNED
OUTAGE
PLANNED
CUMULATIVE
URGENT
OUTAGE
URGENT
CUMULATIVE
EMERGENCY
OUTAGE
EMERGE
NCY
CUMULA
TIVE
TOTAL
TOTALCUM.
JAN.
31
31
5
5
5
5
7
7
48
48
FEB.
26
57
6
11
10
15
9
16
51
99
MAR.
33
90
11
22
11
26
24
40
79
178
APR.
31
121
1
23
11
37
9
49
52
230
MAY
24
145
1
24
9
46
10
59
44
274
JUN.
50
195
5
29
20
66
32
91
107
381
JUL.
42
237
4
33
4
70
20
111
70
451
AUG.
30
267
1
34
8
78
13
124
52
503
SEP.
63
330
4
38
5
83
6
130
78
581
OCT.
34
364
6
44
4
87
5
135
49
630
NOV.
40
404
3
47
7
94
4
139
54
684
DEC.
36
440
3
50
20
114
5
144
64
748
M
ONTH
FORCED
OUTAGE
FORCED
CUMULATIVE
PLANNED
OUTAGE
PLANNED
CUMULATIVE
URGENT
OUTAGE
URGENT
CUMULATIVE
EMERGENCY
OUTAGE
EMERGE
NCY
CUMULA
TIVE
TOTAL
TOTALCUM.
JAN.
48
48
9
9
2
2
1
1
60
60
FEB.
45
93
8
17
4
6
1
2
58
118
MAR.
15
108
14
31
5
11
16
18
50
168
APR.
17
125
8
39
7
18
10
28
42
210
MAY
32
157
4
43
4
22
37
65
77
287
JUN.
20
177
10
53
7
29
29
94
66
353
JUL.
30
207
9
62
7
36
14
108
60
413
AUG.
17
224
6
68
10
46
3
111
36
449
SEP.
23
247
11
79
4
50
0
111
38
487
OCT.
23
270
2
81
8
58
0
111
33
520
NOV.
29
299
21
102
9
67
13
124
72
592
DEC.
42
341
1
103
8
75
12
136
63
655
200
9OUTAGESSTATISTICAL
SUMMARY
(330KV
LINE
-TABLE
5A)
200
8OUTAGESSTATISTICALSUMMARY
(330KV
LINE
-TABLE
5B)
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M
ONTH
FORCED
OUTAGE
FORCED
CUMULATIVE
PLANNED
OUTAGE
PLANNED
CUMULATIVE
URGENT
OUTAGE
URGENT
CUMULATIVE
EMERGENCY
OUTAGE
EMERGE
NCY
CUMULA
TIVE
TOTAL
TOTALCUM.
JAN.
67
67
7
7
29
29
102
102
205
205
FEB.
86
153
1
8
38
67
128
230
253
458
MAR.
91
244
8
16
37
104
293
523
429
887
APR.
106
350
5
21
27
131
234
757
372
1259
MAY
98
448
6
27
29
160
240
997
373
1632
JUN.
74
522
4
31
19
179
500
149
7
597
2229
JUL.
59
581
1
32
16
195
388
188
5
464
2693
AUG.
66
647
3
35
15
210
324
220
9
408
3101
SEP.
89
736
6
41
30
240
181
239
0
306
3407
OCT.
75
811
1
42
20
260
196
258
6
292
3699
NOV.
58
869
4
46
23
283
146
273
2
231
3930
DEC.
48
917
6
52
25
308
92
282
4
171
4101
M
ONTH
FORCED
OUTAGE
FORCED
CUMULATIVE
PLANNED
OUTAGE
PLANNED
CUMULATIVE
URGENT
OUTAGE
URGENT
CUMULATIVE
EMERGENCY
OUTAGE
EMERGE
NCY
CUMULA
TIVE
TOTAL
TOTALCUM.
JAN.
49
49
16
16
23
23
324
324
412
412
FEB.
53
102
8
24
17
40
346
670
424
836
MAR.
61
163
7
31
16
56
351
102
1
435
1271
APR.
48
211
9
40
17
73
453
147
4
527
1798
MAY
57
268
4
44
18
91
498
197
2
577
2375
JUN.
67
335
8
52
23
114
388
236
0
486
2861
JUL.
68
403
5
57
28
142
122
248
2
223
3084
AUG.
102
505
1
58
28
170
71
255
3
202
3286
SEP.
99
604
13
71
25
195
40
259
3
177
3463
OCT.
112
716
8
79
40
235
39
263
2
199
3662
NOV.
68
784
8
87
24
259
107
273
9
207
3869
DEC.
81
865
6
93
30
289
163
290
2
280
4149
2009
OUTAGESSTATISTICAL
SUMMARY
(132KV
LINE-TABLE6A)
2008OUTAGESSTATISTICAL
SUMMARY
(132KV
LINE-TABLE6B)
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The years peak incidents of 330kV forced outages of 63were attained in September.
Year average was 26. The least incident of 24 occurred in May. In the previous year aminimum of 15330kV forced outages wasrecorded in March, 2008.
