statistical report 2009

Statistical Report

ContentsAES Values

Letter from the President

AES Dominicana

AES Dominicana Background

Profile of the Group

Power Generation Units

Fuel Reception Facilities

New Line of Business

Energy Balance

Capacity Balance

Non-Regulated Users

Fuel Inventory and Consumptions

Fuel Imports

Operative Indexes

Relevant Events

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Wholesale Electric Market

Annual Statistics

Anexos

Brief History of the Dominican Electric Sector

Generation Park Installed Capacity

Electric Power Transmission

Electricity Distribution

Energy Balance

Capacity Balance

Maximum Demand

Energy Supply by Fuel Type

International Fuel Prices

Energy Spot Price

Capacity Spot Price and Connection Right

Frequency Regulation Service

Non-Regulated Users Market

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Installed Capacity

Energy Balance

Maximum Demand

Energy Spot Price

International Fuel Price

Power Outages

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using mineral coal, both fuels have become the most competitive and resourceful of all those used in the local market.

As you may realize, AES Dominicana has been able to convert opportunities into success stories, exercising a leadership role in the electric power sector and becoming an engine for development of the Dominican Republic.

Marco De la Rosa President of AES Dominicana

AES Dominicana is pleased to present its 2009 Statistical Report, which includes: operations performance, business model by line of business and electric market composition.

The name of AES Dominicana encompasses the companies of Dominican Power Partners (DPP), AES ANDRES, both 100% owned by AES Corporation, and ITABO S.A., of which AES owns 50% of its equity.

Year 2009 can be defined as a year of continued excellence for AES Dominicana as new lines of business were created and further improvements were obtained.

During 2009, AES Dominicana maintained a leadership position in the national electricity industry with an average contribution of 33% of all energy that was demanded in the National Interconnected Electric System (SENI).

AES Dominicana has been a key component to the diversification of fuel type composition of electric sector in the Dominican Republic, after introducing natural gas for the generation of electricity and reestablishing, in an efficient manner, the production of electricity

de AES Dominicana

Letter from the President

Marco De la Rosa

Put Safety First: We will always put safety first for our people, contractors and communities.

Act with Integrity: We are honest, trustworthy and dependable. Integrity is at the core of all we do, how we conduct ourselves and how we interact with one another and all of our stakeholders.

Honor Commitments: We honor our commitments to our customers, teammates, communities, owners, suppliers and partners, and we want our businesses on the whole, to make a positive contribution to society.

Strive for Excellence: We strive to be the best in all that we do and to perform at world-class levels.

Have Fun through Work: We work because work can be fun, fulfilling and exciting. We enjoy our work and appreciate the fun of being part of a team that is making a difference.

Values• Put Safety First

• Act with Integrity

• Honor Commitments

• Strive for Excellence

• Have Fun through Work

La Gente AES

AESWhat

mean?does this

2009 Statistical Report AES Dominicana

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DominicanaAES 2009


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AES Dominicana Background AES invested for the first time in the Dominican Republic in 1997 when, within the context of a merger that involved the Destec companies and NGC, AES decided to acquire from NGC international assets owned by Destec, which included DPP and other related companies. DPP is the owner of the generation units of Los Mina V and Los Mina VI, two open cycle gas turbines of 118 MW each, which are described below in this report.

From May of 1996 until August of 2001, DPP operated under the Independent Private Producer scheme, selling all of its production to La Corporación Dominicana de Electricidad (CDE). Then, after an agreement between DPP and CDE, the contract between both parties was cancelled and a new electricity sale arrangement was established between DPP and EDEESTE, which included a back-up contract with the CDE.

In the year 2000 AES confirmed its commitment to the long term development of the Dominican Republic by constructing AES ANDRES. The project included a combined cycle with 319 MW, a liquefied natural gas terminal and a gas pipeline towards the DPP power station.

In December of 2000, AES takes another important step, when it acquires the assets of GENER, obtaining a participation of 25% in the ITABO power plant.

Since May 1st, 2003, Dominican Power Partners operates to supply its electricity sale contract with EDEESTE, selling its excess generation and buying what it needs on the spot market.

In the year 2003, AES ANDRES began its operations becoming the most efficient power station of Latin America and representing a jump towards sustainable development for the country using clean energy. At this time, it improved the strategic position of the country that formarly depended 90% on petroleum derivatives to supply its electricity needs.

In the year 2006, AES Dominicana acquires another 25% of the ITABO equity, which were property of El Paso. Then AES becomes the owner of the 50% of ITABO’s equity and therefore takes the control of the operative and administrative areas.

Profile of the Group

AES began operations in the Dominican Republic with the intent to provide value to the national energy market and contribute to the development of the communities where it serves.

Today, AES Dominicana is positioned as the principal investment group in the Dominican electric sector, with modern facilities for energy production and with the most competitive fuels for power generation in the national electric sector.

AES Dominicana has two deep-sea port infrastructures; Itabo’s International Pier, to download the coal used for electricity production and AES Andres’ International Pier, to download the liquefied natural gas used for electricity production. It also has, in its AES Andres’ facilities, the first terminal intended for the distribution of liquefied natural gas in specialized trucks.

As a business group, AES Dominicana combines a global perspective with deep local knowledge and a relentless commitment to operational excellence. There has been a consistent pattern of improvement year after year in generation and efficiency. AES serves as a model to the rest of the players in the electric sector, by displaying the best practices of corporate governance within the electric industry in the Dominican Republic.

AES Dominicana supports the growth of its business by standing upon a strong foundation composed of its code of conduct, corporate social responsibility, environmental care and its people, which are the most valuable resources.


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Power Generations UnitsTechnical details of AES Dominicana power generation units.

AES ANDRES

Installed Capacity: 319 MWTechnology: Combined CyclePrimary Fuel: Liquid Natural Gas (LNG)Commercial Operation Date: December 2nd, 2003Gas Turbine Manufacturer: MitsubishiGas Turbine Capacity: 198 MWGas Turnibe Speed: 3,600 rpmInlet Heat Recovery Steam Generator Temperature: 610 ºCGas Turbine Generator Manufacturer: MitsubishiGas Turbine Generator Nominal Capacity: 218.5 MVAGas Turbine Generator Nominal Voltage: 18 kVGas Turbine Generator Cooling System: AirSteam Turbine Manufacturer: HitachiSteam Turbine Capacity: 121 MWSteam Turbine Speed: 3,600 rpmSteam Pressure: 124 kg/cm² Steam Temperature: 568 ºCSteam Turbine Generator Manufacturer: SiemensSteam Turbine Generator Nominal Capacity: 134 MVASteam Turbine Generator Nominal Voltage: 13.8 kVSteam Turbine Generator Cooling System: AirAdvantages: Low Environmental Impact and More Energetic Efficiency

DPP

Installed Capacity: 2 x 118 MWTechnology: Gas TurbinePrimary Fuel: Liquid Natural Gas (LNG)Commercial Operation Date: 19 de mayo del 1996Manufacturer: WestinghouseTurbine Speed: 3,600 rpmTurbine Stages: Four (4)Compressor Stages: Fourteen (14)Outlet Gas Temperature: 630 ºCGenerator Nominal Capacity: 2 x 142 MVAGenerator Nominal Voltage: 13.8 kVGenerator Speed: 3,600 rpmGenerator Cooling System: AirAdvantages: Fast Manufacture and Installation and Low Environmental Impact

ITABO 2

Installed Capacity: 132 MWTechnology: Steam TurbinePrimary Fuel: Mineral CoalSecundary Fuel: Fuel Oil 6Tertiary Fuel: Fuel Oil 2Commercial Operation Date: Mayo 10th, 1988Turbine Manufacturer: General ElectricTurbine Speed: 3,600 rpmSteam Pressure: 146 kg/cm²Steam Temperature: 540 ºCGenerator Manufacturer: General ElectricGenerator Nominal Capacity: 155.3 MVAGenerator Nominal Voltage: 13.8 kVGenerator Cooling System: HydrogenAdvantages: Provides Economic Base Electricity Generation

ITABO 1

Installed Capacity: 128 MWTechnology: Steam TurbinePrimary Fuel: Mineral CoalSecundary Fuel: Fuel Oil 6Tertiary Fuel: Fuel Oil 2Commercial Operation Date: July 17th, 1984Turbine Manufacturer: Brown Bovery CompanyTurbine Speed: 3,600 rpmSteam Pressure: 141 kg/cm²Steam Temperature: 535 ºCGenerator Manufacturer: Foster WheelerGenerator Nominal Capacity: 150.6 MVAGenerator Nominal Voltage: 13.8 kVGenerator Cooling System: HydrogenAdvantages: Provides Economic Base Electricity Generation


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Fuel Reception Facilities

AES ANDRES’s International Pier

AES ANDRES Power Station is located at the Boca Chica community, just fifteen (15) minutes from Santo Domingo. The power station has a pier and a terminal for liquid natural gas unloading and it also has the capacity to receive other liquid fuels.

Inside the facility, the terminal has an unloading ship system that consists of three (3) arms with an unloading capacity of 10,000 m3 per hour. It also has a double wall cryogenic tank with the capacity to store 160,000 m3. In addition the terminal has a regasification system with the capacity to convert 250,000 MMBTU per day. Finally, it has a boiloff security system to handle the gases of the cryogenic tank in order to keep the atmospheric pressure

During 2009, the terminal was handed 943,024 m3 of liquid natural gas at -161 ºC, from seven (7) ships.

AES ITABO International Pier

The AES ITABO International Pier is located at the power station’s coastal area. It is an open sea port with the capacity to receive auto-discharging vessels with the intention to open the scope for the coal supply agreements.

The pier has a length of 535 meters, providing the facility to load and to unload any other solid products. In addition, it has a mooring system with six (6) dukes, as well as a signal system for the approaching vessels.

Principal Characteristics:

Fourteen (14) meters depth: Allows vessels like Handymax (45,000 mt) and Panamax (65,000 mt).Auto-discharging vessels required.Discharge Capacity of 1,200 metric tones per hour.

During 2009, the AES ITABO International Pier unloaded 678,633 metric tones of mineral coal from fourteen (14) ships vessels.

AES ANDRES – DPP Natural Gas Pipeline

In addition to the LNG Terminal, a natural gas pipeline was built in order to supply natural gas to the DPP power units, improving its efficiency and competitiveness.

Technical Details:Length: 34 kmPipe Diameter: 12 inchesMax Pressure: 100 barAverage Pressure: 50 barControl Valves Station: Eight (8)


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New Lines of BusinessRegasified Natural Gas Sale Business

In the year 2005, AES ANDRES signed its first natural gas supply agreement with LINEA CLAVE. This local distribution company is responsible for distributing regasified natural gas by trucks. The natural gas supply to LINEA CLAVE initiated in 2007.

LINEA CLAVE has its station next to AES ANDRES power station. There, the natural gas is compressed to high pressures and stored in special containers. Then, it is transported by trucks to its final destination.

