thailand power development plan (pdp

PDP 2010. .

Electricity Generating Authority of Thailand

SUMMARYOF

THAILAND POWER DEVELOPMENT PLAN2010-2030

Report no. 912000-5305 System Planning Division

April 2010

SUMMARY

OF

THAILAND POWER DEVELOPMENT PLAN

2010-2030

System Planning Division

Electricity Generating Authority of Thailand

April 2010

Contents

Page

1. Introduction 1

2. Summary 3

3. Assumptions in the Formulation of PDP 2010 11

4. Power Demand Forecast 16

5. Thailand Power Development Plan 2010-2030 (PDP 2010) 19

5.1 Generating Capacity in 2010-2020 19

5.2 Generating Capacity in 2021-2030 22

5.3 Renewable Energy 23

5.4 Fuel Requirement 25

6. Demand Side Management (DSM) 35

7. Renewable Energy 39

7.1 The Renewable Energy Plan (2008-2022) of the Ministry of Energy 39

7.2 EGAT Renewable Energy Projects 40

7.3 Small Power Producer (SPP) Using Renewable Energy 41

7.4 Very Small Power Producer (VSPP) Using Renewable Energy 42

8. Cogeneration System 45

8.1 Cogeneration SPP 45

8.2 Cogeneration VSPP 46

9. Nuclear Power Plant Projects 47

10. Greenhouse Gas Emission Reduction in Power Sector 51

11. Transmission System Development Plan 54

List of Appendices Page Appendix 1 Comparison of Thailand Power Development Plans 63 Appendix 2 Map of Thailand Power System 67 Appendix 3 Installed Capacity of Thailand Power System 71 Appendix 4 Existing Transmission System 75 Appendix 5 Power Demand Statistic and Load Forecast 79 Appendix 6 Projection of Generating Capacity Classified by Power Plant Types 85 Appendix 7 Power Plant Retirement Schedule 89 Appendix 8 Projection of Energy Generation Classified by Fuel Types 93 Appendix 9 Renewable Energy and Purchasement Plan from SPP and VSPP Plan 97 Appendix 10 Transmission System Expansion Projects 105

1. Introduction

The last Thailand Power Development Plan 2007–2021 (PDP 2007 Revision 2) was an

update of the PDP 2007 Revision 1. The original PDP 2007 was issued in June 2007 followed

by a revised PDP 2007 (PDP 2007 Revision 1) in December 2008.

Since December 2008, the electricity demand has decreased significantly due to

depressed economic conditions. To portray a clear picture of power sector development, the

Ministry of Energy appointed a subcommittee to prepare a new Thailand PDP and a working

group to work on the relevant assumptions on 16 September 2009 and 3 November 2009,

respectively. The new PDP was designated as a “Green PDP” which highlights on greenhouse

gas emission reduction and promotions of efficient energy utilization and electricity

production through cogeneration system, in addition to system reliability. Not only did it

corporate power purchase projects from domestic producers and neighboring countries that

were approved by the Cabinet but also power generation from renewable energy the

Alternative Energy Development Plan (AEDP) 2008–2022. Besides, opinions and comments

obtained from the public hearing of PDP 2007 Revision 2 were taken into account. Therefore,

the new PDP could be a complete guideline for power system development that encourages

generation from renewable energy and lessens greenhouse gas emission, and thus a balance of

generation resources.

EGAT, as a member of the subcommittee and the working group, formulated the

Thailand Power Development Plan 2010–2030 (PDP 2010) within the following frameworks:

1. Extend the planning horizon from 15 years to 20 years (2010-2030)

2. Revise Thailand’s Load Forecast based on NESDB’s long term economic growth

3. Analyze and integrate the effects of DSM projects in both the load forecast and the

generation expansion planning

4. Combine the re-estimated amount of power purchase from renewable energy

regarding AEDP 2008–2022 into the plan

5. Review the amount of power purchase from SPPs in 2009-2015 and further

regarding the NEPC’s resolution on 24 August 2009 to promote power production

by cogeneration system

6. Reconsider power import from neighboring countries and identify only promising

projects

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7. Lower greenhouse gas emission

PDP 2010 was approved by NEPC and endorsed by the Cabinet on 12 March 2010

and 23 March 2010, respectively.

