MAINLAND OCCIDENTAL MINDORO POWER SUMMIT
www.omeco.com.ph
Our Vision A fully energized Occidental Mindoro through a self-reliant competitive electric
cooperative where the people in rural areas as well as those in urban
communities enjoy reliable and sustainable electric services provided for and by concerned member-consumers and
competent, honest, enthusiastic officers and employees.
CONNECTIONS
CUSTOMERS PER TYPE @ MUNICIPALITY AS OF NOV 2009
Municipality Res Com PB SL IND LLoad Total
San Jose 16,820 1,731 347 40 31 12 18,981
Magsaysay 3,144 105 90 2 1 0 3,342
Rizal 3,524 94 89 3 0 0 3,710
Calintaan 2,586 104 75 3 0 0 2,768
Sablayan 8,829 483 237 20 1 5 9,575
Mamburao 5,523 356 111 31 12 2 6,035
Abra 2,102 67 57 15 0 0 2,241
Sta. Cruz 3,247 63 62 2 2 0 3,376
Total 45,775 3,003 1,068 116 47 19 50,028
PAG-ASA SUBSTATION
MAPSA AREA OFFICE
SABLAYAN AREA OFFICE
MAIN OFFICE
MAJOR OFFICES
PAG-ASA SUBSTATION
MAPSA AREA OFFICE
SABLAYAN AREA OFFICE
MAIN OFFICE
ROAD KILOMETERS BETWEEN MUNICIPALITIES
San Jose – Magsaysay 15 km
San Jose – Rizal 19 km
Rizal – Calintaan 16 km
Calintaan – Sablayan 51 km
Sablayan - Sta. Cruz 61 km
Sta. Cruz – Mamburao 25 km
Mamburao - Abra de Ilog 31 km
Mamburao – Paluan 32 km
DISTANCE BETWEEN TOWNS
PAG-ASA SUBSTATION
MAPSA AREA OFFICE
SABLAYAN AREA OFFICE
MAIN OFFICE
PAG-ASA SERVICE CENTER
2LINEMEN CREW
ABRA DE ILOG SERVICE CENTER3 LINEMEN CREW
STA CRUZ SERVICE CENTER
4 LINEMEN CREW
LIGAYA SERVICE CENTER
2LINEMEN CREW
MAGSAYSAY SERVICE CENTER2 LINEMEN CREW
ROAD KILOMETERS BETWEEN MUNICIPALITIES
San Jose – Magsaysay 15 km
San Jose – Rizal 19 km
Rizal – Calintaan 16 km
Calintaan – Sablayan 51 km
Sablayan - Sta. Cruz 61 km
Sta. Cruz – Mamburao 25 km
Mamburao - Abra de Ilog 31 km
Mamburao – Paluan 32 km
CALINTAAN SERVICE CENTER3 LINEMEN CREW
SERVICE CENTERS
PAG-ASA SUBSTATION
MAPSA AREA OFFICE
SABLAYAN AREA OFFICE
MAIN OFFICE
TOTAL CIRCUIT KILOMETERS OF LINE AS OF NOV 2009
2,422.278
LINEAL KILOMETERS PER PERMANENT EMPLOYEE AS
OF NOV 20094.38 : 1
LINEAL KILOMETER PER TOTAL EMPLOYEE AS OF
NOV 20094.38 : 1
CIRCUIT KILOMETERS OF LINE
HISTORICAL & FORECAST DATA
MARKET SHARE (KWH SALES)
ABRA1496835.6
3%
MAMBURAO8621170.8
17%STA CRUZ2108226
4%
SABLAYAN6005461.62
12%CALINTAAN1505325.7
3%RIZAL
1691150.13%
SAN JOSE26986576.11
54%
MAGSAYSAY1809209.7
4%
PER MUNICIPALITY ALL CUSTOMERS 2009
MARKET SHARE (KWH SALES)
ABRA1131260.6
4%
MAMBURAO4475033.1
17%
STA CRUZ1603320
6%
SABLAYAN3503942.8
13%
CALINTAAN1126839.7
4%RIZAL
1383950.45%
SAN JOSE12377397
46%
MAGSAYSAY1162699.2
4%
PER MUNICIPALITY RESIDENTIAL 2009
MARKET SHARE (KWH SALES)
PER MUNICIPALITY COMMERCIAL 2009
ABRA194105
2% MAMBURAO1300190
12%STA CRUZ
2200772%
SABLAYAN1049126.42
10%
CALINTAAN1126839.7
11%
RIZAL144014.7
1%
SAN JOSE6219236.8
59%
MAGSAYSAY312503.8
3%
MARKET SHARE
PER MUNICIPALITY INDUSTRIAL 2009
ABRA33347
1%MAMBURAO
118183240%
STA CRUZ73025
2%
SABLAYAN38930
1%
SAN JOSE1480853.5
50%
MAGSAYSAY182920
6%
MARKET SHARE (KWH SALES)
PER MUNICIPALITY PUBLIC BUILDINGS 2009
ABRA125223
4%
MAMBURAO849031.7
24%
STA CRUZ162905
5%SABLAYAN520079.1
15%
CALINTAAN158795
5%
RIZAL158795
5%
SAN JOSE1364849.61
39%
MAGSAYSAY136875.7