In October of 2008, AES ANDRES signed another natural gas supply agreement with SOLUCIONES EN GAS NATURAL (SGN). This local distribution company will be responsible for distrubuting compressed natural gas to the industrial market and transportation market. The agreement will allow more clients to benefit from the advantages of natural gas.

Liquid Natural Gas Sale Business

AES Dominicana continues developing the natural gas market. In 2009 it introduced the first station for liquid natural gas distribution, contemplating the importance of extending the technological options necessary to be able to expand the natural gas market and to improve the industries, commerce and transport competitiveness.

The loading station is located inside the AES ANDRES LNG terminal at Punta Caucedo and includes two areas for the reception of trucks, each with a filling valve. In this way the station is available to fill two trucks simultaneously. In addition, the space is designed for the construction of two additional reception areas in the future.

AES Dominicana successfuly signed contracts with various fuel distribution companies. These companies will be responsible for the natural gas distribution throughout the country: SOLUCIONES DE GAS NATURAL, PLATER GAS, PROPAGAS and TROPIGAS.

Energy BalanceThe following table shows the energy balance of the AES Dominicana generation companies during 2009.

2009 AES ENERGY BALANCE[GWh]

AES ANDRES JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC 2009

CONTRACT SALES

EDENORTE - 13.44 14.88 14.40 14.88 14.40 14.88 14.88 14.40 22.32 21.60 22.32 182

EDEESTE 25.63 22.78 25.28 25.65 26.57 28.16 29.14 28.04 26.71 28.19 25.81 28.43 320

DPP 41.88 38.15 45.27 36.69 76.97 85.65 89.72 78.85 109.80 93.43 84.63 68.99 850

ITABO - - - - 0.71 17.73 9.34 22.97 1.72 8.40 4.16 2.64 68

UNR 17.95 17.18 18.87 17.99 18.95 21.17 23.84 23.53 32.22 34.15 32.06 29.02 287

CONTRACT PURCHASES

ITABO - - - 3.70 18.52 0.57 1.47 0.69 1.52 3.58 5.86 3.14 39

SPOT SALES/(SPOT PURCHASES) (5.75) 13.77 37.79 0.07 (67.46) 10.29 15.88 22.84 (3.24) 4.85 9.60 22.95 62

ANDRES PRODUCTION 79.72 105.32 142.10 91.09 52.11 176.84 181.34 190.42 180.09 187.76 172.00 171.22 1,730

AES ITABO

CONTRACT SALES

EDESUR 58.83 52.24 56.24 57.56 59.34 61.17 64.20 64.53 62.50 65.70 60.11 63.39 726

EDENORTE 41.76 36.55 39.64 41.48 42.29 43.79 47.57 47.32 45.29 48.46 43.30 45.58 523

EDEESTE 24.59 21.64 24.00 24.44 25.31 26.92 27.83 28.04 26.71 28.19 25.81 28.43 312

CDEEE 35.14 41.76 43.10 41.18 42.60 39.79 13.74 5.52 38.49 38.49 35.81 40.32 416

ANDRES - - - 3.70 18.52 0.57 1.47 0.69 1.52 3.58 5.86 3.14 39

UNR 0.21 0.23 0.32 0.31 0.25 0.25 0.25 0.27 0.20 0.25 0.19 0.17 3

CONTRACT PURCHASES

ANDRES - - - - 0.71 17.73 9.34 22.97 1.72 8.40 4.16 2.64 68

MONTERIO - - - - - - - - 4.31 3.04 1.80 1.59 11

FALCONDO 35.14 41.76 43.10 41.18 42.60 39.79 13.74 5.52 38.49 38.49 35.81 40.32 416

SPOT SALES/(SPOT PURCHASES) 18.44 (25.33) (28.90) (0.86) (3.10) (18.60) (6.34) (2.21) (2.31) 7.34 11.85 11.68 (38)

ITABO PRODUCTION 143.84 85.33 91.30 126.64 141.90 96.36 125.63 115.66 127.88 142.07 141.15 148.17 1,486

DPP

CONTRACT SALES

EDEESTE 103.27 90.88 100.81 102.65 106.30 113.05 116.89 117.74 112.18 118.38 108.39 119.42 1,310

CONTRACT PURCHASES

ANDRES 41.88 38.15 45.27 36.69 76.97 85.65 89.72 78.85 109.80 93.43 84.63 68.99 850

SPOT SALES/(SPOT PURCHASES) 1.28 0.37 (0.00) 0.92 0.85 0.02 0.00 (0.00) 0.01 0.05 (0.00) (0.00) 3

DPP PRODUCTION 62.67 53.10 55.54 66.88 30.18 27.42 27.16 38.89 2.40 25.00 23.76 50.43 463

In the previous table we highlighted some important lines: contract sales, contract purchases, spot sales, spot purchases and energy supply. The next lines will focus on the contract market between AES Dominicana and some agents of the Wholesale Electricity Market:

AES Andres

Since February, a new short term contract sale with EDENORTE was signed, where the energy is sold in two hourly blocks. Also since April, a backup contract with AES ITABO took effect in order to reduce the exposure in the spot market.

AES ITABO

During 2009, the contract sale with CDEEE continued in order to increase the energy supply of the country’s north zone through FALCONDO’s units, whose injections and retirements are administrated by AES ITABO in the market. Also, as indicated before, since April, a backup contract with AES ANDRES took effect in order to reduce the exposure in the spot market. Lastly, in September a contract purchase with MONTERIO was signed.

DPP

During 2009, the contract sale with EDEESTE continued along with a back up contract purchase with AES ANDRES.

Capacity BalanceThe following table shows the capacity balance of AES Dominicana’s power stations during 2009.

2009 AES CAPACITY BALANCE[MW]

JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC 2009

AES ANDRES

Contract Capacity Sales 269.38 269.98 269.01 269.88 270.78 275.11 276.33 277.75 289.15 289.13 288.77 290.04 278

Firm Capacity 209.98 202.70 214.78 204.03 201.73 207.01 220.61 201.72 204.74 204.99 209.38 193.20 206

Contract Capacity Purchase - - - - - - - - - - - - -

Spot Sale / (Spot Purchase) (59.40) (67.28) (54.23) (65.85) (69.05) (68.10) (55.72) (76.03) (84.41) (84.15) (79.40) (96.84) (72)

AES ITABO


Firm Capacity 225.82 225.64 225.03 225.82 225.82 225.82 225.81 225.82 225.82 225.82 225.82 223.02 226

Contract Capacity Purchase - - - - - - - - - - - - -

Spot Sale / (Spot Purchase) (24.18) (24.36) (24.97) (24.18) (24.18) (24.18) (24.19) (24.18) (24.18) (24.18) (24.18) (26.98) (24)

DPP


Firm Capacity 16.75 16.16 17.12 16.25 15.35 15.71 16.77 15.35 15.59 15.61 15.97 14.70 16

Contract Capacity Purchase (193.25) (193.84) (192.88) (193.75) (194.65) (194.29) (193.23) (194.65) (194.41) (194.39) (194.03) (195.30) (194)

Spot Sale / (Spot Purchase) - - - - - - - - - - - - -

Non-Regulated UsersAES ANDRES continues strengthening its position in the Non-Regulated Users Market, with the support of a strategy based on competitive prices and quality services as aggregate value to the offering. AES Andres’s portfolio of energy distribution has been further diversified and collections of this segment has met target.

During 2009, four new contracts were signed with non-regulated users; INCA KM 22, INCA LA ISABELA, SAN ISIDRO FREE ZONE and LATIN AMERICA FREE ZONE (PIISA), which represent a monthly consumption of approximately 13 GWh. In addition, there were renewed contract sales with BARCELO CAPELLA, TERMO ENVASES, MOLINOS DEL OZAMA, JARAGUA and AERODOM.

The following table shows AES ANDRES’s and AES ITABO’s non-regulated users’s consumption during 2009.

2009 AES NON-REGULATED USERS DEMAND(GWh)

JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC

AES ANDRES

AERODOM 2.30 2.16 2.37 2.59 2.75 2.84 3.10 3.12 3.04 3.15 2.82 2.90

ALDOM 0.47 0.36 0.58 0.47 0.43 0.43 0.55 0.44 0.46 0.50 0.35 0.37

CARREFOUR 0.69 0.60 0.64 0.68 0.73 0.72 0.79 0.78 0.77 0.80 0.74 0.79

HAMACA 0.67 0.62 0.62 0.67 0.73 0.79 0.93 0.87 0.77 0.83 0.82 0.76

CAPELLA 0.53 0.46 0.49 0.54 0.60 0.62 0.68 0.69 0.67 0.69 0.61 0.67

COSTA CARIBE 0.54 0.48 0.48 0.50 0.51 0.56 0.63 0.66 0.53 0.61 0.57 0.54

LISTIN DIARIO 0.53 0.50 0.56 0.51 0.57 0.59 0.63 0.62 0.56 0.61 0.57 0.58

MALLA 1.06 1.04 1.17 1.02 1.25 1.04 0.96 1.08 0.85 1.09 1.16 0.98

MOLINOS 1.07 1.06 1.10 1.01 1.03 1.17 1.02 0.91 0.71 1.05 1.05 0.79

MC CHARLES 0.73 0.64 0.68 0.73 0.75 0.78 0.80 0.73 0.76 0.77 0.75 0.78

PLASTIFAR 1.25 1.33 1.52 1.35 1.42 1.46 1.56 1.46 1.47 1.55 1.51 1.45

JARAGUA 0.89 0.76 0.86 0.86 0.86 0.91 0.96 0.97 0.96 1.04 0.98 0.93

TERMO ENVASES 1.22 1.33 1.31 1.10 1.26 1.30 1.34 1.36 1.38 1.61 1.41 1.30

ZF CAUCEDO 2.07 1.65 1.85 1.75 1.75 1.88 1.81 1.71 1.49 1.41 1.54 1.37

LADOM 0.45 0.46 0.51 0.51 0.50 0.40 0.49 0.45 0.53 0.56 0.54 0.50

MULTIFORM 0.19 0.26 0.30 0.26 0.27 0.29 0.30 0.28 0.30 0.38 0.40 0.25

ZF LAS AMERICAS 3.29 3.46 3.82 3.42 3.52 3.80 4.19 4.09 4.19 4.32 4.07 3.55

INCA kM 22 1.57 1.55 1.77 2.02 2.44 2.39 2.09

INCA LA ISABELA 1.55 1.53 1.38 1.53 1.33 1.20

ZF SAN ISIDRO 2.86 2.98 2.70 2.25

PIISA 6.52 6.24 5.75 4.97

TOTAL 17.95 17.18 18.87 17.99 18.95 21.17 23.84 23.53 32.22 34.15 32.06 29.02

AES ITABO

QUITPE 0.19 0.18 0.23 0.30 0.25 0.24 0.15 0.14 0.23 0.24 0.21 0.23

TOTAL 0.19 0.18 0.23 0.30 0.25 0.24 0.15 0.14 0.23 0.24 0.21 0.23

The next chart shows the average demand of AES’s non-regulated users during 2009.


