MAINLAND OCCIDENTAL MINDORO POWER SUMMIT

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


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


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


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


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


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%


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%


PER MUNICIPALITY STREET LIGHTS 2009

ABRA12900

4%

MAMBURAO4081412%

STA CRUZ4889915%

SABLAYAN80407.3

24%CALINTAAN17636

5%

RIZAL43901%

SAN JOSE112196.2

34%

MAGSAYSAY14211

4%

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


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


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)


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)


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

MAINLAND OCCIDENTAL MINDORO POWER SUMMIT

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