4%
MARKET SHARE (KWH SALES)
PER MUNICIPALITY STREET LIGHTS 2009
ABRA12900
4%
MAMBURAO4081412%
STA CRUZ4889915%
SABLAYAN80407.3
24%CALINTAAN17636
5%
RIZAL43901%
SAN JOSE112196.2
34%
MAGSAYSAY14211
4%
MARKET SHARE (KWH SALES)
ENERGY SALES (MWH)
YEAR 2003 2004 2005 2006 2007 2008 2009
SALES 31,389 36,233 38,199 39,711 42,665 45,748 50,224
YEAR 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019
SALES 53,359 57,390 61,931 67,283 73,329 80,097 87,673 96,168 105,717 116,461
MWH SALES
2003 2004 2005 2006 2007 2008 2009 -
10,000
20,000
30,000
40,000
50,000
60,000
HISTORICAL SALES
YEAR
MW
H
ENERGY SALES (MWH)
ENERGY SALES (MWH)
2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 -
20,000
40,000
60,000
80,000
100,000
120,000
140,000
PROJECTED SALES
YEAR
MW
H
DEMAND (MW)
2003 2004 2005 2006 2007 2008 2009
PEAK 8.61
9.03
9.52
9.91
10.63
11.40
12.53
AVERAGE 5.12 5.92 6.24 6.49 6.96 7.46 8.20
MINIMUM 4.12 4.92 5.24 5.49 5.96 6.39 7.43
2010 2011 2012 2013 2014 2015 2016 2017 2018 2019
PEAK 15.09 16.06 17.07 18.34 19.12 20.47 21.56 22.39 23.76 25.16
AVERAGE 10.42 11.25 12.14 13.24 14.01 15.22 16.27 17.15 18.47 19.86
MINIMUM 7.90 8.41 8.94 9.60 10.01 10.71 11.28 11.72 12.44 13.50
SYSTEM DEMAND
DEMAND (MW)
2003 2004 2005 2006 2007 2008 2009 -
2.00
4.00
6.00
8.00
10.00
12.00
14.00
HISTORICAL SYSTEM DEMAND
PEAK
AVERAGE
MINIMUMYEAR
MW
DEMAND (MW)
1 2 3 4 5 6 7 8 9 10 -
5.00
10.00
15.00
20.00
25.00
30.00
PROJECTED SYSTEM DEMAND
PEAK
AVERAGE
MINIMUMYEAR
MW
CONCERNS
NET LOSS
2008 2009
P50.8 M P37.8 M
NET LOSS
HIGH SYSTEM LOSS
2003 2004 2005 2006 2007 2008 2009
0.00%
5.00%
10.00%
15.00%
20.00%
25.00%
15.20% 16.20%18.33% 19.87%
17.28%15.98% 15.77%
YEAR
PERC
ENT
SYSTEM LOSS CHART2003-2009
HIGH SYSTEM LOSS
2009 2010
14 % 13 %
System loss cap
HIGH SYSTEM LOSS
2010 2011 2012 2013 2014 2014 2015 2016 2017 2018 2019MWh Sales 53,359 57,390 61,931 67,283 73,329 80,097 87,673 96,168 105,717 116,461 128,574 MWh Coop Cons 368 375 383 390 397 405 412 420 427 435 442 MWh Accounted 53,727 57,765 62,314 67,673 73,726 80,502 88,085 96,588 106,144 116,896 129,016 System Loss by Linear GrowthMWh Loss 9,275 9,628 10,016 10,444 10,916 11,427 11,978 12,572 13,215 13,909 14,661 MWh Purchased 63,003 67,393 72,329 78,117 84,642 91,930 100,062 109,160 119,359 130,805 43,677 Projected System Loss (Trend) 14.72% 14.29% 13.85% 13.37% 12.90% 12.43% 11.97% 11.52% 11.07% 10.63% 10.20%
System Loss Cap PrescriptionCap 13.00% 13.00% 13.00% 13.00% 13.00% 13.00% 13.00% 13.00% 13.00% 13.00% 13.00%SL in Excess of Cap 1.72% 1.29% 0.85% 0.37% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00%Passed-on SL 13.00% 13.00% 13.00% 13.00% 12.90% 12.43% 11.97% 11.52% 11.07% 10.63% 10.20%Energy Loss Passed-on/Subsidized (MWh)Customers 8,190 9,435 10,126 10,936 11,850 12,870 14,009 15,282 16,710 18,313 14,661 OMECO 1,085 867 613 289 - - - - - - - Rate Impact of System Loss (Linear Trend on Losses)Customers (P/KWH) 0.9697 1.0386 1.0329 1.0268 1.0209 1.0151 1.0094 1.0039 0.9985 0.9933 0.7203 OMECO (P/KWh) 0.0453 0.0338 0.0223 0.0097 - - - - - - - Supply Cost with VAT 6.3172 (No Capex Recovery Adjustment Considered) DU Tarriff with VAT 2.6320