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5.87 3.81

2.76

2.70

1.98

1.69

1.44

1.42

1.33

1.06

1.00

0.91

0.76

0.74

0.73

0.61

0.57

0.55

0.49

0.45

0.29

0.22

0.00 1.00 2.00 3.00 4.00 5.00 6.00

PIISA

ZF LAS AMERICAS

AERODOM

ZF SAN ISIDRO

INCA kM 22

ZF CAUCEDO

PLASTIFAR

INCA LA ISABELA

TERMO ENVASES

MALLA

MOLINOS

JARAGUA

HAMACA

MC CHARLES

CARREFOUR

CAPELLA

LISTIN DIARIO

COSTA CARIBE

LADOM

ALDOM

MULTIFORM

QUITPE

GWh

AVERAGE DEMAND 2009 AES NRU

Fuel Inventory and Consumptions

Natural GasDuring 2009, AES ANDRES and DPP had a total natural gas consumption of 19,236,618 MMBTU and 20,935,129 MMBTU were purchaced through a long term supply agreement.

The next table shows the inventory evolution details during 2009.

2009 NATURAL GAS INVENTORY AND CONSUMPTIONS[MMBTU]

AES ANDRES Y DPP JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC TotalBeginning Inventory 676,550 2,166,000 564,588 1,755,012 3,232,785 2,362,153 591,025 1,799,763 2,809,690 1,336,402 2,465,715 759,874

Purchases 2,973,408 - 3,010,798 3,030,396 - - 2,990,750 2,998,381 - 2,942,221 - 2,989,175 20,935,129

ANDRES Consumptions 673,013 906,764 1,104,538 702,236 426,456 1,368,510 1,410,286 1,477,654 1,395,741 1,464,078 1,364,424 1,322,181 13,615,881

DPP Consumptions 764,507 640,165 660,982 798,629 400,585 349,904 325,975 462,492 29,790 298,133 285,877 603,699 5,620,737

BOG Consumptions 7,435 16,202 18,941 17,322 9,440 23,189 14,814 16,238 13,170 13,266 18,080 15,959 184,054

Third Partie Sales 39,003 38,282 35,913 34,437 34,151 29,525 30,937 32,069 34,587 37,431 37,461 39,082 422,878

Final Inventory 2,166,000 564,588 1,755,012 3,232,785 2,362,153 591,025 1,799,763 2,809,690 1,336,402 2,465,715 759,874 1,768,128

CoalDuring 2009, AES ITABO, with two steam units, had a total consumption of 640,390 metric tones of coal and 19,160 metric tones of petcoke. Also, through different providers, 678,633 metric tones of coal were purchaced.

The following table shows the inventory evolution details during 2009.

2009 COAL INVENTORY AND CONSUMPTIONS[metric ton]

AES ITABO JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC Total

Beginning Inventory 49,784 20,419 3,747 76,481 82,215 81,315 39,069 32,421 30,507 93,061 89,559 84,176

Purchases 40,376 22,426 116,359 60,608 55,830 - 47,295 52,103 117,950 56,499 56,487 52,700 678,633

Consumptions 67,514 36,471 43,625 53,861 56,730 39,699 53,943 51,130 53,549 60,001 60,530 63,337 640,390

Third Partie Sales - - - - - - - - - - - - -

Losses 2,227 2,627 - 1,014 - 2,547 - 2,888 1,847 - 1,339 - 14,489

Final Inventory 20,419 3,747 76,481 82,215 81,315 39,069 32,421 30,507 93,061 89,559 84,176 73,538

Subtotal Consumption 67,514 36,471 43,625 53,861 56,730 39,699 53,943 51,130 53,549 60,001 60,530 63,337 640,390

2009 PETCOKE INVENTORY AND CONSUMPTIONS[metric ton]

AES ITABO JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC Total

Beginning Inventory 32,204 32,204 32,204 32,204 62,503 54,984 51,677 50,308 49,763 46,290 46,046 46,046

Purchases - - - 33,002 - - - - - - - - 33,002

Consumptions - - - 2,702 7,519 3,307 1,369 545 3,473 244 - - 19,160

Third Partie Sales - - - - - - - - - - - - -

Losses - - - - - - - - - - - - -

Final Inventory 32,204 32,204 32,204 62,503 54,984 51,677 50,308 49,763 46,290 46,046 46,046 46,046

Subtotal Consumption - - - 2,702 7,519 3,307 1,369 545 3,473 244 - - 19,160

Total Consumption 67,514 36,471 43,625 56,563 64,249 43,006 55,312 51,674 57,022 60,245 60,530 63,337 659,549

Fuel Imports

Natural Gas During 2009, the AES ANDRES LNG Terminal received seven vessels with 20,935,129 MMBTU equivalents to 943,024 m3. The next table shows the details.

2009 AES ANDRES NATURAL GAS IMPORTS

# Date Supplier Vessel MMBTU M3

1 January 5, 2009 BPGM BRITISH RUBY 2,973,408 133,937

2 March 3, 2009 BPGM BRITISH MERCHANT 3,010,798 135,622

3 April 27, 2009 BPGM BRITISH DIAMOND 3,030,396 136,504

4 July 6, 2009 BPGM BRITISH MERCHANT 2,990,750 134,718

5 August 18, 2009 BPGM BRITISH DIAMOND 2,998,381 135,062

6 October 10, 2009 BPGM BRITISH TRADER 2,942,221 132,532

7 December 9, 2009 BPGM BRITISH INNOVATOR 2,989,175 134,648

20,935,129 943,024


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CoalDuring 2009, the International Port of AES ITABO received fourteen (14) vessels with 678,633 metric tones of coal. The next table shows the details.

2009 AES ITABO COAL IMPORTS

# Date Supplier Vessel Loading Port Metric Ton MMBTU

1 January 17, 2009 CARBONES DEL CARIBE BALLANGEN ITABO 40,376 1,069,975

2 February 2, 2009 OXBOW UBC SALVADOR ITABO 22,426 594,292

3 March 1, 2009 CARBONES DEL CARIBE BALDER ITABO 47,262 1,252,433

4 March 4, 2009 MG TRADING HERON ITABO 28,553 756,654

5 March 20, 2009 COAL MARKETING COMPANY BALLANGEN ITABO 40,544 1,074,416

6 April 22, 2009 COAL MARKETING COMPANY CSL ARGOSY ITABO 60,608 1,606,112

7 May 14, 2009 COAL MARKETING COMPANY CSL METIS ITABO 55,830 1,479,495

8 July 2, 2009 GLENCORE INTERNATIONAL ALICE OLDENDORF ITABO 47,295 1,253,322

9 August 12, 2009 SHELTON TRADING CSL SPIRIT ITABO 52,103 1,380,736

10 September 12, 2009 BULKTRADING BERNHARD OLDENDORFF ITABO 60,683 1,608,092

11 September 29, 2009 GLENCORE INTERNATIONAL JOHANNA OLDENDORFF ITABO 57,268 1,517,592

12 October 7, 2009 EDF TRADING CSL ATLAS ITABO 56,499 1,497,222

13 November 15, 2009 EDF TRADING CSL METIS ITABO 56,487 1,496,897

14 December 31, 2009 GLENCORE INTERNATIONAL SHEILA ANN ITABO 52,700 1,396,537

678,633 17,983,774

2009 AES ITABO PETCOKE IMPORTS

# Date Supplier Vessel Loading Port Metric Ton MMBTU

1 April 19, 2009 KOMSA MUSKETEER HAINA 33,002 874,540

Operative Indexes

The following table shows the operative indexes and operation rates of power units applied to AES ANDRES, AES ITABO and DPP.

2009 AES OPERATIVE INDEXES


EAF [%]

ANDRES 41.3% 56.7% 66.5% 45.5% 34.7% 99.1% 94.9% 99.1% 99.2% 99.7% 93.7% 95.6% 77.2%

ITABO 1 93.5% 37.3% 37.2% 90.2% 90.7% 86.1% 82.6% 72.6% 82.8% 91.2% 94.6% 97.3% 79.7%

ITABO 2 93.8% 92.6% 96.8% 84.6% 87.4% 45.3% 89.3% 77.1% 84.4% 80.8% 85.4% 87.2% 83.7%

LOS MINA 5 83.2% 91.9% 100.0% 90.3% 88.5% 100.0% 100.0% 100.0% 0.0% 0.0% 0.0% 0.0% 62.8%

LOS MINA 6 99.9% 94.8% 95.1% 97.7% 98.9% 100.0% 93.0% 100.0% 100.0% 99.8% 98.4% 93.5% 97.6%

EFOR [%]

ANDRES 58.7% 34.8% 33.5% 31.9% 3.5% 0.9% 1.1% 0.9% 0.0% 0.3% 3.2% 0.1% 14.1%

ITABO 1 5.1% 14.7% 1.0% 9.8% 8.8% 6.4% 14.3% 11.6% 12.1% 4.0% 0.8% 1.8% 7.5%

ITABO 2 0.8% 0.6% 3.2% 8.7% 12.6% 24.1% 9.4% 8.0% 10.5% 7.2% 5.3% 4.3% 7.9%

LOS MINA 5 27.7% 16.1% 0.0% 18.7% 21.3% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 7.0%

LOS MINA 6 0.1% 1.8% 0.0% 0.0% 2.8% 0.0% 8.8% 0.0% 0.0% 0.6% 3.9% 0.0% 1.5%

HEAT RATE [BTU/kWh]

ANDRES 8,369 8,603 7,773 7,684 8,135 7,738 7,773 7,760 7,750 7,778 7,932 7,718 7,918

ITABO 1 10,809 11,502 11,683 11,048 11,373 11,056 11,287 10,839 10,516 10,638 10,703 11,210 11,055

ITABO 2 11,135 11,549 12,398 11,874 11,630 12,546 11,541 11,435 11,526 11,391 11,218 11,237 11,623

LOS MINA 5 14,490 14,175 14,095 14,297 14,264

LOS MINA 6 11,694 11,831 11,894 11,738 11,921 12,446 11,985 11,524 12,038 11,839 12,072 12,064 11,920

As can be seen above, 2009 was a year full of challenges for the operating area due to some externalities such as AES ANDRES transformer failure, affecting the power plant operations during the first five months of the year, as well as the quality of coal received at AES ITABO in the first half of the year, while negotiating the supply contract with Glencore.

Relevant Events

During 2009, two black outs have occurred on the Interconected National Electric System: the first one was on Wednesday 15th of July at 11:34 and the second one was on Wednesday 2nd of September at 18:03.

The following table shows the programmed major maintenances applied to AES Dominicana power units during 2009.

