2009 AnnualReport Final-13!05!10

7/14/2019 2009 AnnualReport Final-13!05!10

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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

(i)


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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

(ii)


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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

(iii)


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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

(iv)


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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.

1


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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

4


10/104

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

6


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0

200

400

600

800

1000

1200

1400

1600

1800

2000


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



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


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



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

8


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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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16/104


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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


19/104


20/104

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


21/104

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)

16


22/104

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

17


23/104

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 )

18


24/104

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)

19


25/104

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

20


26/104

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

contd pg. 29


27/104

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


SAPELE STEAM TURBINES 47.50 2.0 SECS.DELAY


EGBIN ST.UNITS STAGE 1 47.50 0.5 SECS. DELAY [Fast Call Back]

STAGE 2 47.00 3.0 SECS.DELAY [House Load]


OKPAI UNITS 46.95 0.15 SECS.DELAY

22


28/104

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)

23


29/104

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)

24


30/104

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.

25


31/104

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


CUMMU

LATIVEFREQUENCY

OFOUTAGES

MONTHS

132KV FORCED OUTAGES (2008 & 2009)CHART 14 (TABLES 6A & 6B)

2008MONTHLY 2009MONTHLY 2008CUM 2009CUM

26


32/104

COMBINED 2008 & 2009 330KV OUTAGESCHART 15 (TABLES 5A & 5B)

0

100

200

300

400

500

600

700

800


MONTHS

CUMMULA

TIVEFREQUENCYOFOUTAGES

2008MONTHLY 2009MONTHLY

COMBINED 2008 & 2009 132KV OUTAGESCHART 16 (TABLES 5A & 5B)

0

500

1000

1500

2000

2500

3000

3500

4000

4500


MONTHS

CUMULATIVEFREQUE

NCYOFOUTAGES

2008MONTHLY 2009MONTHLY


33/104

0

20

40

60

80

100

120

140

160


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


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

28


34/104

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.

29


35/104

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


(c) Osogbo Region

(Osogbo, Ayede, OmotoshoArea Transmission) 2358247.56MWH


(d) Port- Harcourt Region

(Alaoji Area Transmission) 1825474.76MWHInjection points (9.80%)

(e) Kaduna Region

30

contd. pg. 35


36/104


37/104


38/104

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

33


39/104

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


Thousands

MONTHS

ENERGY

GENERATED(MWH)

HYDRO ENERGY GENERATED (MWH)

THERMAL ENERGY GENERATED (MWH)

TOTAL ENERGY GENERATED (MWH)

34


40/104

(Kaduna and Kano Area Transmission) 1755436.59MWH


(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


(h) Benin Region

(Benin & Ajaokuta Area Transmission) 2100718.42MWH


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,

35


41/104

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.


42/104

ENERGY GENERATED IN HYDRO P.S. (MWH)JANUARY-DECEMBER 2009 CHART 21 (SEE TABLE 7)

0

50

100

150

200

250

300

350


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


Thousan

ds

MONTHS

ENERGYGENERATED(MWH)

EGBIN SAPELE DELTA AFAM OMOTOSHO GEREGU OLORUNSOGO

37


43/104

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

38


44/104

AVAILABLE ENERGY FOR SALES

JANUARY - DECEMBER 2009 CHART 23 (SEE TABLE 10)

200

700

1200

1700

2200

2700


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


Thousands

MONTHS

ENERGYAVAILABLEFOR

S

ALES(MWH)

2008 2009

39


45/104

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

40


46/104

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


47/104

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

42


48/104

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


49/104

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


50/104

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


MONTHS

ENERGYAVAILABLEFORSALES(M

WH)

LAGOS ENUGU OSOGBO

P/HARCOURT KADUNA SHIRORO

BAUCHI BENIN

45


51/104

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


52/104

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


53/104

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


54/104

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


55/104

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

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