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2. Summary

2.1 Current Status

The peak power demand of 2009 occurred on 24 April 2009 of which the

maximum power generation of the country reached 22,315.4 MW which was 78.4 MW or

0.35% higher than the record of 2008.

2.1.1 Power Plants: As of December 2009, the total contract capacity was

29,212 MW comprising 14,328.1 MW (49.0%) of EGAT’s power plants, 14,243.9 MW

(48.8%) of domestic private power producers (IPPs and SPPs) and 640 MW (2.2%) of

neighboring country power purchase. The details of contract capacity of Thailand power

system are shown in Appendix 3.

2.1.2 Transmission System: The standard voltage levels of EGAT

transmission system are 500 kV, 230 kV, 132 kV, 115 kV, and 69 kV at operating frequency

of 50 Hz. The total length of high voltage transmission line as of December 2009 was 30,446

circuit-kilometers. The total number of high voltage substations was 209 with total

transformer capacity of 72,787 MVA. The summary of transmission line length and number

of EGAT’s substations classified by voltage level are shown in the table below.

Voltage Substation Transmission Number MVA (Circuit-km) 500 kV 10 15,850 3,722

230 kV 68 41,860 13,393

132 kV - 133 9

115 kV 131 14,556 13,280

69 kV - - 19

300 kV HVDC - 388 23

Total 209 72,787 30,446

Details of transmission lines and substations are shown in Appendix 4.

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2.2 Key Assumptions in PDP 2010

2.2.1 The new Thailand’s Load Forecast was calculated upon energy

consumption at end users’ level projected by the Metropolitan Electricity Authority (MEA)

and the Provincial Electricity Authority (PEA). The figures were derived from regression

analysis based on recorded electricity retail and the GDP growth in the base case of NESDB’s

preliminary study result. The reason to employ this initial outcome was to establish PDP 2010

in due course to cope with present situations and to ascertain work plans of the obliged

projects.

2.2.2 Information about energy conservation from ongoing DSM programs

was acquired from EPPO and already included in regression analysis, whereas that from new

programs was subtracted from the forecast demand afterward.

2.2.3 Power generation using renewable energy in 2010-2022 was estimated as

per AEDP (2008-2022) of the Ministry of Energy, while that in 2023-2030 was done with the

annual estimation.

2.2.4 The quantity and timing of power purchase from SPPs in 2010-2021 was

reviewed with the actual purchasing progress as well as the additional capacity to comply

with the NEPC’s resolution on 24 August 2009 to promote electricity production by

cogeneration system. Thereafter, the purchased capacity was planned to be 360 MW annually

in 2022–2029 and 540 MW in 2030.

2.2.5 The minimum annual reserve margin was constraint to 15% or sufficient

to handle the western gas shortage which is equivalent to 6,961 MW. Hence, the system’s

reserve margin in the early years is greater than 20%.

2.2.6 Candidate power plants considered in PDP 2010 were 800 MW clean

coal power plant, 800 MW combined cycle power plant, 1,000 MW nuclear power plant, 250

MW gas turbine power plant and 500 MW Lam Takhong pumped storage hydro power plant

(additional units).

2.2.7 In order to maintain the natural gas consumption in power sector, the gas

fired power plants to be retired would be replaced with their succeeding combined cycle

generating units.

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2.2.8 Greenhouse gas emission per unit of generated electricity in 2030 was set

to be lower than that of PDP 2007 Revision 2.

2.2.9 The proportion of fuel use and energy resources was allocated as below:

− Renewable energy as per the 15 Years AEDP; Cogeneration SPP

took first priority and was followed by other alternative technologies.

− Nuclear power plant was limited to 1 unit/year and allowed only 2

years in a row with a pause of 2 years to comfort the investment plan.