2009 AES RELEVANT EVENTS

Unit Description From To Hours

Itabo 1 Programmed Maintenance 15-Feb-2009 00:43 14-Mar-2009 14:20 662

Andres Programmed Maintenance 21-Apr-2009 00:37 19-May-2009 06:34 678

Los Mina 5 Programmed Maintenance 01-Sep-2009 00:00 01-Jan-2010 00:00 2,928

Itabo 2 Programmed Maintenance 20-Jun-2009 01:58 30-Jun-2009 19:14 257

ElectricalWholesale

Market


26 27

Brief History of the Dominican Electric SectorIn 1997 the capitalization process began. This process was instituted due to serious problems in the electrical sector caused by a deficit of the generation, poor quality service and a lack of capital investment for the electrical sector expansion.

The capitalization process was formalized on June 24, 1997, with the publication of the State Companies Reform Law. Before this process, generation, transmission and distribution assets in the Dominican Republic were owned by CDE, who by law was the only entity authorized to operate in the electricity sector.

In the mid 90s, CDE subscribed several power purchased agreements with independent power producers; increasing the systems installed capacity with private capital. During this period, the sector was regulated by a series of administrative resolutions issued by the Industry and Commerce Ministry.

Through the different stages of the capitalization process, the assets held by CDE were divided into eight state-owned companies: CDEEE, a parent holding company, three distribution companies: EDENORTE, EDESUR and EDEESTE, three generation companies: HAINA, ITABO and HIDRO and the power transmission company.

In 1999, the three distribution companies and the two thermal generation companies were capitalized through the sale of 50% of the stocks to private investors. The Dominican State remained with 49% of the stocks and the last 1% was sold to the employees of these companies.

In July 2001, the Electricity General Law was issued, establishing the institutions of the sector and the rules under which it will operate. In July 2002, the Electricity General Law Rulebook was issued, completing the electrical sector new legislation.

During 2007, the Electricity General Law and its Rulebook were modified by the law number 186-07. The new law has as a goal to criminalize the electrical fraud and establish other measures to obtain the electrical sector’s financial viability.

Generation Park Installed CapacityThe generation park of the system is mainly componed of 82.5% thermoelectric units while the other 17.5% is componed by hydroelectric units.

The following chart shows the installed capacity by technology and fuel type.

Steam Turbine20.3%

Gas Turbine11.2%

Diesel Engine24.2%

Combined Cycle26.9%

Hydro Turbine17.5%

INSTALLED CAPACITY BY TECHNOLOGYDecember 2009

The following table shows the installed capacity by company and technology.

INSTALLED CAPACITY BY FUEL TYPE December 2009

Natural Gas18.5%

Water17.5%

Fuel Oil 639.1%

Fuel Oil 214.4%

Coal10.5%

2009 SYSTEM INSTALLED CAPACITY

TOTAL

GENERATION COMPANY STEAMTURBINE

GASTURBINE

COMBINEDCYCLE

DIESELENGINE

HYDRO [MW] [%]

AES ANDRES 319.00 319.00 10.8%

AES ITABO 260.00 260.00 8.8%

DPP 236.00 236.00 8.0%

HAINA 346.16 100.00 102.00 548.16 18.5%

HYDRO 523.10 523.10 17.6%

METALDOM 42.00 42.00 1.4%

SEABOARD 116.30 116.30 3.9%

GPLV 194.50 194.50 6.6%

MONTERIO 100.10 100.10 3.4%

CEPP 76.86 76.86 2.6%

LAESA 31.60 31.60 1.1%

INDEPENDENT POWER PRODUCERS [IPP'S]

SAN FELIPE 185.00 185.00 6.2%

CESPM 300.00 300.00 10.1%

MAXON 30.00 30.00 1.0%

CDEEE 1.90 1.90 0.1%

TOTAL [MW] 606.16 336.00 804.00 695.26 523.10 2,964.52 100.0%

TOTAL [MW] 866.2 572.0 1123.0 723.2 523.1 2,992.50 100.0%


28 29

SYSTEM INSTALLED CAPACITYTHERMOELECTRIC UNITS

COMPANIES FUEL TECHNOLOGY CAPACITY [MW]

AES DOMINICANA

ANDRES NATURAL GAS Combined Cycle 319.0

ITABO I COAL Steam Turbine 128.0

ITABO II COAL Steam Turbine 132.0

NATURAL GAS Gas Turbine 118.0

LOS MINA VI NATURAL GAS Gas Turbine 118.0

SubTotal 815.0

HAINA

HAINA I FUEL 6 Steam Turbine 54.0

HAINA II FUEL 6 Steam Turbine 54.0

HAINA IV FUEL 6 Steam Turbine 84.9

SAN PEDRO VAPOR FUEL 6 Steam Turbine 33.0

PUERTO PLATA I FUEL 6 Steam Turbine 27.6

PUERTO PLATA II FUEL 6 Steam Turbine 39.0

HAINA TG FUEL 2 Gas Turbine 100.0

BARAHONA CARBON COAL Steam Turbine 53.6

SULTANA DEL ESTE FUEL 6 Diesel Engine 102.0

SubTotal 548.2

GENERADORA PALAMARA - LA VEGA

PALAMARA FUEL 6 Diesel Engine 107.0

LA VEGA FUEL 6 Diesel Engine 87.5

SubTotal 194.5

CDEEE

SAN FELIPE FUEL 6 Combined Cycle 185.0

CESPM I FUEL 2 Combined Cycle 100.0

CESPM II FUEL 2 Combined Cycle 100.0

CESPM III FUEL 2 Combined Cycle 100.0

MAXON FUEL 2 Diesel Engine 30.0

RIO SAN JUAN FUEL 2 Diesel Engine 1.9

SubTotal 516.9

SEABOARD

ESTRELLA DEL NORTE FUEL 6 Diesel Engine 43.0

ESTRELLA DEL MAR FUEL 6 Diesel Engine 73.3

SubTotal 116.3

CEPP

CEPP I FUEL 6 Diesel Engine 18.7

CEPP II FUEL 6 58.1

SubTotal 76.8

MONTE RIO POWER

MONTE RIO FUEL 6 Diesel Engine 100.1

SubTotal 100.1

METALDOM

METALDOM FUEL 6 42.0

SubTotal 42.0

LAESA

PIMENTEL FUEL 6 Diesel Engine 31.6

SubTotal 59.6

TOTAL THERMO 2,441.36

HYDROELECTRIC UNITS

RESERVOIR HYDRO FUEL TECHNOLOGY CAPACITY [MW]

TAVERA I WATER Hydro Turbine 48.0

TAVERA II WATER Hydro Turbine 48.0

JIGUEY I WATER Hydro Turbine 49.0

JIGUEY II WATER Hydro Turbine 49.0

AGUACATE I WATER Hydro Turbine 26.0

AGUACATE II WATER Hydro Turbine 26.0

VALDESIA I WATER Hydro Turbine 27.0

VALDESIA II WATER Hydro Turbine 27.0

RIO BLANCO I WATER Hydro Turbine 12.5

RIO BLANCO II WATER Hydro Turbine 12.5

MONCION I WATER Hydro Turbine 26.0

MONCION II WATER Hydro Turbine 26.0

RINCON WATER Hydro Turbine 10.1

PINALITO I WATER Hydro Turbine 25.0

WATER Hydro Turbine 25.0

SubTotal 437.1

NON-RESERVOIR HYDRO

LOPEZ ANGOSTURA WATER Hydro Turbine 18.4

CONTRA EMBALSE MONCION I WATER Hydro Turbine 1.6

CONTRA EMBALSE MONCION II WATER Hydro Turbine 1.6

BAIGUAQUE I WATER Hydro Turbine 0.6

BAIGUAQUE II WATER Hydro Turbine 0.6

HATILLO WATER Hydro Turbine 8.0

JIMENOA WATER Hydro Turbine 8.4

EL SALTO WATER Hydro Turbine 0.7

ANIANA VARGAS I WATER Hydro Turbine 0.3

ANIANA VARGAS II WATER Hydro Turbine 0.3

DOMINGO RODRIGUEZ I WATER Hydro Turbine 2.0

DOMINGO RODRIGUEZ II WATER Hydro Turbine 2.0

ROSA JULIA DE LA CRUZ WATER Hydro Turbine 0.9

NIZAO NAJAYO WATER Hydro Turbine 0.3

LOS ANONES WATER Hydro Turbine 0.1

SABANA YEGUA WATER Hydro Turbine 12.8

LAS DAMAS WATER Hydro Turbine 7.5

SABANETA WATER Hydro Turbine 6.3

LOS TOROS I WATER Hydro Turbine 4.9

LOS TOROS II WATER Hydro Turbine 4.9

MAGUEYAL I WATER Hydro Turbine 1.5

MAGUEYAL II WATER Hydro Turbine 1.5

LAS BARIAS WATER Hydro Turbine 0.8

SubTotal 86.0

TOTAL HYDRO 523.13

GRAND TOTAL 2,964.5


30 31

Electric Power TransmissionElectric power transmission or “high voltage electric transmission” is the bulk transfer of electrical energy, from generating power plants to substations located near the population centers. This is distinct from the local wiring between high voltage substations and customers, which is typically referred to as electricity distribution.

Transmission lines, when interconnected with each other, become high voltage transmission networks. Electricity is transmitted at high voltages (69 kV or above) to reduce the energy lost in long distance transmission.

A key limitation in the distribution of electricity is that, with minor exceptions, electrical energy cannot be stored, and therefore it must be generated as it is needed. A sophisticated system of control is therefore required to ensure electric generation very closely matches the demand. If supply and demand are not in balance, generation plants and transmission equipment can shut down which, in the worst cases, can lead to a major regional blackout. To reduce the risk of such failures, electric transmission networks are interconnected into regional, national or continental wide networks thereby providing multiple redundant alternate routes for power to flow should failures occur. Much analysis is done by transmission companies to determine the maximum reliable capacity of each line which is mostly less than its physical or thermal limit, to ensure spare capacity is available should there be any such failure in another part of the network.

The Dominican Electricity Transmission Company is a state enterprise whose main objective is to build, operate and maintain self-sustaining networks and substations of the National Interconnected Electric System to provide quality electric services at reasonable prices.

The Dominican system has four mayor zones: Santo Domingo Zone, Southern Zone, Northern Zone and Eastern Zone. The main substations of these mayor zones are: Palamara and Hainamosa for Santo Domingo Zone, Pizarrete for Southern Zone, Bonao II and Canabacoa for Northern Zone and finally San Pedro II for Eastern Zone.

The Dominican Electricity Transmission Company continues progressing in its construction of a new transmission line of 345 kV. This proyect includes four interconnected substations located at Julio Sauri, Bonao, El Naranjo and Navarrete.

Electricity DistributionElectricity distribution is the final stage in the delivery of electricity to end users. A distribution system’s network carries electricity from the transmission system and delivers it to consumers. Typically, the network would include medium-voltage (less than 69 kV) power lines, electrical substations and pole-mounted transformers, low-voltage distribution wiring and sometimes electricity meters.