1.6.2.3 132kV Circuit Forced OutagesIn 2009, there were 917 incidents of 132kV forced outages. It rose by 5.6% in
comparison with 2008 value of 865. The year commenced with 67 number of 132kVforced outages. It peaked at 106in Apriland closed at 48incidents by December with
a year average of 76.
1.6.2.4 330kV Planned, Urgent And Emergency Outages
Frequencies of occurrence planned and emergency outages in 2009were 50, 114and 144respectively compared with 103, 75 and 136 values of 2008. There was drop of 53 in
planned outage but urgent and emergency outages increased in number by 35(9.6%) and 8(5.5%).
1.6.2.5 132kV Planned, Urgent And Emergency OutagesIn 2009the incidents of 132kV planned,urgent and emergency outages summed up to 53,
308 and 2824. Relative to 2008 withfigures of 93, 289and 2902respectively, incidents
of planned and emergency outages dropped by 40(78%) and 78(2.7%) - (Tables 6Aand 6B).
1.6.2.6 Combined 330kV and 132kV OutagesThere were 748 330kV outages comprising forced, planned, urgent and emergency
outages in 2009. It rose by 93 compared with 2008 figure of 635. Year 2009 had a
combined 4101 incidents of 132kV outages. It dropped by 78in comparison with 2008value of 4149.
The reduction in total number of incidents in 2008 could be attributed to measures takenin June, 2008 to address incessant system disturbance. It involves a 12-hour,2-Zonal load
allocation arrangement. A Zone had supply for 12-hours as the other was on outage.
This arrangement ensured full and uninterrupted supply to a Zone.
1.7 ENERGY PRODUCTIONThe total energy generated from all the Power Stations owned by the Power Holding
Company of Nigeria (PHCN) was 13577979.69MWH. This figure was by 16.61% lowerthan that generated in 2008.
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0
50
100
150
200
250
300
350
400
450
500
JAN. FEB. MAR. APR. MAY JUN. JUL. AUG. SEP. OCT. NOV. DEC.
CUMMULATIVEFREQUENCYOFOUTAGE
S
MONTHS
330KV FORCED OUTAGES (2008 & 2009)CHART 13 (TABLES 5A & 5B)
2008MONTHLY 2009MONTHLY 2008CUM 2009CUM
0
100
200
300
400
500
600
700
800
900
1000
JAN. FEB. MAR. APR. MAY JUN. JUL. AUG. SEP. OCT. NOV. DEC.
CUMMU
LATIVEFREQUENCY
OFOUTAGES
MONTHS
132KV FORCED OUTAGES (2008 & 2009)CHART 14 (TABLES 6A & 6B)
2008MONTHLY 2009MONTHLY 2008CUM 2009CUM
26
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COMBINED 2008 & 2009 330KV OUTAGESCHART 15 (TABLES 5A & 5B)
0
100
200
300
400
500
600
700
800
JAN. FEB. MAR. APR. MAY JUN. JUL. AUG. SEP. OCT. NOV. DEC.
MONTHS
CUMMULA
TIVEFREQUENCYOFOUTAGES
2008MONTHLY 2009MONTHLY
COMBINED 2008 & 2009 132KV OUTAGESCHART 16 (TABLES 5A & 5B)
0
500
1000
1500
2000
2500
3000
3500
4000
4500
JAN. FEB. MAR. APR. MAY JUN. JUL. AUG. SEP. OCT. NOV. DEC.
MONTHS
CUMULATIVEFREQUE
NCYOFOUTAGES
2008MONTHLY 2009MONTHLY
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0
20
40
60
80
100
120
140
160
JAN. FEB. MAR. APR. MAY JUN. JUL. AUG. SEP. OCT. NOV. DEC.
CUMULATIVE
FREQUENCY
OFOUTAGES
MONTHS
330KV PLANNED, URGENT & EMERGENCY OUTAGES (2008 & 2009)CHART 17 (TABLES 5A & 5B)
2008 PLAN CUM 2009 PLAN CUM 2008 URGENT CUM
2009 URGENT CUM 2008 EMERGENCY CUM 2009 EMERGENCY CUM
0
500
1000
1500
2000
2500
3000
3500
JAN. FEB. MAR. APR. MAY JUN. JUL. AUG. SEP. OCT. NOV. DEC.
CUMULATIVE
FREQUENCY
OFOUTAGES
MONTHS
132KV PLANNED, URGENT & EMERGENCY OUTAGES ( 2008& 2009)CHART 18 (TABLES 5A & 5B)
2008 PLAN CUM 2009 PLAN CUM 2008 URGENT CUM
2009 URGENT CUM 2008 EMERGENCY CUM 2009 EMERGENCY CUM
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Independent Power Plants (IPPs) which included AES (former Enron), Okpai, Ibom,
Omoku (P/H) and Afam VI all together generated 7315453.11MWH (see Table 7.)
This figure was higher than 2008 figure of 5025638.94MWH by 45.56%.
The Niger-Delta problem affected the energy production from the Thermal Power
Stations gravely.
The Nigerian Electricity Supply Corporation Limited (NESCO) and Omoku (PH) were
still feeding isolated portion of the grid on 33kV network.