− Power purchase from neighboring countries must not exceed 25% of

the total generating capacity.

− Other generating capacity was a well considered mix of replacing gas

fired combined cycle power plants and clean coal thermal power

plants.

2.3 Thailand Power Development Plan (PDP 2010)

With the aforementioned assumptions about future electrical supplies, power

import from neighboring countries, load forecast and others, EGAT and the Ministry of

Energy cooperated in performing Thailand Power Development Plan 2007–2021 (PDP 2010)

which can be summarized as followings.

2.3.1 Projects during 2010-2020 - EGAT owned power plants 4,821 MW

- IPP 4,400 MW

- SPP 3,539 MW

- VSPP 2,335 MW

- New combine cycle power plant supporting 800 MW

LPG production at Khanom GSP

- Power purchase from neighboring countries 5,669 MW

2.3.2 Projects during 2021-2030 - New EGAT power plant (Renewable) 97 MW

- New EGAT power plant (Natural Gas) 13x800 MW

- New EGAT power plant (Clean Coal) 8x800 MW

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- New EGAT power plant (Nuclear) 4x1,000 MW

- Power purchase from SPP 3,800 MW

- Power purchase from VSPP 1,745 MW

- Power purchase from neighboring countries 6,000 MW

Details of power plants commissioning in the period of 2010-2020 and 2021-

2030 are exhibited in Table 2.1 and 2.2, respectively.

2.3.3 Subsequent Works from PDP 2010: Since an intention of PDP 2010 is

to response to environmental policies by lowering greenhouse gas emission, EGAT has

prepared to implement the following programs.

- Continuous studies of innovative DSM programs and development

- Improvement on the efficiency of EGAT’s aging power plants

considering their potential and action plans individually

- Improvement on transmission system to reduce losses

- EGAT Renewable Energy Development Plan in harmony with

Thailand PDP 2010 and the 15 Years AEDP

Further information about measures and indicative plans are described in

Chapter 10.

2.3.4 Power Purchase from Neighboring Countries, and SPP and VSPP

Using Renewable Energy Power import projects stated in PDP 2010 are merely a long term indicative

guideline. The actual purchase depends on definite capacity and completion date of each

project as well as the appropriate timing and power demand. Above all, it must follow the

MOU(s) between the governments.

In the same manner, power purchase projects from SPP and VSPP using

renewable energy specified in PDP 2010 are only a guideline for long term outlook based on

the purchase status as of 31 December 2009 and the 15 Years AEDP. The exact purchase

varies upon the potential of different resources and technologies, and must be corresponding

with the Government’s policies.

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Table 2.1Thailand Power Development Plan 2010-2020

(PDP 2010)Peak Contract Minimum

Year Demand Capacity Reserve Margin(MW) (MW) (%)

2009 22,044.9 Total Capacity as of December 2009 29,212 27.62010 23,249 VSPP (Jan) 367 MW

SPP (Renewables) (Jun) 90 MW

Power Purchase from Lao PDR (Nam Theun 2) (Mar) 920 MW

North Bangkok CC #1 (May) 670 MW

SPP (Cogeneration) (Nov) 90 MW 31,349 28.12011 24,568 Retirement of Khanom TH #1 (Jul) -70 MW

VSPP (Jan) 258 MW

EGAT Renewables (Jan) 18 MW

Power Purchase from Lao PDR (Nam Ngum 2) (Jan) 597 MW

Chao Phraya Dam #1-2 (Jan) 2x6 MW


Naresuan Dam (Oct) 8 MW

GHECO-ONE Co., Ltd. (Nov) 660 MW 32,992 27.12012 25,913 VSPP (Jan) 162 MW

Mae Klong Dam #1-2 (Jan) 2x6 MW

Khun Dan Prakarnchon Dam (Apr) 10 MW

Pasak Jolasid Dam (May) 7 MW


SPP (Cogeneration) (Jun-Dec) 704 MW

Power Purchase from Lao PDR (Theun Hinboun Ext.) (Jul) 220 MW 34,172 23.72013 27,188 VSPP (Jan) 187 MW