The actual distribution system begins as the primary circuit leaves the sub-station and ends as the secondary service enters the customer’s meter socket. A variety of methods, materials, and equipments are used among the various utility companies, but the end result is similar.

Distribution networks are typically of two types, radial or interconnected. A radial network leaves the station and passes through the network area with no normal connection to any other supply. This is typical of long rural lines with isolated load areas. An interconnected network is generally found in more urban areas and will have multiple connections to other points of supply. These points of connection are normally open but allow various configurations by the operating utility by closing and opening switches. Operation of these switches may be by remote control from a control center or by a lineman. The benefit of the interconnected model is that in the event of a fault or required maintenance a small area of the network can be isolated and the remainder kept on supply.

Within these networks there may be a mix of overhead line construction utilizing traditional utility poles and wires, as well as, underground construction with cables and indoor or cabinet substations. However, underground distribution is significantly more expensive than overhead construction. In part to reduce this cost, underground power lines are sometimes co-located with other utility lines in what are called Common Utility Ducts. Distribution feeders emanating from a substation are generally controlled by a circuit breaker which will open when a fault is detected. Automatic Circuit Reclosers may be installed to further segregate the feeder, thus, minimizing the impact of faults.

The Dominican Electricity Distribution has three companies:

Edesur Dominicana, S. A.Edenorte Dominicana, S. A.Empresa Distribuidora de Electricidad del Este, S. A.

Energy BalanceThe following table shows the monthly energy balance in 2009.

2009 SYSTEM ENERGY BALANCE[GWh]


AES ANDRES 79.7 105.3 142.1 91.1 52.1 176.8 181.3 190.4 180.1 187.8 172.0 171.2 1,730

AES ITABO 143.8 85.3 91.3 126.6 141.9 96.4 125.6 115.7 127.9 142.1 141.2 148.2 1,486

DPP 62.9 53.3 55.7 67.1 30.4 27.6 27.4 39.1 2.5 25.2 23.9 50.6 466

HIDRO 127.7 135.4 114.7 114.8 169.1 150.2 110.1 132.6 118.4 104.8 81.8 82.9 1,442

IPPs 91.3 60.6 60.5 89.2 115.9 101.0 156.5 127.1 104.0 118.8 91.9 136.3 1,253

HAINA 90.7 79.2 90.3 85.6 87.3 70.9 93.2 90.1 106.3 114.0 103.6 94.8 1,106

GPLV 87.4 75.3 91.5 92.8 82.6 98.1 99.4 106.2 102.5 103.3 95.6 84.1 1,119

SEABOARD 70.1 62.7 64.2 66.2 66.9 68.8 68.8 70.3 69.3 69.0 69.1 59.3 805

CEPP 22.7 25.7 29.9 22.7 23.5 21.7 27.1 27.7 24.2 16.9 27.1 26.4 296

MONTERIO 40.6 38.2 46.1 46.2 48.1 46.3 49.0 41.9 41.3 45.1 42.7 38.5 524

METALDOM 14.8 10.1 11.5 11.4 12.1 11.7 12.8 17.4 14.5 14.0 9.0 11.1 150

LAESA 18.6 14.3 26.1 26.4 32.5 34.3 37.8 39.2 38.2 39.5 38.3 37.3 383

FALCONDO 35.2 41.9 43.2 41.2 42.6 39.9 13.8 5.7 38.5 38.5 35.8 40.3 417

GENERATION 885.4 787.5 867.2 881.3 904.9 943.8 1,002.9 1,003.3 967.7 1,018.9 932.0 981.0 11,176

EDESUR 307.8 272.6 293.0 300.2 305.4 318.7 335.2 335.2 327.3 343.7 313.9 331.9 3,785

EDENORTE 249.8 218.7 237.1 248.1 253.0 261.9 284.6 283.1 270.9 289.9 259.0 272.7 3,129

EDEESTE 240.4 211.6 234.7 239.0 247.5 263.2 272.1 274.2 261.2 275.6 252.4 278.0 3,050

UNR's 70.6 68.7 81.9 74.2 82.9 79.7 89.6 88.8 81.1 86.1 83.7 77.6 965

OTHERS 2.9 2.4 2.7 3.0 0.4 0.2 0.2 0.5 2.4 2.2 2.3 2.5 22

DEMAND 871.6 773.9 849.4 864.4 889.2 923.7 981.7 981.7 942.9 997.5 911.2 962.7 10,950

LOSS 13.8 13.6 17.7 16.8 15.7 20.1 21.2 21.6 24.8 21.4 20.8 18.3 226

PERDIDAS 13.8 13.6 17.7 16.8 15.7 20.1 21.2 21.6 24.8 21.4 20.8 18.3 226

During 2009, the total net generation was 11,176 GWh. The companies with mayor contribution to the system were AES ANDRES with 16%, AES ITABO with 13%, HIDRO with 13%, IPP’s with 11%, HAINA with 10% and GPLV with 10%.


32 33

The next chart shows the energy contribution of all the system companies.

2009 SYSTEM ENERGY BALANCE

AES ANDRES 16%

AES ITABO 13%

DPP 4%

HIDRO 13%

IPPs 11%

HAINA 10%

GPLV 10%

SEABOARD 7%

CEPP 3%

MONTERIO 5%

METALDOM 1%

LAESA 3%

FALCONDO 4%

As shown above, AES Dominicana is the group with the highest contribution to the electrical market, reaching on 2009 a 33% of participation through the contributions of AES ANDRES, AES ITABO and DPP.

Capacity BalanceThe following table shows the final capacity values by power generation companies in 2009.

2009 FIRM CAPACITY BALANCE[MW]

JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC MW %

AES ANDRES 210.0 202.7 214.8 204.0 201.7 207.0 220.6 201.7 204.7 205.0 209.4 193.2 206.2 12.2%

AES ITABO 225.8 225.6 225.0 225.8 225.8 225.8 225.8 225.8 225.8 225.8 225.8 223.0 225.5 13.4%

DPP 16.8 16.2 17.1 16.3 15.4 15.7 16.8 15.4 15.6 15.6 16.0 14.7 15.9 0.9%

Total AES Dominicana 452.6 444.5 456.9 446.1 442.9 448.5 463.2 442.9 446.1 446.4 451.2 430.9 447.7 26.6%

HYDRO 321.4 337.9 300.0 321.1 323.1 319.5 287.7 316.5 309.4 308.7 308.9 344.5 316.6 18.8%

IPPs* 141.8 136.9 145.2 137.7 134.4 137.7 147.1 134.6 136.6 136.8 139.7 128.9 138.1 8.2%

HAINA 236.5 233.3 238.6 233.8 231.4 219.5 227.1 231.4 232.9 233.0 225.3 221.7 230.4 13.7%

GPLV 189.9 189.9 189.9 189.9 189.9 189.9 189.9 189.9 189.9 189.9 189.9 189.9 189.9 11.3%

SEABOARD 108.9 108.9 108.9 108.9 108.9 108.9 108.9 108.9 108.9 108.9 108.9 108.9 108.9 6.5%

CEPP 65.0 64.7 64.8 65.1 64.9 64.9 65.0 64.8 65.1 65.1 65.1 64.1 64.9 3.9%

MONTERIO 96.4 96.4 96.4 96.4 96.4 96.4 96.4 96.4 96.4 96.4 96.4 96.4 96.4 5.7%

METALDOM 40.5 40.5 40.5 40.5 40.5 40.5 40.5 40.5 40.5 40.5 40.5 40.5 40.5 2.4%

LAESA 30.7 30.7 42.7 44.4 51.3 58.0 58.0 58.0 57.9 58.1 58.1 58.1 50.5 3.0%

Total 1,683.7 1,683.7 1,683.8 1,683.8 1,683.8 1,683.8 1,683.8 1,683.7 1,683.7 1,683.9 1,683.9 1,684.0 1,683.8 100.0%

* SAN FELIPE and CESPM

The companies that contributed the most capacity to the system during 2009 was HIDRO with 19%, HAINA with 14%, AES ITABO with 13%, AES ANDRES with 12%, and finally GPLV with 11%.

2009 SYSTEM ENERGY BALANCE

HIDRO16.3%

ITABO12.7%

DPP 0.9%

ANDRES12.9%

IPPs* 8.2%

HAINA17.3%

GPLV 10.2%

SEABOARD5.9%

CEPP 3.9%

MONTERIO 5.2%

METALDOM 2.2%

LAESA 1.7%

Maximum DemandThe system’s maximum demand is the highest power consumed by the distribution companies in a specific moment of the year. Generally it happens during the system peak hours. Maximum demand is data used on the capacity recalculation, because the system remunerates only the maximum capacity effectively recorded as demanded during the year.

The following table shows the power production and power consumptions during the monthly maximum demand hour.

DEMANDA MAXIMA MENSUAL 2009[MW]

Month JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC

Day / Hour D07 H20 D03 H21 D02 H20 D22 H20 D29 H21 D05 H21 D30 H21 D26 H21 D30 H22 D12 H20 D13 H20 D03 H20

GENERATION

GROSS GENERATION 1,575 1,604 1,564 1,652 1,683 1,645 1,674 1,726 1,743 1,712 1,698 1,702

NET GENERATION sub-transmission voltage 1,524 1,553 1,521 1,599 1,629 1,593 1,620 1,667 1,689 1,656 1,643 1,644

NET GENERATION transmission high-voltage 1,520 1,546 1,512 1,595 1,624 1,588 1,614 1,661 1,685 1,652 1,639 1,640

DISTRIBUTION DEMAND

EDEESTE 453 450 397 432 459 463 450 456 461 493 467 455

EDENORTE 456 421 423 430 429 429 426 473 477 468 462 484

EDESUR 498 524 509 579 556 539 558 581 588 545 546 531

OTHER DEMAND

NRU 99 119 120 125 114 115 125 122 100 113 118 124

GENERATION UNITS 7 9 7 11 6 8 9 10 7 9 9 10

Pérdidas [MW] 8 24 56 18 62 33 45 19 51 23 36 37

Pérdidas [%] 0.52% 1.55% 3.67% 1.15% 3.80% 2.08% 2.78% 1.16% 3.02% 1.41% 2.20% 2.23%

In 2009, the maximum demand occurred on September 30th at 22:00 hours. The total gross power production was 1,743 MW and the total power consumption was 1,634 MW. 93% was consumed by the distribution companies and 6% was consumed by the non-regulated users.


34 35

International Fuel PricesThe prices of Fuel Oil 6 and Fuel Oil 2 correspond to the Platts reference prices in the US Gulf Coast Port. For Mineral Coal, the price is FOB Puerto Bolívar, for a heat rate of 11,300 Btu/pound. The Natural Gas prices are referred to the monthly average of the front month future NYMEX (Henry Hub) contract.

The following table shows the monthly average price for each fuel, expressed in US$/MMBtu.