RATE IMPACT OF SYSTEM LOSSBASE FORECAST without LOSS REDUCTION PROJECTS
HIGH SYSTEM LOSS
2010 2011 2012 2013 2014 2014 2015 2016 2017 2018 2019 MWh Sales 53,359 57,390 61,931 67,283 73,329 80,097 87,673 96,168 105,717 116,461 128,574 MWh Coop Cons 368 375 383 390 397 405 412 420 427 435 442 MWh Accounted 53,727 57,765 62,314 67,673 73,726 80,502 88,085 96,588 106,144 116,896 129,016 System Loss by Linear GrowthMWh Loss 8,701 8,668 8,318 8,174 6,934 7,476 8,075 8,739 9,478 10,299 11,214 MWh Purchased 62,428 66,433 70,632 75,848 80,660 87,978 96,159 105,327 115,622 127,195 140,230 Projected System Loss (Target) 13.94% 13.05% 11.78% 10.78% 8.60% 8.50% 8.40% 8.30% 8.20% 8.10% 8.00%
System Loss Cap PrescriptionCap 13.00% 13.00% 13.00% 13.00% 13.00% 13.00% 13.00% 13.00% 13.00% 13.00% 13.00%SL in Excess of Cap 0.94% 0.05% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00%Passed-on SL 13.00% 13.00% 11.78% 10.78% 8.60% 8.50% 8.40% 8.30% 8.20% 8.10% 8.00%Energy Loss Passed-on/Subsidized (MWh)Customers 8,116 9,301 9,888 10,619 11,292 12,317 13,462 14,746 16,187 17,807 11,214
OMECO 585 31 - - - - - -
-
-
-
Rate Impact of System Loss (With Target Loss Reduction)Customers (P/KWH) 0.9608 1.0238 1.0087 0.9970 0.9728 0.9714 0.9700 0.9686 0.9673 0.9659 0.5510
OMECO (P/KWh) 0.0247 0.0012 - - - - - -
-
-
-
Supply Cost with VAT 6.3172 (No Capex Recovery Adjustment Considered) DU Tarriff with VAT 2.6320
RATE IMPACT OF SYSTEM LOSSBASE FORECAST with LOSS REDUCTION PROJECTS
HIGH SYSTEM LOSSCOMPARATIVE RATE IMPACT
2010 2011 2012 2013 2014 2014 2015 2016 2017 2018 2019 System Loss
System Loss (Trend without Projects - Base Forecast) 14.63% 14.20% 13.76% 13.29% 12.82% 12.36% 11.90% 11.45% 11.01% 10.57% 10.15%System Loss (Trend without SLR - System Forecast) 14.72% 14.29% 13.85% 13.37% 12.90% 12.43% 11.97% 11.52% 11.07% 10.63% 10.20%System Loss (Targetted SLR – System Forecast) 13.94% 13.05% 11.78% 10.78% 8.60% 8.50% 8.40% 8.30% 8.20% 8.10% 8.00%
Rate Impact to Customers (Trend without Projects - Base Forecast)
0.96893
1.03812
1.03282
1.02707
1.02143
1.01594
1.01055
1.00530
1.00018
0.99520
0.71787
(Trend without SLR - System Forecast)
0.96966
1.03856
1.03291
1.02682
1.02086
1.01506
1.00940
1.00390
0.99854
0.99335
0.72034
(Targetted SLR - System Forecast) 0.96082
1.02377
1.00868
0.99699
0.97284
0.97143
0.97003
0.96865
0.96728
0.96593
0.55100
Rate Impact to OMECO (Trend without Projects - Base Forecast) 0.04297 0.03156 0.02009 0.00761 -
-
-
-
-
-
-
(Trend without SLR - System Forecast) 0.04533 0.03384 0.02230 0.00972 -
-
-
-
-
-
-
(Targetted SLR - System Forecast) 0.02467
0.00124
-
-
-
-
-
-
-
-
-
Supply Cost with VAT 6.3172 (No Capex Recovery Adjustment Considered) DU Tarriff with VAT 2.6320
INDEBTEDNESS TO NPC-SPUG
P252,725,968.81 As of December 2009
INDEBTEDNESS TO NPC-SPUG
2008 2009POWER ACCOUNTS & E-VAT 273,074,966.78 353,163,647.92 RESTRUCTURED ACCOUNT 22,015,922.31 29,354,563.08
TOTAL 295,090,889.09 382,518,211.00 INTEREST (NEA-STCF) 1,195,690.45 POWER RELATED PAYMENTS 295,090,889.09 383,713,901.45
PAYMENTS TO NPC SPUG
INDEBTEDNESS TO NPC-SPUG
NEEDS SPECIAL RESTRUCTURINGIN ORDER TO SUSTAIN.