Kwae Noi Dam #1-2 (Jan) 2x15 MW


SPP (Cogeneration) (Mar-Sep) 720 MW

Siam Energy Co., Ltd. #1-2 (Mar, Sep) 2x800 MW

National Power Supply Co., Ltd. #1-2 (Nov) 2x135 MW 37,003 25.42014 28,341 Retirement of Bang Pakong TH #1-2 (Jan) -1052 MW

VSPP (Jan) 192 MW


National Power Supply Co., Ltd. #3-4 (Mar) 2x135 MW

Wang Noi CC #4 (Jun) 800 MW

SPP (Cogeneration) (Jun) 90 MW

Power Generation Supply Co., Ltd. #1-2 (Jun, Dec) 2x800 MW

Chana CC #2 (Jul) 800 MW 39,720 23.42015 29,463 Retirement of Rayong CC #1-4 (Jan) -1175 MW

VSPP (Jan) 167 MW


Bang Lang Dam (Renovate) (Jan) 12 MW

Power Purchase from Lao PDR (Hongsa TH #1-2) (May, Oct) 2x491 MW

SPP (Cogeneration) (Jun) 270 MW 39,990 26.0

Projects

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Table 2.1 (Continued)

Thailand Power Development Plan 2010-2020

(PDP 2010)

Peak Contract Minimum

Year Demand Capacity Reserve Margin

(MW) (MW) (%)

2016 30,754 Retirement of Khanom TH #2 (Jul) -70 MW

Retirement of Khanom CC #1 (Jul) -678 MW


Power Purchase from Myanmar (Mai Khot TH #1-3) (Jan, Apr, Jul)3x123 MW

Power Purchase from Lao PDR (Hongsa TH #3) (Feb) 491 MW

VSPP (Jun) 231 MW

SPP (Cogeneration) (Jun) 270 MW

New Capacity _ South (Jul) 800 MW 41,419 27.2

2017 32,225 Retirement of Bang Pakong CC #3 (Jan) -314 MW

End of SPP Contract (Apr-Oct) -180 MW

VSPP (Jan) 229 MW


Power Purchase from Lao PDR (Nam Ngum 3) (Jan) 440 MW

Lam Takhong Pumped Storage #3-4 (Jun) 2x250 MW

SPP (Cogeneration) (Jun) 270 MW 42,374 23.2

2018 33,688 Retirement of Bang Pakong CC #4 (Jan) -314 MW

Retirement of Nam Pong CC #1 (Jan) -325 MW

End of SPP Contract (Feb-Apr) -42 MW

VSPP (Jan) 176 MW


SPP (Cogeneration) (Jan) 270 MW

Power Purchase from Neighbouring Countries (Jun) 450 MW 42,619 17.3

2019 34,988 End of SPP Contract (Jun-Sep) -185 MW

VSPP (Jan) 177 MW



Power Purchase from Neighbouring Countries (Jun) 600 MW

EGAT Clean Coal #1 (Jun) 800 MW 44,289 15.0

2020 36,336 Retirement of South Bangkok CC #1 (Jan) -316 MW

Retirement of Nam Pong CC #2 (Jan) -325 MW

End of Tri Energy Co., Ltd. (TECO) PPA (Jun) -700 MW

End of SPP Contract (Feb-Aug) -188 MW

VSPP (Jan) 190 MW



EGAT Nuclear Power Plant #1 (Jan) 1000 MW

Power Purchase from Neighbouring Countries (Jun) 600 MW 44,842 15.6

Total Added Capacity 2010-2020 21,564 MW

Total Retired Capacity 2010-2020 - 5,933 MW

Projects

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Table 2.2

Thailand Power Development Plan 2021-2030

(PDP 2010)



(MW) (MW) (%)