2009 INTERNATIONAL FUEL PRICES(US$/MMBTU)


COAL 2.91 2.62 2.14 2.21 2.08 2.13 2.16 2.15 1.98 2.09 2.06 2.16

LNG 5.90 5.20 4.41 4.04 3.60 3.88 3.94 3.57 3.37 3.28 4.76 4.60

FO6 6.14 6.45 5.97 6.80 8.29 9.55 9.50 10.51 10.17 10.65 11.32 10.96

FO2 10.09 8.87 8.87 9.59 10.52 12.57 11.68 13.38 12.43 13.84 14.21 14.06

Energy Supply by Fuel TypeThe fuels that supplied the most energy to the system in 2009 were Fuel Oil 6, supplying 46%, Natural Gas supplying 20% and finally Coal supplying 16%.

ENERGY SUPPLY BY FUEL TYPE2009

Fuel Oil 6 47%

Fuel Oil 2 5%

Coal 16%

Natural Gas 19%

Water 13%

The following chart shows the evolution of fuel price in the International market during 2009.

0

2

4

6

8

10

12

14

16

US$

/MM

BTU


2009 INTERNATIONAL FUEL PRICESCOAL LNG

FUEL OIL 6 FUEL OIL 2

Energy Spot PriceThe energy spot price is the variable cost needed to produce an additional unit of energy, considering the system demand and the available installed capacity.

The following chart shows the evolution of the average energy spot price and the maximum energy spot price during 2009.


2009 ENERGY SPOT PRICEMAX

AVG

0

50

100

150

200

US$

/MW

h

The next table shows the monthly average energy spot price and the maximum energy spot price during 2009.

2009 ENERGY SPOT PRICE[US$/MWh]

JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC AVERAGE

AVG 80 87 86 89 99 110 132 131 146 145 150 139 116

MAX 86 101 105 100 110 128 143 143 155 151 157 165 129


36 37

Capacity Spot Price and Connection RightThe capacity spot price is defined by a formula with the cost to install an open cycle gas turbine with 50 MW and the O&M costs.

The next chart shows the evolution of the capacity spot price and the connection right during 2009.

2009 CAPACITY SPOT PRICE AND CONNECTION RIGHT[US/kW-mes]

JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC Promedio

Capacity Spot Price 7.77 7.78 7.83 7.83 7.86 7.92 7.96 7.95 7.97 7.97 7.98 7.99 7.90

Connection Right 3.14 2.74 3.14 3.26 3.34 3.53 3.43 3.31 3.56 3.13 2.91 3.23 3.23

The annual average capacity spot price was 7.9 US$/ kW-month. The following table shows the monthly values.


CAPACITY SPOT PRICE2009 CAPACITY SPOT PRICE AND CONNECTION RIGHTCONNECTION RIGHT

0

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US$

/kW

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Frequency Regulation ServiceThe AES power generation units play an important role in the frequency regulation service of the system. The following chart shows the margins contributed by each company that participates in this market.


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40

AES ANDRES DPP HIDRO SAN FELIPE FALCON HAINA

GPLV SEABOARD METALDOM MONTERIO 3% Demanda

FREQUENCY PRIMARY REGULATION SERVICE 2009 CONTRIBUTION RESERVE

[GWh]

AES Dominicana, through AES ANDRES, AES ITABO including FALCONDO and DPP, was the Group who had more contributions to the Primary Frequency Regulation, with an important 46% of the reserve margins, maintaining the quality and reliability of the electric supply.

During 2009 AES ANDRES and DPP contributed 51% and 9% respectively to the Secondary Frequency Regulation Service. The hydroelectric power generators contributed 39% of the margin. As we can see in some months the 3% established in the regulation was not reached, as the minimum that the system should have in order to operate with security, facing the planned demand variations.

0

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AES ANDRES HIDRO DPP

FREQUENCY SECONDARY REGULATION SERVICE 2009 CONTRIBUTION RESERVE

[GWh]


3% DEMAND

Non-Regulated Users MarketA non-regulated user (NRU) is a public service user that, before having the non- regulated user status, could have the electricity service through free contracts, with any electric supplier.

Article 108 of the General Electricity Law states that companies must apply to the Superintendency of Electricity to be authorized the non-regulated user status. Also, to obtain this status the public service users must meet the following power consumption:

2007 ≥ 1.4 MW 2008 ≥ 1.3 MW 2009 ≥ 1.2 MW 2010 ≥ 1.1 MW 2011 hereafter ≥ 1 MW

From 2000 to 2009, the Superintendency of Electricity has issued 107 authorizations to have the non-regulated user status. However, currently only 63 non-regulated users are using their authorizations in the wholesale electric market.


38 39

The next table shows the monthly energy supplied by each power generation company to their non-regulated users during 2009.

2009 NON-REGULATED USERS MARKET EVOLUTION(GWh)

JAN FEB MAR APR MAR JUN JUL AUG SEP OCT NOV DEC GWh %

AES ANDRES 17.95 17.18 18.87 17.99 18.95 21.17 23.84 23.53 32.22 34.15 32.06 29.02 286.94 29.9%

HAINA 2.36 2.11 2.24 2.23 2.35 2.44 - - - - - - 13.72 1.4%

AES ITABO 0.21 0.23 0.32 0.31 0.25 0.25 0.25 0.27 0.20 0.25 0.19 0.17 2.90 0.3%

MONTERIO 12.36 12.42 14.04 12.92 16.65 14.72 12.94 12.94 3.81 4.06 0.70 0.69 118.25 12.3%

SEABOARD 23.72 22.92 30.54 25.18 25.03 22.14 25.80 26.09 21.46 17.99 6.94 6.55 254.35 26.5%

EDESUR 7.99 7.79 8.86 8.74 9.72 9.62 9.44 9.31 8.10 8.89 8.67 8.35 105.49 11.0%

EDENORTE 5.45 5.39 6.31 6.10 6.36 6.55 6.81 6.60 6.16 6.80 6.32 5.47 74.32 7.7%

EDEESTE 1.04 1.14 1.28 1.20 1.26 1.25 6.04 5.67 4.78 8.31 18.88 18.93 69.79 7.3%

HIDRO - - - - - - 2.54 2.58 4.81 6.22 10.37 8.92 35.44 3.7%

TOTAL (GWh) 71.07 69.19 82.45 74.67 80.57 78.14 87.66 86.98 81.55 86.67 84.14 78.10 961.20 100.0%

As we can see the distribution companies had an important role in the non-regulated users market, remaining participation of the power generation companies.

The following chart shows the evolution of the non-regulated users market in 2009.

0%

10%

20%

30%

40%

50%

60%

70%

80%

90%

100%

AES ANDRES HAINA AES ITABO MONTE RIO SEABOARD EDESUR EDENORTE EDEESTE


2009 NON-REGULATED USERS MARKET EVOLUTION


40 41

AnnualStatistics


42 43

Installed CapacityThe next table shows the installed capacity evolution of the Dominican electric system between 2000 and 2009.

SYSTEM INSTALLED CAPACITYMW

COMPANY 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009

CAYMAN POWER 50.0

ENERGYCORP 103.5 103.5 103.5 103.5

AES ITABO 586.0 586.0 432.5 432.5 432.5 432.5 432.5 432.5 294.5 260.0

HAINA 456.7 663.3 665.1 665.1 665.1 663.4 663.4 663.4 548.2 548.2

HIDRO 402.0 411.8 463.8 463.8 463.8 463.8 469.3 469.3 472.3 523.1

DPP 236.0 236.0 236.0 236.0 236.0 236.0 236.0 236.0 236.0 236.0

GPLV 194.5 194.5 194.5 194.5 194.5 194.5 194.5 194.5 194.5 194.5

SAN FELIPE 175.0 175.0 185.0 185.0 185.0 185.0 185.0 185.0 185.0 185.0

METALDOM 42.0 42.0 42.0 42.0 42.0 42.0 42.0 42.0 42.0 42.0

SEABOARD 115.0 115.0 115.0 115.0 115.0 116.3 116.3 116.3 116.3 116.3

CEPP 76.9 76.9 76.9 76.9 76.9 76.9 76.9 76.9 76.9 76.9

MAXON 30.0 30.0 30.0 30.0 30.0 30.0 30.0 30.0 30.0 30.0

LAESA 79.9 79.9 83.9 87.7 87.7 31.6 31.6 31.6 59.6

CESPM 200.0 300.0 300.0 300.0 300.0 300.0 300.0 300.0 300.0

AES ANDRES 319.0 319.0 319.0 319.0 319.0 319.0 319.0

MONTERIO 100.0 100.0 100.0 100.0 100.0 100.0 100.0

RIO SAN JUAN 1.9 1.9

TOTAL [MW] 2,547.5 2,913.9 2,928.2 3,351.0 3,247.5 3,159.4 3,196.5 3,196.5 2,948.2 2,992.5

Energy BalanceThe following table shows the electric market agents annual energy balance between 2000 and 2009.

SYSTEM ENERGY BALANCE[GWh]

2000 2001 2002 2003 2004 2005 2006 2007 2008 2009

AES ITABO 2,214.2 1,867.3 1,271.1 1,509.4 955.3 1,048.2 1,574.8 1,630.3 1,735.5 1,903

HIDRO 915.8 736.3 876.5 1,189.5 1,571.6 1,883.0 1,745.4 1,465.5 1,369.4 1,442

IPPs 3,316.3 2,085.2 2,377.9 1,515.6 1,767.2 1,396.2 1,228.1 1,100.0 1,431.3 1,253

HAINA 1,973.8 2,241.2 2,985.0 2,196.1 1,331.2 1,774.4 1,757.1 1,662.6 1,334.8 1,106

GPLV 213.2 1,422.5 1,428.4 1,329.5 814.9 814.4 765.7 888.3 1,084.8 1,119

SEABOARD 415.9 885.0 890.3 864.5 699.0 792.8 777.6 777.3 796.3 805

CEPP 473.2 385.6 401.8 266.5 242.0 283.8 339.4 361.8 262.6 296

AES ANDRES 345.5 691.9 984.2 1,582.2 1,900.2 2,040.9 1,730

DPP 537.7 18.1 18.2 94.0 364.2 338.2 466

MONTERIO 594.9 461.3 555.6 495.7 448.2 526.1 524

METALDOM 138.5 160.7 184.4 193.1 188.7 150

LAESA 48.8 237.9 230.3 383

GENERATION 9,522.4 9,623.1 10,231.0 10,349.2 8,691.0 9,711.5 10,593.2 11,029.4 11,338.9 11,176.3

EDESUR 3,420.0 3,445.0 3,709.4 3,608.2 2,968.6 3,266.5 3,488.2 3,655.8 3,826.0 3,785

EDENORTE 2,863.8 2,788.8 3,022.9 3,087.3 2,497.2 2,725.4 2,967.4 3,098.6 3,240.2 3,129

EDEESTE 2,991.1 2,926.1 3,101.5 3,216.7 2,706.3 2,960.6 3,053.0 3,033.9 3,042.6 3,050

NRU 5.0 73.3 68.4 163.3 314.9 461.5 767.7 878.7 975.7 965

OTHERS 1.8 1.3 30.4 18.8 12.3 62.5 72.8 122.3 60.7 22

DEMAND 9,281.7 9,234.5 9,932.6 10,094.3 8,499.3 9,476.5 10,349.1 10,789.3 11,145.2 10,950

LOSS 240.7 388.6 298.4 254.9 191.7 235.0 244.1 240.1 193.7 226.3

Maximum DemandThe next table shows the maximum demand between 2001 and 2009.