The total energy pooled by all the PHCN owned Power Stations and the IPPs excluding
NESCO was 20893432.80MWH.
Overall, the total energy produced in the country including NESCO fell by 1.93% incomparison with the energy produced in 2008.
Hydro Power Generation in 2009 was 7464640.00(35.73%) while the thermal powerPlants produced 13428792.80MWH (64.27%) (see Table 8.0)
Maintenance of the units in hydro power stations was normally scheduled to hold
during the dry seasononly(July - September).
Jebba P.S produced less energy in 2009 (2676860.00MWH) when compared with the
energy production in 2008 (2794976MWH). The decrease was as a result of reducedinflow into the Lake.
The shortfall in thermal generation could be attributed to:
a. Unstable dry gas supply from Nigerian Gas Companyb. Each time there was system disturbance,thermal plants seldom came back quickly
especially the steam turbines.
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The simultaneous National Peak Generation for 2009was 3710.0MW which occurred on
December 24, 2009. It was greaterthan the previous year by 114.1MW(3.17%).
All the power stations consumed a total of 563981.38MWH in 2009, bringing the overall
consumption to 2.70% of total generation.
The net energy sent out to the various injection substations, via the Transmission lineswas 20329451.42MWH. Total energy made available for sales and Distribution losses
by the end of 2009was 18620097.53MWH. Thisrepresented 91.59% of the total energy
sent out.
The overall transmission losses and substation consumption amounted to 8.41% of the
total energy sent out (see Table 10)
1.7.1 Energy Sales Analysis
Tables 10 and 11 show the total Energy made available for the eight (8) TransmissionRegion across the country.
(a) Lagos Region
(Ikeja West, Akangba, Egbin & Aja
Area Transmission) 4971291.81MWH
Injection points (26.69%)
(b) Enugu Region
(New Haven, Onitsha Area Transmission) 1722387.71MWH
Injection points (9.25%)
(c) Osogbo Region
(Osogbo, Ayede, OmotoshoArea Transmission) 2358247.56MWH
Injection points (12.66%)
(d) Port- Harcourt Region
(Alaoji Area Transmission) 1825474.76MWHInjection points (9.80%)
(e) Kaduna Region
30
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MONTHS
HYDRO
ENERGY
GENERATE
D
HYDRO
ENERGY
USED
IN
STATION
THERMAL
ENERGY
GENERATED
THERMAL
ENERGY
USED
IN
STATION
TOTAL
ENERGYUSED
IN
STATION
HYDR
OENERGY
SE
NTOUT
THERMAL
ENERGYSENT
OUT
TOTA
LENERGY
GENERATED
TOTAL
ENERGY
SENTOUT
JAN.
710021.00
2149.23
1225195.05
44784.42
46933.65
707871.77
1180410.63
19
35216.05
1888282.40
FEB.
604528.00
1954.48
1176801.42
44414.49
46368.97
602573.52
1132386.93
17
81329.42
1734960.45
MAR.
700038.00
2340.53
1280314.49
45286.57
47627.10
697697.47
1235027.92
19
80352.49
1932725.39
APR.
555838.00
2361.50
1151407.19
48136.51
50498.01
553476.50
1103270.68
17
07245.19
1656747.18
MAY.
532167.00
2045.41
1114125.54
39645.38
41690.79
530121.59
1074480.16
16
46292.54
1604601.75
JUN.
392378.00
2285.85
994052.42
41036.66
43322.51
390092.15
953015.76
13
86430.42
1343107.91
JAN-JUN
TOTAL
3494970.00
13137.00
6941896.11
263304.03
276441.03
34
81833.00
6678592.08
10436866.11
10160425.08
JUL.
379769.00
2120.00
919010.05
44915.08
47035.08
377649.00
874094.97
12
98779.05
1251743.97
AUG.
572760.00
1995.12
983326.82
38145.94
40141.06
570764.88
945180.88
15
56086.82
1515945.76
SEP.
783355.00
2068.10
926470.04
41976.01
44044.11
781286.90
884494.03
17
09825.04
1665780.93
OCT.
765787.00
2274.98
1020586.60
47374.44
49649.42
763512.02
973212.16
17
86373.60
1736724.18
NOV.
721265.00
2143.32
1208386.43
49452.10
51595.42
719121.68
1158934.33
19
29651.43
1878056.01
DEC.