2021 37,856 End of SPP Contract (Feb-Oct) -200 MW

VSPP (Jan) 135 MW




Power Purchase from Neighbouring Countries (Jan) 600 MW

EGAT Clean Coal #2 (Jun) 800 MW 47,618 15.4

2022 39,308 Retirement of Bang Pakong TH #3 (Jan) -576 MW

End of SPP Contract (Aug-Oct) -150 MW

VSPP (Jan) 294 MW



EGAT Gas Fired CC #1 (Jan) 800 MW

Power Purchase from Neighbouring Countries (Jan) 600 MW 48,982 16.0

2023 40,781 Retirement of Wang Noi TH #1-3 (Jan) -1910 MW

Retirement of South Bangkok CC #2 (Jan) -562 MW

Retirement of Bang Pakong TH #4 (Jan) -576 MW

End of Theun Hinboun PPA (Jan) -214 MW

End of Eastern Power & Electronic Co., Ltd. (EPEC) PPA (Apr) -350 MW

End of SPP Contract (Apr) -41 MW

VSPP (Jan) 146 MW


EGAT Gas Fired CC #2-6 (Jan) 5x800 MW

EGAT Clean Coal #3 (Jan) 800 MW


2024 42,236 End of SPP Contract (Feb-Sep) -680 MW

Retirement of Mae Moh TH #4 (Jan) -140 MW

VSPP (Jan) 148 MW




2025 43,962 Retirement of Mae Moh TH #5-6 (Jan) -280 MW

End of SPP Contract (Apr-Oct) -244 MW

End of Independent Power (Thailand) Co., Ltd. (IPT) PPA (Sep) -700 MW

Retirement of Ratchaburi TH #1-2 (Nov) -1440 MW

VSPP (Jan) 163 MW





Projects

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Table 2.2 (Continued)Thailand Power Development Plan 2021-2030

(PDP 2010)



(MW) (MW) (%)

2026 45,621 Retirement of Mae Moh TH #7 (Jan) -140 MW

End of SPP Contract (Sep) -5 MW

VSPP (Jan) 159 MW



EGAT Clean Coal #4-5 (Jan) 2x800 MW


2027 47,344 End of SPP Contract (Feb) -15 MW

Retirement of Ratchaburi CC #1-2 (May) -1360 MW

Retirement of Ratchaburi CC #3 (Nov) -681 MW

VSPP (Jan) 169 MW




2028 49,039 End of SPP Contract (Jan-Dec) -95 MW

End of Glow IPP Co., Ltd. PPA (Feb) -713 MW

VSPP (Jan) 173 MW




EGAT Clean Coal #6-7 (Jan) 2x800 MW



VSPP (Jan) 179 MW



EGAT Clean Coal #8 (Jan) 800 MW



End of Houay Ho PPA (Jan) -126 MW

VSPP (Jan) 179 MW


EGAT Clean Coal TH #9 (Jan) 800 MW




Total Installed Capacity as of December 2009 29,212 MW



Grand Total Capacity at the end of 2030 65,547 MW

Projects

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3. Assumptions in the Formulation of PDP 2010

The crucial assumptions and criteria employed in performing PDP 2010 can be

divided into 3 categories as followings:

1. System Reliability

- Reserve Margin

- Power Purchase from Neighboring Countries

2. Clean Energy and Efficient Utilization

- Demand Side Management (DSM)

- Electricity Generation from Renewable Energy

- Electricity Generation with Cogeneration System

- Greenhouse Gas Emission Reduction

3. Load Forecast

3.1 Reserve Margin

There have been several gas shortage events mostly from western pipeline system,

while natural gas is still the major fuel for power generation in Thailand. Considering the risk

of such emergency incidents, the suitable reserve margin is probably larger than 20% of the

total generating capacity of the system. In addition, fuel diversification is a concerned issue, i.e.

balancing the portion of power generation from coal, nuclear, renewable energy and power

import.

3.2 Power Import from Neighboring Countries

Only promising power import projects were identified in PDP 2010 with their

contract capacity and commissioning schedule. They must have certain signs of success e.g.