YEARLY MAXIMUM DEMAND[MW]

YEARMONTH

2001 2002 2003 2004 2005 2006 2007 2008 2009

DECEMBER DECEMBER SEPTEMBER MAY JUNE MAY JULY MAY SEPTEMBER

Day / Hour D11 H21 D20 H20 D11 H21 D04 H21 D02 H22 D17 H21 D05 H21 D13 H21 D30 H22

GENERATION

GROSS GENERATION 1,601 1,634 1,737 1,690 1,691 1,766 1,772 1,925 1,743

NET GENERATION sub-transmission voltage 1,553 1,578 1,691 1,643 1,639 1,708 1,724 1,861 1,689

NET GENERATION transmission high-voltage 1,551 1,575 1,688 1,639 1,634 1,703 1,719 1,855 1,685

DEMAND

EDEESTE 465 473 519 481 463 466 454 502 461

EDENORTE 478 499 545 522 491 521 502 591 477

EDESUR 524 535 539 538 546 580 602 604 588

NON-REGULATED USERS 7 8 18 35 49 77 101 93 100

OTHERS 12 17 13 13 39 12 31 10 7

TOTAL RETIROS 1,487 1,532 1,634 1,589 1,586 1,656 1,690 1,799 1,634

Losses [MW] 64 43 54 50 48 47 29 56 51

Losses [%] 4.11% 2.71% 3.23% 3.06% 2.93% 2.74% 1.66% 3.02% 3.02%

Energy Spot PriceThe following table shows the energy spot price evolution between 2001 and 2009.

ENERGY SPOT PRICE[US$/MWh]


2001 47.79 53.22 50.71 51.67 53.41 65.76 72.07 74.52 79.83 60.37 51.35 45.58

2002 44.72 42.28 47.28 59.29 60.60 63.99 58.65 65.72 65.28 63.64 66.62 62.76

2003 69.89 73.08 69.41 61.49 58.90 60.82 77.46 70.63 77.90 73.71 59.01 68.07

2004 57.60 67.20 62.24 63.93 56.55 76.92 72.86 74.24 73.18 68.57 79.58 58.74

2005 55.76 66.89 59.77 70.43 70.58 72.05 75.88 85.91 87.08 92.54 95.24 77.25

2006 79.57 92.79 103.30 79.95 91.13 95.93 87.92 91.33 107.09 96.58 89.42 72.81

2007 71.01 76.72 81.93 83.19 97.55 99.02 111.59 114.39 107.12 116.65 120.19 115.32

2008 134.21 141.28 144.31 157.78 163.76 184.58 204.88 216.24 186.00 179.44 134.27 84.52

2009 79.51 86.56 86.48 88.88 99.15 110.05 132.04 131.23 146.33 144.58 150.03 138.79


44 45

ENERGY SPOT PRICE EVOLUTION

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50

100

150

200

250

Jan-01 J an-02 J an-03 Jan-04 Jan-05 J an-06 Jan-07 J an-08 Jan-09

US$

/MW

h

International Fuel PricesThe next chart shows the evolution of international fuel prices between 2004 and 2009.

INTERNATIONAL FUEL PRICE EVOLUTION

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04

Jan-

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07

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Jan-

09

USD

/MM

Btu

EVOLUCION PRECIOS INTERNACIONALES COMBUSTIBLES

FO2 FO6 LNG COAL

The following charts show the evolution of fuel prices by fuel type.

- 20

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100

120

140

160

180

Jan-04 Jan-05 Jan-06 Jan-07 Jan-08 Jan-09

US$

/BBL

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160

180

Jan-04 Jan-05 Jan-06 Jan-07 Jan-08 Jan-09

US$

/BBL

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16

Jan-04 Jan-05 J an-06 Jan-07 J an-08 Jan-09

US$

/MM

BTU

- 20 40 60 80

100 120 140 160 180

Jan-04 Jan-05 J an-06 Jan-07 J an-08 Jan-09

US$

/TM

INTERRUPCIONES TOTALES SENI 2000 - 2009

DAY DATE HOUR CAUSE

Wednesday 9-Feb-2000 16:47 Shortcircuit to 138 kV Itabo - Los Prados power line

Saturday 25-Mar-2000 19:19 Strain insulator failure to 138 kV Itabo - Palamara II power line

Sunday 13-Aug-2000 11:55 Low Frequency

Sunday 13-Aug-2000 19:22 Low Frequency

Friday 25-Aug-2000 13:35 High-voltage breakers trip to 138 kV Villa Duarte - Hainamosa II power line

Saturday 2-Sep-2000 15:50 Low Frequency

Monday 9-Oct-2000 7:01 Autotransformer trip at Villa Duarte Substation

Friday 8-Dec-2000 8:33 A conductor landing to 138 kV Itabo - Haina I power line

Saturday 2-Jun-2001 14:27 Low Frequency

Monday 4-Jun-2001 15:51 Failure at Palamara substation

Thursday 28-Jun-2001 15:53 Low Voltage

Thursday 28-Jun-2001 18:06 Low Frequency

Tuesday 6-Nov-2001 6:49 Low Frequency

Sunday 18-Nov-2001 16:37 Low Voltage

Thursday 22-Nov-2001 12:40 Low Frequency

Tuesday 27-Nov-2001 3:16 Low Frequency

Saturday 9-Mar-2002 20:06 Low Frequency

Tuesday 19-Mar-2002 11:49 Shortcircuit to 138 kV Los Mina - Hainamosa power line

Sunday 24-Mar-2002 1:46 Low Frequency

Friday 26-Jul-2002 12:38 Low Voltage

Saturday 4-Jan-2003 0:55 Distribution transformer failure at Villa Duarte substation

Wednesday 6-Aug-2003 3:20 Unknown

Saturday 27-Sep-2003 13:04 A damage to 138 kV Embajador - Los Prados power line

Saturday 11-Oct-2003 3:03 Low Frequency

Sunday 22-Feb-2004 3:40 A trip of 138 kV Villa Duarte - Timbeque II power line

Thursday 25-Mar-2004 14:05 Failure at Bonao II substation

Sunday 8-Aug-2004 14:40 High Frequency. Failure of the 69 kV San Francisco - Pimentel power line and 69 kV Hatillo - Pimentel power line

Monday 9-Aug-2004 14:11 Low Frequency

Tuesday 10-Aug-2004 15:47 High Frequency

Monday 23-Aug-2004 14:52 Unknown

Monday 23-Aug-2004 18:29 Unknown

Tuesday 7-Sep-2004 13:56 Failure of the 138 kV Hainamosa - AES Andres power line

Monday 13-Sep-2004 16:13 Low Frequency

Tuesday 21-Sep-2004 3:33 Failure of the 138 kV Palamara - Hainamosa power line

Wednesday 3-Aug-2005 13:15 High-voltage breakers trip of the 138 kV Jigüey/Aguacate - Pizarrete power line

Thursday 18-Aug-2005 8:27 Failure of the 138 kV Haina - Itabo power line

Friday 19-Aug-2005 10:56 Low Frequency

Saturday 20-Aug-2005 11:05 Low Frequency

Wednesday 7-Sep-2005 13:11 Low Frequency

Wednesday 21-Sep-2005 22:51 High Frequency. Failure of the 138 kV Bonao II - Canabacoa power line

Monday 29-Oct-2007 0:52 Low Frequency

Wednesday 15-Jul-2009 11:34 Low Frequency

Wednesday 2-Sep-2009 18:03 Low Frequency. AES Andres Trip caused by 138 kV power line interconection wron open

Power Outages or Black OutsA power outage (also known as a power cut, power failure, power loss, or blackout) is a short- or long-term loss of the electric power to an area.

There are many causes of power failures in an electricity network. Examples of these causes include: faults at power stations, damage to power lines, substations or other parts of the distribution system, a short circuit, or the overloading of electricity mains.

The following table presents a list of the power outages that have occurred between 2000 and 2009.

COAL FOB Bolivar

FO6 3% Sulfur, Gulf Coast, Residual Fuel

LNG NYMEX Henry Hub

FO2 Gulf Coast, Destillates and Blendstocks, Waterborne


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Attachments


48 49

AVAILABILITY FACTOR OF A CENTRAL GENERATING UNIT: The quotient between the energy that the Available power of the plant could generate in the period considered, which is normally one year, and the energy corresponding to its maximum power during the same.

BAR: That point of the electrical system prepared to deliver and withdraw electricity.

BTU: British Thermal Unit of measurement. It is a unit of heat in the English European System. Its equivalence in the International System (IS) is the Calorie. The prices of Natural Gas are usually expressed in US$/MMBtu. 1 BTU is equivalent to 252 Calories (Cal).

CONTRACTS MARKET: The market for transactions of sale and purchase of electricity based on freely negotiated contracts for supply.

COMBINED CYCLE: a machine composed of two phases: one phase of gas and the other phase of steam. Typically the whole entity consists of a gas turbine, a heat recuperation boiler, a steam turbine, and one or several electrical generators.

COST OF LACK OF SUPPLY OR ENERGY NOT SERVED: The cost incurred by users, by not having energy available and having to obtain it from alternative sources; or the economic loss derived from the lack of production and sale of goods and services, and the loss of well-being due to the decrease of quality of living in the case of the residential sector. This cost is established annually by means of resolution of the Superintendency of Electricity.

FIRM POWER: The power that can be supplied by each generating units during peak hours, with high security/safety.

FREQUENCY REGULATION: Actions necessary to maintain frequency within the permissible tolerances defined for the system. The OC establishes the regulation parameters, and the generator companies are responsible for providing service through their control Centers.

FUEL OIL: A petroleum derivative obtained as a residue after the distilling process. Being a fuel, which is heavier than those which can be distilled at atmospheric pressure, Fuel Oil is used as a fuel for electrical energy plants, boilers, and ovens.

GAS TURBINE: A machine composed of a compressed air compressor (sic), a turbine especially designed for this purposes, and an electrical generator. The turbine converts thermal energy from fuel which is produced as a result of the expansion of hot gases from the explosion of the mixutre of compressed air, fuel, and flame, into mechanical energy that is used by the electrical generator to produce electricity.