746734.00
2239.24
1429116.75
52836.02
55075.26
744494.76
1376280.73
21
75850.75
2120775.49
JUL-DEC
TOTAL
3969670.00
12840.76
6486896.69
274699.59
287540.35
39
56829.24
6212197.10
10456566.69
10169026.34
ANNUAL
TOTAL
7464640.00
25977.76
13428792.80
538003.62
563981.38
74
38662.24
12890789.18
20893432.80
20329451.42
TABLE8:HYDRO
&THERMALGE
NERATED(MWH
)JAN-DEC.2009
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PERCENTAGE ENERGY USED IN POWER STATIONS
JANUARY - DECEMBER 2008/2009 CHART 19 (SEE TABLE 9)
0.00
1.00
2.00
3.00
4.00
5.00
6.00
7.00
8.00
9.00
10.00
11.00
12.00
13.00
JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC
MONTHS
%ENERGYUSEDINPOWER
STATIONS
2008 2009
HYDRO, THERMAL & TOTAL ENERGY GENERATED (MWH)
JANUARY - DECEMBER 2009 CHART 20 (SEE TABLE 8)
0
500
1000
1500
2000
2500
JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC
Thousands
MONTHS
ENERGY
GENERATED(MWH)
HYDRO ENERGY GENERATED (MWH)
THERMAL ENERGY GENERATED (MWH)
TOTAL ENERGY GENERATED (MWH)
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(Kaduna and Kano Area Transmission) 1755436.59MWH
Injection points (9.42%)
(f) Shiroro Region
(Shiroro, Birnin Kebbi, Jebba & Katampe 2990617.91MWH
Area Transmission)Injection points (16.05%)
(j) Bauchi Region
(Gombe and Jos Area Transmission) 903556.68MWH
Injection points (4.85%)
(h) Benin Region
(Benin & Ajaokuta Area Transmission) 2100718.42MWH
Injection points (11.28%)
Lagos Region consumed 26.69% of the total energy made available for sales
in 2009. In 2008, the Region consumed 29.40% of the energy made available for sales.
Similarly, Enugu Region in 2009consumed 9.25% while in 2008 it consumed 8.54%. of
the total energy made available for sales. The incessant trippings of Benin/ Onitshaand Onitsha/Alaoji 330kV Lines contributed to loss of revenue from this axis.
It has been observed that Osogbo, PortHarcourt,Shiroro and Benin Regions improved
in their consumption, 12.66% , 9.80 %, 16.05% and 11.18% respectively from 11.38%, 8.42%,15.18% and 10.56% in 2008.
Bauchi and Kaduna Regions both dropped in their consumption from 5.27% and 11.26%in 2008 to 4.85% and 9.24% in 2009.
For three consecutives years the energy made available for sales has been dropping. In2007 it dropped by 2.58% , in 2008 by 7.51%and in 2009 by 1.36%.
1.7.2. GAS SUPPLY TO THERMAL STATIONS
PHCN is a major consumer of the abundant natural gas marketed by Nigerian Gas
Company (NGC) to generate power for the country and her neighbours. All the PHCN
owned Thermal Power Stations namely Egbin, Sapele, Delta, Afam 1-V, Geregu,
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Omotosho and Olorunsogo, and IPPs such as AES, Okpai, Ajaokuta, AfamVI ran primarily on
natural gas. During the period of drought or low lake levels, all these Power Station depended
solely on the gas supply. Okpai G.S. rarely had gas problems because they own and maintain
their gas wells. Over the years, the quantity and quality of this commodity supplied by NGC,had not been adequate for PHCN operations. Some of the consequences of this inadequate
supply were:
1. Inability of PHCN to utilize available thermal plants capacity for power generation.
2. Plants breakdowns due to ingress of condensate in the Combustion chamber or incessant
. forced outage.
3. Frequent system disturbances.
4. Embarrassment to PHCN corporate image in particular and the country at large.
5. Loss of revenue to PHCN and economic activities throughout the country.
6. Enironmental pollution as some customers put on their personal generators inin the absence of PHCN supply.
7. Insecurity Evil practices thrived in locations without electricity.
8. Much demand was put on the hydro turbines, making it difficult to follow planned projections.
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ENERGY GENERATED IN HYDRO P.S. (MWH)JANUARY-DECEMBER 2009 CHART 21 (SEE TABLE 7)
0
50
100
150
200
250
300
350
JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC
Thou
sands
MONTHS
ENERGYGENERATED(MW
H)
KAINJI JEBBA SHIRORO
ENERGY GENERATED IN MAJOR THERMAL P.S. (MWH)JANUARY-DECEMBER 2009 CHART 22 (SEE TABLE 7)
0
50
100
150
200
250
300
350
400
450
JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC
Thousan
ds
MONTHS
ENERGYGENERATED(MWH)
EGBIN SAPELE DELTA AFAM OMOTOSHO GEREGU OLORUNSOGO
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MONTHS
ENERGY
GENERATED
(MWH)
USED IN
POWER
STATIONS
(MWH)
% ENERGY USED IN POWER
STATIONS
JAN. 1935216.05 46933.65 2.43
FEB. 1781329.42 46368.97 2.60
MAR. 1980352.49 47627.10 2.40
APR. 1707245.19 50498.01 2.96
MAY. 1646292.54 41690.79 2.53
JUN. 1386430.42 43322.51 3.12-
TOTAL 10436866.11 276441.03 2.65
JUL. 1298779.05 47035.08 3.62
AUG. 1556086.82 40141.06 2.58
SEP. 1709825.04 44044.11 2.58
OCT. 1786373.60 49649.42 2.78
NOV. 1929651.43 51595.42 2.67
DEC. 2175850.75 55075.26 2.53-
TOTAL 10456566.69 287540.35 2.75
TOTAL 20893432.80 563981.38 2.70
TABLE 9: ENERGY GENERATION AND POWER
CONSUMPTION RECORDS: JAN - DEC 2009
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AVAILABLE ENERGY FOR SALES
JANUARY - DECEMBER 2009 CHART 23 (SEE TABLE 10)
200
700
1200
1700
2200
2700
JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC
Thousands
MONTHSENER
GYINMWH
MWH FOR SALES MWH SENT OUT MWH GENERATED
TOTAL MONTHLY ENERGY FOR SALES (MWH)
JANUARY-DECEMBER 2008/2009 CHART 24 (SEE TABLE 11)
0
500
1000
1500
2000
2500
JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC
Thousands
MONTHS
ENERGYAVAILABLEFOR
S
ALES(MWH)
2008 2009
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MONTHS
ENERGY
GENERATED
(MWH)
ENERG
Y
SENTO
UT
(MWH
)
ENERGY
AVAILABLE
FORSALES&
DIST.LOSSES
MWH
TX
.LOSSES
&S
UB.STN.