Tariff MOU. However, as suggested by the study on power import proportion, maximum

share of the power import over the system’s generating capacity must not exceed the following

percentages:

• Total import from 1 country - 13%

• Total import from 2 countries - 25%



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3.3 Demand Side Management (DSM)

Electrical energy saving at consumption level and peak reduction at the system

peak time resulting from existing DSM programs were already integrated in the regression

analysis of the “February 2010” Load Forecast. These programs were composed of energy

conservation campaigns as well as market mechanisms and consumer behaviors that induced

appliances’ efficiency improvement e.g. “No.5 Label”. Nevertheless, information about the

impacts of new programs and innovations, e.g. T5 fluorescent tubes, was unavailable and

beyond the capability of regression analysis. Thus, they were later deducted from the load

forecast.

3.4 Electricity Generation from Renewable Energy

At present, the proposed power generation from renewable energy projects are

indefinite in aspects of duplicated locations and no robust guarantee of implementation, while

their influences on system reliability and the readiness of transmission network are also needed

to be studied. Therefore, PDP 2010 contains power generation from renewable energy

regarding the 15 Years AEDP to the year 2022 and not less than 5% of energy production

referring to the VSPP purchase projected by distribution authorities afterward. The table below

shows the cumulative generating capacity from all renewable energy resources.

Unit: MW

Type Biomass Biogas Solar MSW 1/ Wind Small Hydro Total

End of 2009 663.04 49.04 9.23 10.82 3.07 18.33 753.52

End of 2022 2,272.04 152.04 707.23 159.32 1,231.07 281.33 4,803.02

End of 2030 3,032.04 176.04 1,107.23 183.32 1,321.07 281.33 6,101.02

Note: 1/ Municipal Solid Waste

Since renewable technologies are in their early stage and recently commercially

introduced, there is insufficient evidence to assure their dependable generating capacity. Most

of available data are average values on daily and monthly basis, which cannot reflect the power

generation at a certain point of time, particularly that of wind and solar power. Consequently,

concerning risk aversion, PDP 2010 recommends deeming their dependable capacity at

confident level and later adjusting it when the actual information is available.

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3.5 Electricity Generation with Cogeneration System

Due to the NEPC’s resolution on 24 August 2009 to promote cogeneration

system, the amount of power purchase from SPP using cogeneration system in PDP 2010 was

not only compatible with the purchasing plan during 2009-2015 but also added with another

2,000 MW in 2015-2021 and 360 MW annually during 2022-2030. Cogeneration system is

promoted by the Government as it allows more efficient use of steam and power as well as the

natural gas utilization.

Unit: MW

Type Firm SPP

Non-Firm SPP VSPP Annual

Total Cumulative

Total

End of 2009 1,787 169 6 1,962 1,962

Proposed to sell by 2014 1,604 40 65 1,709 3,671

NEPC’s Resolution (2015-2021) 2,000 - 23 2,023 5,694

360 MW Annual Addition (2022-2030) 3,420 - 25 3,445 9,139

Total 8,811 209 119 9,139

3.6 Load Forecast

NESDB in collaboration with NIDA are currently performing a study of Thailand

long term economic outlook. The primary outcomes had revealed the long term GDP

projection in 3 scenarios namely High Case, Base Case and Low Case. The PDP revising

subcommittee then selected the Base Case figures to perform the load forecast for PDP 2010.

The peak demand of the year 2021 was estimated at 37,718 MW which is 6,563 MW lower

than that of PDP 2007 Revision 2. Meanwhile, the peak demand at the end of PDP 2010 (the

year 2030) was expected to be 52,691 MW.

3.7 Greenhouse Gas Emission Reduction

In 2009, the power generation sector released 0.546 kg of carbon dioxide for every

kWh of electricity production. To respond to clean energy policy and the Green PDP, the

concrete plan to cut down greenhouse gas emission in generation system was incorporated into

PDP 2010. The goal is to have a lower emission rate than that of PDP 2007 Revision 2 in the

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year 2020 and then to retain it at not a higher rate, which can be done by apportioning assorted

types of low emission power plant.