POWER OUTAGES
SYSTEM OUTAGES (SUPPLY AND LINES)
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec HOURS DAYS
2003 13 39 679 74 117 201 62 71 72 224 29 20 1,602 67
2004 34 42 84 43 67 62 44 63 48 44 39 45 616 26
2005 65 34 48 43 48 37 87 61 19 9 16 30 497 21
2006 23 26 6 9 19 10 46 19 29 40 14 19 261 11
2007 22 21 27 21 21 24 40 27 25 42 35 12 317 13
2008 24 42 15 14 30 24 21 26 24 22 18 18 277 12
2009 7 12 10 25 30 39 43 107 72 44 29 37 455 19
POWER OUTAGES
SYSTEM OUTAGES (OMECO LINES)
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec HOURS DAYS
2003 2 10 634 8 4 24 13 5 13 16 4 6 738 31
2004 7 2 13 4 16 23 8 23 4 6 7 8 120 5
2005 7 1 14 3 11 10 14 5 8 3 1 3 81 3
2006 5 9 4 3 15 6 23 8 2 12 3 7 96 4
2007 4 2 4 8 9 7 13 8 12 14 13 2 98 4
2008 9 8 4 10 15 9 12 11 8 9 11 7 114 5
2009 7 2 4 12 11 22 25 12 16 7 10 7 135 6
POWER OUTAGES
SYSTEM OUTAGES (SUPPLY)
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec HOURS DAYS
2003 11 29 45 66 113 178 49 66 59 208 26 14 864 36
2004 27 40 71 39 51 40 35 40 45 38 33 37 496 21
2005 58 33 34 40 37 27 72 55 11 7 15 27 416 17
2006 17 17 3 6 4 5 23 12 26 28 11 12 164 7
2007 17 19 23 13 12 17 28 19 13 28 22 9 219 9
2008 15 34 11 4 14 14 9 14 16 13 7 11 163 7
2009 0 10 6 13 19 17 18 95 57 37 19 30 321 13
POWER OUTAGES
POWER OUTAGES
1:00
AM
2:00
AM
3:00
AM
4:00
AM
5:00
AM
6:00
AM
7:00
AM
8:00
AM
9:00
AM
10:0
0 AM
11:0
0 AM
12:0
0 NN
1:00
PM
2:00
PM
3:00
PM
4:00
PM
5:00
PM
6:00
PM
7:00
PM
8:00
PM
9:00
PM
10:0
0 PM
11:0
0 PM
12:0
0 M
N4.0
6.0
8.0
10.0
12.0
14.0
16.0
8.78.2
8.0
7.98.4
8.5 9.1
10.7
12.7
11.8
13.1
11.0
10.8
14.2
11.6
10.9
9.8
11.611.6
15.1
14.3
11.5
10.8
8.7
PROJECTED LOAD CURVESUPPLY/DEMAND STATUS
2010
SYSTEM LOADRATED SUPPLYDEPENDABLE SUPPLYSUPPLY(WORST CASE)
MW
POWER OUTAGES
POWER OUTAGES
• LOAD SHIFTING• INCREASE IN LINE LOSSES• POWER QUALITY PROBLEMS• IMPAIRS LOCAL ECONOMY• INCONVENIENCE TO PEOPLE• FINANCIAL LOSSES TO OMECO
LET US SOLVE OUR PROBLEM!
OMECO5MVA PAG-ASA SUBSTATION
29.7 Km NPC 69 KV TX LINEUSED AS OMECO’S 13.2 KV TIE LINE
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