CONSUMPSI
ON
(MWH)
TX.LOSSES
&
SUB.STN.
CONSUMPS
IO
N%OF
ENERGYSE
NT
ENERGY
AVAILABLE
FORSALES&
DIST.LOSSES%
OFENERGY
JAN.
1935216.05
1888282.40
1699465.95
188816.45
10.00
90.00
FEB.
1781329.42
1734960.45
1577290.34
157670.11
9.09
90.91
MAR.
1980352.49
1932725.39
1760663.30
172062.09
8.90
91.10
APR.
1707245.19
1656747.18
1542223.78
114523.40
6.91
93.09
MAY.
1646292.54
1604601.75
1484568.92
120032.83
7.48
92.52
JUN.
1386430.42
1343107.91
1226006.23
117101.68
8.72
91.28
-
TOTAL
10436866.11
10160425
.08
9290218.52
870206.56
8.56
91.44
JUL.
1298779.05
1251743.97
1187732.36
6
4011.61
5.11
94.89
AUG.
1556086.82
1515945.76
1423773.75
9
2172.01
6.08
93.92
SEP.
1709825.04
1665780.93
1559646.24
106134.69
6.37
93.63
OCT.
1786373.60
1736724.18
1575205.17
161519.01
9.30
90.70
NOV.
1929651.43
1878056.01
1712447.57
165608.44
8.82
91.18
DEC.
2175850.75
2120775.49
1871073.92
249701.57
11.77
88.23
JUL-DEC
TOTAL
10456566.69
10169026
.34
9329879.01
839147.33
8.25
91.75
ANNUAL
TOTAL
20893432.80
20329451
.42
18620097.53
17
09353.89
8.41
91.59
TA
BLE10:MONTHLY
ENERGYBALANCESUMMARYJAN.-DEC.2009
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REGION
LAG
OS
ENUGU
OSOGBO
P/HARCOURT
KADUNA
SHIRORO
BAUCHI
BE
NIN
TOTAL
JAN.
467
638.34
150787.10
194697.84
143435.60
180371.76
270657.40
88714.40
20
3163.51
1699465.95
FEB.
421
596.83
134366.30
187599.94
153921.00
175038.21
239551.01
81150.98
18
4066.08
1577290.35
MAR.
504
800.46
143376.70
211977.58
165608.69
182429.21
278405.10
85192.70
18
8872.86
1760663.30
APR.
411
807.52
135475.80
205085.81
147386.67
156191.41
248514.00
75885.10
16
1877.47
1542223.78
MAY.
391
686.65
139354.40
183441.16
134566.90
140976.01
249517.20
72122.10
17
2904.50
1484568.92
JUN.
276
153.76
140562.00
168589.73
151412.70
98888.64
210268.30
48287.50
13
1843.60
1226006.23
JAN-
APRIL
2473
683.56
843922.301151392.06
896331.56
933895.24
1496913.01
451352.78104
2728.02
9290218.53
JUL.
260
205.43
129477.70
167403.80
127981.40
98969.53
198635.80
47735.40
15
7323.30
1187732.36
AUG.
339
881.95
130486.60
213891.10
164338.50
113934.20
240889.60
57087.30
16
3264.50
1423773.75
SEP.
405
466.65
142885.10
202449.20
161159.90
139985.69
257728.90
72661.10
17
7309.70
1559646.24
OCT.
414
256.97
143864.30
193957.90
150003.60
165483.90
272391.90
83600.30
15
1646.30
1575205.17
NOV.
504
211.16
146949.74
199524.00
158442.30
145440.17
257493.10
89736.10
21
0651.00
1712447.57
DEC.