3.8 Allocation of New Generating Capacity

The combination of new capacities in PDP 2010 was considered upon the

followings.

Renewable Energy and Cogeneration System

Power generation from renewable energy and cogeneration SPPs was the first

priority in future planting up. Their capacity and operating schedule of the renewable energy in

2010-2022 was in line with the 15 Years AEDP. Thereafter, their energy generation was set to

not less than 5% of total energy requirement as predicted by distribution power utilities.

Meanwhile, cogeneration SPPs utilize energy resources and infrastructures more efficiently.

Their capacity and commissioning schedule was according to the purchasing progress in 2010-

2014, the NEPC’s resolution on 24 August 2009 in 2015-2021 (2,000 MW) and the agreed

capacity in 2022-2030 (360 MW annually).

Power Purchase from Neighboring Countries

PDP 2010 has promising power purchase projects from 2 neighboring countries.

Hence, their portion was limited to 25% due to the system reliability constraints. However,

most of them are hydro electric power plants which do not discharge greenhouse gases, so

they can lessen the number of future fossil fuel fired power projects.

Gas Fired Power Plant

Due to the risk of natural gas supply, especially from the western gas pipeline

system, PDP 2010 attempted to diminish gas quantity in power generation by diversifying fuel

types and resources. Nevertheless, to maximize the profits of existing domestic resources and

infrastructures, new gas-fired power plants were assigned to replace the retiring ones.

Nuclear Power Plant

Nuclear power plants were selected by the optimization because of their low

production cost. In addition, they can serve base load for a long duration and thus secure the

power system. They can also help trimming down the number of fossil fuel fired power plants

since they do not release greenhouse gases. However, due to public acceptance, PDP 2010

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allowed only 5 units of them with a maximum energy generation share of 10% to the total

generation requirement. Besides, they had to come in intervals to ease the investment burdens.

Clean Coal Power Plant

As well as nuclear power plants, coal-fired power plants were picked up by the

optimization due to their low production cost. However, there are difficulties with location,

greenhouse gas emission and public acceptance, despite Supercritical or Ultra-supercritical

technologies with bituminous fuel and FGD equipment. Educating people about facts,

knowledge and understanding is therefore very essential. To avoid greenhouse gas emission,

clean coal power plants were the last precedence of new planting up in PDP 2010.

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4. Power Demand Forecast

The power demand forecast used for the arrangement of this Thailand Power

Development Plan (PDP 2010) is the electricity demand prediction of the Thailand power

system, called “The Power Demand Forecast (February 2010)”, prepared by the Load

Forecast Working Group (LFWG) set up by the Thailand Load Forecast Subcommittee

(TLFS). The forecast is based on the following assumptions.

1. The forecast period 2010 – 2030 is defined.

2. The actual peak demand and actual energy generation of 2009 are bases for

this forecast.

3. The estimated Thailand Economic Growth or the forecasted Thailand Gross

Domestic Products (GDP), shown in Table 4.1, is a required parameter to predict the future

power demand. The forecast GDP figure was agreed by the LFWG for this power demand

forecast as the followings:

• For short-term period (2010 – 2011): the estimated GDP as agreed among

MEA, PEA, and EGAT for performing their plan their 2011 budgets was used

• For long-term period (2012 – 2024): the forecasted GDP was applied

following the initial result obtained from the Thailand Long-term GDP study

by the National Institution of Development Administration (NIDA) under the

governance of the National Economic and Social Development Board

(NESDB). The final report of the study will be completed by this year 2010.

• For further period (2025 – 2030): the forecasted GDP was fixed as the same

rate as that in 2024 in the initial result of the study

4. Considering renewable energy in the power demand forecast, the estimated

amounts of MEA and PEA renewable energy purchases from Very Small Power Producers

(VSPP), which is consistent with the Alternative Energy Development Plan (AEDP) prepared

by the Ministry of Energy was taken into account. It is noted that the plan was approved by

the Cabinet on 28 January 2009 (more details shown in Chapter 7).