HYDRAULIC TURBINE: A machine that uses kinetic energy and power from water to produce a rotation movement which , transferred through an axis, directly moves a machine or generator that transforms mechanical energy into electrical energy.

LIQUID NATURAL GAS (LNG): Natural Gas processed to be transported in liquid form. It is the best alternative for transporting and storage because when transformed into liquid as atmospheric pressure and –163oC , the liquefaction process reduces the volume of gas by 600 times.

MARGINAL CENTRAL UNIT: This refers to the generating unit or units, which at optimum load dispatch increase their generation when we demand is marginally increased.

MARGINAL SHORT-TERM COST: The variable costs necessary to produce one additional unit of energy, considering the demand and the generation infrastructure available.

MAXIMUM ANNUAL DEMAND: The maximum gross half our demand, during a calendar year, of the total of the generator units of the system, occurring within the system´s peak hours.

NATURAL GAS (NG): A mixture of gases that is frequently found in fossil beds, alone or accompanied by oil. It is composed mainly of methane in quantities greater than 90 to 95%, and in addition , usually contains other gases such as nitrogen, ethane, CO2, and traces of butane or propane , as well as small proportions of inert gases such as carbon dioxide and nitrogen.

NON REGULATED USER (UNR): That user of the electrical service will his monthly demand exceeds the limits established by the Superintendency in order to classified as a public user, and which fulfill the requirements established in the Regulation of the General Electricity Law.

OWN CONSUMPTION: The energy consumed by the auxiliary systems of a central unit or Substation.

PEAK POWER: Maximum power on the annual load curve.

PRIMARY FREQUENCY REGULATION (RPF): Power that a generator units can vary by automatic action of its system in the face of changes in the system’s frequency.

RIGHT OF CONNECTION: The difference between the total annual cost of the transmission system and the right of use estimated for the year. The procedure to determine the right of use is established in the Regulation of the General Electricity Law.

SECONDARY FREQUENCY REGULATION (RSF): Power which a generator unit can vary, or modify by automatic or manual action of its system of regulation in a sustained manner.

SELF PRODUCERS: Those enterprises or entities , who have available their own generation for consumption of electricity, independently of their productive process, and who eventually sell their surplus power or electrical energy to third parties.

SPOT MARKET: The market for transactions of short-term sale and purchase of electricity not based on term contracts was economic transactions are performed at Marginal Short Term Energy Cost and at Marginal Our Cost.

STEAM TURBINE: A machine that transforms thermal energy from fuel into mechanical energy. Through a process of generation of steam produced in a boiler, from which come conditions of high temperature and pressure. The kinetic energy of the steam is used by the turbine mechanically and through this by a generator to produce electricity.

VARIABLE PRODUCTION COST OF A THERMAL ELECTRICAL MACHINE: This corresponds to the cost of fuel placed in the plants, and used in the production of electrical energy, multiplied by the average specific consumption of the machine plus the variable non-fuel cost.

A

B

C

N

G

P

R

S

V

O

F

H

M

L

Glossary


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CONSUMER PRICE INDEX

Year JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC2000 168.80 169.80 171.20 171.30 171.50 172.40 172.80 172.80 173.70 174.00 174.10 174.00

2001 175.10 175.80 176.20 176.90 177.70 178.00 177.50 177.50 178.30 177.70 177.40 176.70

2002 177.10 177.80 178.80 179.80 179.80 179.90 180.10 180.70 181.00 181.30 181.30 180.90

2003 181.70 183.10 184.20 183.80 183.50 183.70 183.90 184.60 185.20 185.00 184.50 184.30

2004 185.20 186.20 187.40 188.00 189.10 189.70 189.40 189.50 189.90 190.90 191.00 190.30

2005 190.70 191.80 193.30 194.60 194.40 194.50 195.40 196.40 198.80 199.20 197.60 196.80

2006 198.30 198.70 199.80 201.50 202.50 202.90 203.50 203.90 202.90 201.80 201.50 201.80

2007 202.42 203.50 205.35 206.69 207.95 208.35 208.30 207.92 208.49 208.94 210.18 210.04

2008 211.08 211.69 213.53 214.82 216.63 218.82 219.96 219.09 218.78 216.57 212.43 210.23

2009 211.14 212.19 212.71 213.24 213.86 215.69 215.35 215.83 215.97 216.18 216.33 215.95

Source: Web Page of the DR Central Bank

Source: U.S. Bureau of Labor Statistics

Economic Indexes

PODERES CALORÍFICOS SUPERIORES E INFERIORES DE ALGUNOS COMBUSTIBLES

PCS PCI PCS PCI PCS PCI

Kcal/Kg Kcal/Kg Kcal/L Kcal/L Kj/L Kj/L

Combustibles Líquidos

Petróleo 10,800 10,008 9,374 8,686 39,250 36,371

Oleo Diesel 10,750 10,000 9,159 8,680 38,350 36,343

Oleo Combustible 10,090 9,583 10,217 8,318 42,780 34,827

Gas Licuado de Petróleo 11,750 11,000 6,486 9,548 27,160 39,977

PCS PCI PCS PCI

Kcal/m3 Kcal/m3 Kcal/m3 Kcal/m3

Combustibles Gaseosos

Gas Natural Húmedo 10,454 8,240 43,770 34,500

Gas Natural Seco 9,256 8,500 38,750 35,584

PCS PCI PCS PCI

Kcal/Kg Kcal/Kg Kj/Kg Kj/Kg

Combustibles Sólidos

Carbón Vegetal 7,500 6,500 30,560 27,213

Coque de Carbón Mineral 7,300 6,998 30,560 29,299

MONTHLY AVERAGE EXCHANGE RATE [RD/USD]

Year JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC AVERAGE

2000BUY 15.98 16.05 16.05 16.05 16.05 16.05 16.05 16.05 16.38 16.45 16.49 16.53 16.18

SALE 15.98 16.05 16.05 16.05 16.05 16.05 16.05 16.05 16.38 16.45 16.49 16.53 16.18

2001BUY 16.62 16.66 16.66 16.66 16.66 16.66 16.66 16.66 16.66 16.66 16.76 16.97 16.69

SALE 16.62 16.66 16.66 16.66 16.66 16.66 16.66 16.66 16.66 16.66 16.76 16.97 16.69

2002BUY 17.05 17.15 17.15 17.56 17.56 17.56 17.56 17.56 17.56 17.56 17.56 17.56 17.45 SALE 17.05 17.15 17.15 17.70 17.76 17.76 17.76 17.76 17.76 17.76 17.76 17.76 17.59

2003BUY 17.56 18.17 22.72 23.78 25.60 28.89 34.45 33.72 31.70 34.91 39.74 37.44 29.06 SALE 17.76 18.37 22.92 23.98 25.80 29.09 34.85 34.13 32.25 35.23 40.24 37.82 29.37

2004BUY 46.09 49.23 46.52 44.35 46.92 48.12 44.84 41.25 36.95 32.27 29.56 28.86 41.25 SALE 46.64 50.44 47.18 44.81 47.69 48.67 45.56 42.11 37.62 32.98 30.13 29.33 41.93

2005BUY 29.84 28.85 28.30 28.25 28.70 28.90 28.93 29.00 30.42 32.41 33.25 33.12 30.00 SALE 30.40 29.22 28.60 28.54 28.91 29.08 29.06 29.13 30.82 32.70 33.54 33.39 30.28

2006BUY 34.56 34.17 32.56 32.11 32.49 32.77 32.75 32.63 32.95 33.47 33.56 33.09 33.09 SALE 34.84 34.44 32.85 32.33 32.73 32.94 32.91 32.80 33.12 33.66 33.69 33.30 33.30

2007BUY 33.70 33.36 32.79 32.23 32.14 32.42 32.99 32.90 33.31 33.46 33.41 33.52 33.02 SALE 33.90 33.51 32.96 32.40 32.29 32.57 33.14 33.05 33.46 33.59 33.53 33.66 33.17

2008BUY 33.76 33.83 33.92 34.03 34.01 34.16 34.27 34.68 34.83 34.99 35.19 35.26 34.41 SALE 33.89 33.96 34.04 34.14 34.13 34.27 34.39 34.80 34.95 35.09 35.32 35.39 34.53

2009BUY 35.37 35.56 35.67 35.83 35.95 35.92 35.98 36.03 36.06 36.09 36.09 36.09 35.89 2009 SALE 35.49 35.65 35.77 35.92 36.04 36.00 36.07 36.10 36.13 36.16 36.17 36.16

ENERGY’S UNITS

J Cal Btu KVh

Joulie J 1 0.2388 0.009478 0.000000277

Calories Cal 4.1869 1 0.0039683 0.000001163

Term Unit British Btu 1055.06 252 1 0.00029307

Kilowatt / Hours KVh 3600000 8598000 3412.14 1

DENSITY’S UNITS

Kg / m3 Lb / Pie 3 Lb / Gl (UK) Lb / Gl (US)

Kilograms / Cubic Meters Kg / m3 1 0.062428 0.010022 0.008345

Pound / Cubic Feet Lb / Pie 3 16.0185 1 0.160544 0.133681

Pound / Gallon UK Lb / Gl (UK) 99.7764 6.22884 1 0.83268

Pound / Gallon USA Lb / Gl (US) 119.826 7.48047 1.20094 1

MASS’S UNITS

Kg Ton. Large Ton Short Ton Pound (Lb

Kilogramo Kg 1 0.001 0.000984 0.001102 2.2046

Ton T 1000 1 0.984207 1.10231 2204.62

Large Ton TL 1016 1.016 1 1.12 2240

Short Ton TC 907 0.907 0.892857 1 2000

Pound Lb 0.4535 0.0004535 0.000446429 0.0005 1

VOLUME’S UNITS

cm3 M3 Feet 3 Inch 3 Gal (UK) Gal (USA) BBL Liters (Lt)

Cubic Centimeters cm3 1 0.000001 0.0000353 0.06102 0.00021997 0.00026417 6.2899E-06 0.006102

Cubic Meters M3 1000000 1 35.3147 61000 219.969 264.17 6.28976 1000.028

Cubic Feet Feet 3 28320.589 0.028317 1 1727.556 6.2288 7.4805 0.178107 28.321

Cubic Inch Inch 3 16.387 0.00001639 0.00057863 1 0.00360465 0.00432898 0.0001031 0.0163866

Gallon Gal (UK) 4546.09 0.004546 0.160544 277.42 1 1.20094 0.028594 4.54596

Gallon Gal (US) 3785.41 0.003785 0.133681 231 0.83268 1 0.02381 3.78533

Barrels BBL 158984 0.158988 5.6146 9698.024 34.9726 42 1 158.984

Liters Liters (Lt) 1000.028 0.001 0.03531 61.0255 0.219976 0.264178 0.0063 1

2009 Statistical Report

52

statistical report 2009

Documents

aes dominicanaletter

aes andres

aes corporation

electric power sector

electric market composition

dominican republic

integrity honor commitments

generation of electricity