573
586.09
184801.97
229629.50
159583.60
157727.86
266565.60
101383.70
19
7795.60
1871073.92
JUL-DEC
TOTAL
2497
608.25
878465.411206855.50
921509.30
821541.35
1493704.90
452203.90105
7990.40
9329879.01
ANNUAL
TOTAL
4971
291.811722387.712358247.561817840.86
1755436.59
2990617.91
903556.68210
0718.4218620097.54
DISTRIBUTIONLOSSESINEACHREGION(MWH)JAN-DECEM
BER2009
41
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MONTH
EGBIN
AES
DELTA
SAPELE
AFAM
OM
OTOSHO
GEREGU
OLORUNSO
GO
TOTAL
JAN
4112503794.00
1968713700.00
2390641251.00
0.00
172077631.00
1536
84452.67
804088378.00
455997730.00
10057706936.67
FEB
364920471
.40
1981069900.00
2289295589.25
0.00
78708685.00
3472
33183.64
623684977.00
85072722
.00
5769985528.29
MAR
3924360317.00
2141829700.00
2685364532.17
0.00
64588685.00
5307
82542.99
733242392.00
47979545
.00
4891782917.17
APR
3527146835.00
2186922000.00
2297479815.66
0.00
96414437.00
3713
40756.50
678364432.71
218293183.00
8107963087.66
MAY
3141182586.00
1757155600.00
1718808539.56
0.00
224844210.00
2808
99748.55
460962078.92
67943183
.00
7651795946.03
JUN
2346841177.00
2095357700.00
1956246857.44
0.00
270174314.00
2276
82868.00
0.00
0.00
6896302916.44
JUL
2040317043.00
1521875300.00
1422456932.05
0.00
242656832.00
2648
74365.84
0.00
0.00
5492180472.89
AUG
2236037702.00
1770775400.00
1188863320.50
0.00
285176224.00
2900
74232.65
0.00
0.00
5770926879.15
SEP
2637801045.00
1733363400.00
927947900.14
0.00
81860940.00
3175
62721.35
146549308.60
0.00
5845085315.09
OCT
2822260379.00
1690016600.00
1089816182.12
333656876.00
77912048.00
1920
51740.00
506931861.35
0.00
6712645686.47
NOV
3808197380.00
1458147400.00
2017036381.42
768833581.00
229498757.00
9193
76197.00
711815048.70
64934093
.00
8281713499.42
DEC
4175838761.00
1641033300.00
1944353761.68
300362556.00
451309375.00
3838
70379.00
405571293.23
0.00
8512897753.68
TOTAL
35137407490.40
21946260000.00
21928311062.99
1402853013.00
2275222138.00
4279
433188.19
5071209770.51
94022045
6.00
82690053704.39
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MONTH
E
GBIN
AES
DELTA
SAPELE
AFAM
OM
OTOSHO
GEREGU
LORUN
SOG
TOTAL
JANUARY
129,543,869.51
62,014,481.55
75,305,199.41
0.00
5,420,445.38
4
,841,060.26
25,328,783.91
14,363,928
.50
316,817,768.51
FEBRUARY
114,949,948.49
62,403,701.85
72,112,811.06
0.00
2,479,323.58
10,937,845.28
19,646,076.78
2,679,790.74
285,209,497.78
MARCH
123,617,349.99
67,467,635.55
84,588,982.76
0.00
2,034,543.58
16,719,650.10
23,097,135.35
1,511,355.67
319,036,653.00
APRIL
111,105,125.30
68,888,043.00
72,370,614.19
0.00
3,037,054.77
11,697,233.83
21,368,479.63
6,876,235.26
295,342,785.99
MAY
98,9
47,251.46
55,350,401.40
54,142,469.00
0.00
7,082,592.62
8
,848,342.08
14,520,305.49
2,140,210.26
241,031,572.30
JUNE
73,9
25,497.08
66,003,767.55
61,621,776.01
0.00
8,510,490.89
7
,172,010.34
0.00
0.00
217,233,541.87
JULY
64,2
69,986.85
47,939,071.95
44,807,393.36
0.00
7,643,690.21
8
,343,542.52
0.00
0.00
173,003,684.90
AUGUST
70,4
35,187.61
113,942,839.50
106,429,169.3
7
0.00
16,154,181.10
15,515,552.87
0.00
0.00
322,476,930.45
SEPTEMBER
83,0
90,732.92
54,600,947.10
29,230,358.85
0.00
2,578,619.61
10,003,225.72
4,616,303.22
0.00
184,120,187.43
OCTOBER
88,9
01,201.94
53,235,522.90
34,329,209.74
10,510,191.59
2,454,229.51
6
,049,629.81
15,968,353.63
0.00
211,448,339.12
NOVEMBER
119,958,217.47
45,931,643.10
63,536,646.01
24,218,257.80
7,229,210.85
28,960,350.21
22,422,174.03
2,045,423.93
314,301,923.40
DECEMBER
137,838,920.97
51,692,548.95
61,247,143.49
9,461,420.51
14,216,245.31
12,091,916.94
12,775,495.74
0.00
299,323,691.92
TOTAL
1,216
,583,289.59
749,470,604.40
759,721,773.2
6
44,189,869.91
78,840,627.39
14
1,180,359.97
159,743,107.77
29,616,944
.36
3,179,346,576.65
AVERAGE
101,381,940.80
62,455,883.70
63,310,147.77
3,682,489.16
6,570,052.28
11,765,030.00
13,311,925.65
2,468,078.70
264,945,548.05
TABLE13
COSTOFGAS(NAIRA)AGAINSTE
NERGYENERATED
200
9
43
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GENER
ATED
SEN
T
OUT
GENERAT
ED
SENTOUTGENERA
TED
SENT
OUT
GENER
ATED
SENT
OUT
GENER
ATED
SENT
OUT
GENERA
TED
SENT
OUT
GENER
ATED
SENT
OUT
GENERA
TED
SENT
OUT
GENER
ATED
SENT
OUT
GENERA
TED
SENT
OUT
JAN
0.3570
0.3833
0.4099
0.4221
0.4359
0.4387
0.0000
0.0000
0.5221
0.5344
0.3604
0.3691
0.4324
0.4366
0.4106
0.4239
0.3939
0.4105
0.2092
0.2141
FEB
0.3572
0.3851
0.4094
0.4223
0.4489
0.4518
0.0000
0.0000
0.4810
0.5018
0.3686
0.3731
0.3685
0.3716
0.1161
0.1219
0.3823
0.3989
0.2112
0.2165
MAR
0.3571
0.3845
0.4105
0.4217
0.4622
0.4652
0.0000
0.0000
0.6099
0.6542
0.3509
0.3558
0.3726
0.3757
0.1166
0.1275
0.3893
0.4055
0.2100
0.2149
APR
0.3104
0.3333
0.4119
0.4255
0.4619
0.4740
0.0000
0.0000
0.5067
0.5277
0.3647
0.3694
0.4431
0.4475
0.3591
0.3810
0.3751
0.3932
0.2199
0.2264
MAY
0.3315
0.3564
0.4129
0.4263
0.4317
0.4320
0.0000
0.0000
0.5720
0.5855
0.3702
0.3767
0.4858
0.4924
0.2998
0.3545
0.4010
0.4193
0.2176
0.2233
JUN
0.4016
0.4454
0.4111
0.4234
0.4232
0.4366
0.0000
0.0000
0.6136
0.6232
0.3648
0.3726
0.0000
0.0000
0.0000
0.0000
0.4051
0.4279
0.2316
0.2395
JUL
0.3911
0.4366
0.4140
0.4258
0.4251
0.4415
0.0000
0.0000
0.4888
0.4964
0.2815
0.3777
0.0000
0.0000
0.0000
0.0000
0.4204
0.4541
0.2234
0.2332
AUG
0.3755
0.4110
0.4111
0.4252
0.4100
0.4101
0.0000
0.0000
0.4968
0.5047
0.3701
0.3770
0.0000
0.0000
0.0000
0.0000
0.3975
0.4170
0.1765
0.1806
SEP
0.3987
0.4411
0.4119
0.4255
0.3885
0.3979
0.0000
0.0000
0.5617
0.5901
0.4050
0.4128
0.4454
0.4493
0.0000
0.0000
0.4039
0.4292
0.1486
0.1521
OCT
0.3956
0.4326
0.4114
0.4241
0.3854
0.4091
0.3618
0.4190
0.3687
0.3801
0.2458
0.2504
0.4013
0.4047
0.0000
0.0000
0.4088
0.4145
0.1648
0.1660
NOV
0.3553
0.3809
0.4094
0.4234
0.4198
0.4248
0.3554
0.3891
0.3947
0.4006
0.3643
0.3674
0.4871
0.4925
0.3260
0.3953
0.3836
0.4015
0.2040
0.2093
DEC
0.3534
0.3781
0.4107
0.4223
0.4536
0.4612
0.3930
0.4663
0.3880
0.3912
0.3563
0.3616
0.4198
0.4249
0.0000
0.0000
0.3857
0.4045
0.1966
0.2016
AVERAGE
0.3654
0.3974
0.4112
0.4240
0.4289
0.4369
0.0652
0.0735
0.5003
0.5158
0.3502
0.3636
0.3213
0.3246
0.1357
0.1503
0.3955
0.4147
0.2011
0.2065
MONTHS
MONTHLY
THERMAL
OPT.COST
COST/UNIT
AFAM
COST/UNIT
COST/UNIT
OLORUNSOG
O
COST/UNIT
TOT.MONTHLY
HYD/THERMAL
PROD.COST
COST/UNIT
GEREGU
COST/UNIT
TABLE14OPERATING
FUELCOST(NAIRA/KW
h)JANUARY-DECEMBER
2009
EGBIN
COST/UN
IT
AES
COST/UNIT
OMOT
OSHO
COST/UNIT
DELTA
COST/UNIT
SAPELE
44
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REGIONAL ENERGY FOR SALES (MW)
JANUARY-DECEMBER 2009, CHART26(TABLE 11)
2100718.42
11.28%903556.68
4.85%
2990617.91
16.06%
1755436.59
9.43% 1817840.86
9.76%
2358247.56
12.67%
1722387.71
9.25%
4971291.81
26.70%
LAGOS ENUGU OSOGBO P/HARCOURT
KADUNA SHIRORO BAUCHI BENIN
TRANSMISSION REGIONS MONTHLY ENERGY FOR SALES
(MWH)
JANUARY-DECEMBER 2009, CHART 25 (SEE TABLE 11)
0
100,000
200,000
300,000
400,000
500,000
600,000
700,000
JAN. FEB. MAR. APR. MAY. JUN. JUL. AUG. SEP. OCT. NOV. DEC.
MONTHS
ENERGYAVAILABLEFORSALES(M
WH)
LAGOS ENUGU OSOGBO
P/HARCOURT KADUNA SHIRORO
BAUCHI BENIN
45
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MAJOR
TH
ERMALSTATIONSFUELCOSTS.
C
HART27(SEETAB
LE13)
0.00
20,000,
000.00
40,000,
000.00
60,000,
000.00
80,000,
000.00
100,000,
000.00
120,000,
000.00
140,000,
000.00
160,000,
000.00
JAN
FEB
M
AR
APR
MAY
JUN
JUL
AUG
SEP
O
CT
NOV
DEC
MONTHS
COSTS IN NAIRA (MILLIONS)
EGBIN
AES
DELTA
SAPELE
AFAM
OMOTOSHO
GEREGU
OLORUNSOGO
46
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MONTHLY
UNITPROD.COST(
NAIRA/UNIT)
CHART28(SEETABLE
14)
0.0
0.1
0.1
0.2
0.2
0.3
0.3
0.4
0.4
0.5
0.5
J
AN
FEB
MAR
AP
R
MAY
JUN
JUL
AUG
SEP
OCT
NOV
DEC
MONTH
S
UNIT PRODUCTION COST (NAIRA/UNIT).
THMALGEN.COST
THMALSENTOUTCOST
THMAL&
HYGEN.
COST
THMAL&HYD
SENTOUTC
OST
47
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STATIO
NSAVE.PROD.COST
S(NAIRA/UNIT)
CHART29(SEETAB
LE14)
0.00
0.10
0.20
0.30
0.40
0.50
0.60
0.70
EGBIN
AES
DELT
A
SAPELE
AFAM
OM
OTOSHO
GEREGU
OLORUNSO
GO
POWERSTATION
S
UNIT PRODUCTION COSTS (NAIRA/UNIT)
48
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2.0. CONSTRAINTS TO GRID OPERATIONS
This subject is treated under the following sub-headings: 2.1. System Control Constraints
2.2. Generation Constraints.
2.3. Transmission Constraints
2.1. Constraints to Grid Operations: System Communications
2.1.1 Achievements
2.1.1.1 System Communications
In the System Communications Maintenance Subsector great efforts are continually being madeto ensure availability of reliable telecommunications for effective Power System Operations andControl. Following are some of the achievements made in the year under review.
i. Provision of HOTLINE Communication to OKPAI Power Station.ii. Restoration of HICOM Optic Fibre Voice Communication to Akangba T.S. (Extension
2287) and Ikeja West (Extension 2286). This doubles the media of communicationfrom NCC to these stations.
iii.
Installation of Voice Communication through PAX/PLC (Power Link Type) andMicrowave Radio to following 132KV Stations Ile-Ife, Ilesa, Ondo, Akure, Offa andOmuaran.
iv. Provision of Fibre Optics Communication via SOPHO PAX between Osogbo (NCC) and
Ayede 330KV T.S. This is to augment the existing PAX/PLC Communication to Ayede.v. Restoration of PLC Communication media to Afam P.S., Jebba T.S., Alaoji T.S. and
Delta P.S. after a major breakdown of the PLC equipment in these stations. CorporateHeadquarters provided the spare RF converter (P4LQ) modules used to replace the
faulty ones.vi. Restoration of HICOM Optic Fibre telephone line No. 2282 to Benin T.S. This facilitates
having double media to Benin T.S. also.
The above achievements have really enhanced effective Power System Operations and Controlunlike the previous years. There is now redundancy to most stations where NCC cancommunicate to through Optic Fibre medium and Power Line Carrier medium. This makescommunication more reliable and System Operations easier.
2.1.2. Constraints
2.1.2.1. System Communications
i. As a result of the vandalized ADLASH Optic Fibre cable between Benin T.S., Sapele and
Delta Power Stations, communication to these stations has been a big problem
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especially during system restoration after a collapse. For reliability ofcommunication to these stations there is need to restore these Optic Fibre cables.Meanwhile only PAX/PLC with limited channel is in use to reach the two stations.
ii. Contract has been awarded to rehabilitate the DC S255 switches in New Haven,
Kaduna, Kano, Gombe, Onitsha, Alaoji and Egbu 330KV Transmission Stations for moreefficient interconnectivity between the various stations and NCC, Osogbo.
iii. Contract hasbeen awarded for provision of Direct Voice Communication line fromNCC to Kainji, Ayede, Ikeja West, Egbin, Jebba T.S., Jebba G.S., Shiroro, Benin, DeltaP.S., Sapele P.S. via the existing PDH Optic Fibre equipment.
iv. Contracts have also been awarded to extend the reach of Optic Fibre technology fromShiroro to Kaduna to Kano route and Kaduna-Jos-Gombe route.
v. Contracts for rehabilitation of 11no. PLC links have been awarded in order to improveGRID Telecommunication.
vi.Another big constraint to System Communication which has not been taken care of islack of communication me