5. The Demand Side Management (DSM) project with a clear specification of

electricity demand reduction at consumption level was considered. However, DSM projects

are classified from electricity conservation plans gathered and estimated by the Energy

Planning and Policy Office (EPPO). In addition, the DSM project is considered as new

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projects which have not been included in the Load Forecast Model (more details shown in

Chapter 6).

Table 4.1 The Preliminary Estimation of Thailand Economic Growth or Forecasted Gross Domestic Products for Thailand Power Demand Forecast (February 2010)

Unit: Percent

Year Low Case Base Case High Case

2010 3.41 3.41 3.41

2011 3.88 4.02 4.28

2012 3.84 4.24 4.78

2013 3.50 4.06 4.24

2014 4.32 4.78 5.12

2015 3.97 4.46 4.83

2016 3.82 4.28 4.61

2017 3.85 4.28 4.60

2018 3.68 4.10 4.43

2019 3.75 4.15 4.49

2020 3.87 4.24 4.58

2021 3.82 4.18 4.53

2022 3.63 4.01 4.37

2023 3.60 3.95 4.31

2024 3.58 3.92 4.28

2025 3.58 3.92 4.28

2026 3.58 3.92 4.28

2027 3.58 3.92 4.28

2028 3.58 3.92 4.28

2029 3.58 3.92 4.28

2030 3.58 3.92 4.28

Source: The National Institute of Development Administration (NIDA), 2010, Draft Final Report of

the study of Thailand Long-term Economic Growth or Gross Domestic Products (GDP) Project

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The “February 2010” power demand forecast used in formulating PDP 2010 is

shown in Appendix 5. For peak demand, the forecasted peak demand in 2030 is

approximately 52,890 MW, 2.37 times higher than that in 2009, (22,315.35 MW). An average

growth rate of the forecasted peak demand during 2010 – 2030 is 4.19 percent per year. For

energy demand, the forecasted energy demand in 2030 is about 347,947 GWh, 2.38 times

higher than that in 2009, (146,182 GWh). An average growth rate of the forecasted energy

demand during 2010 – 2030 is 4.22 percent per year. Thus, the long-term load factor is

between 74 and 75 percent.

The “February 2010” demand forecast anticipated electricity saving resulting from

the new DSM projects by adjusting electricity demand at consumption level. This causes the

future energy elasticity1 decrease from 1.36 in 2010 to 0.99 in 2030 (more details shown in

Appendix 5).

Compared with the previous “December 2008” demand forecast, the “February

2010” demand forecast indicates decreasing projection due to the lower long-term economic

forecast which was reviewed to be compatible with the global economic recession and

Thailand economic downturn, as presented in Appendix 5.

1 Energy Elasticity means the ratio of the energy increase rate and the GDP increase rate.

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5. Thailand Power Development Plan 2010-2030 (PDP 2010)

The current Thailand Power Development Plan or PDP 2010 embraces the horizon

of 2010 to 2030. The total contract capacity at the end of 2030 is 65,547 MW comprising a)

29,212 MW existing capacity as of December 2009, b) 54,005 MW of future added capacity

from EGAT power plants, power purchase from IPP, SPP and VSPP, and c) 17,671 MW of

retired power plants and expiration of Power Purchase Agreement (PPA) term. Details of new

power plants and power purchase projects are displayed in Table 5.1 and Figure 5.1, while the

annual generating capacity by power plant type and the retirement schedule are attached in

Appendix 6 and 7, respectively.

5.1 Generating Capacity in 2010-2020 Power projects commissioning in this

period are already under implementation, committed or needed to serve the increasing demand.

The additional 21,564 MW include:

5.1.1 EGAT Power Plants: 4,582 MW

- North Bangkok Combined Cycle Block #1 (670 MW)

- Wang Noi Combined Cycle Block #4 (800 MW)

- Chana Combined Cycle Block #2 (800 MW)

- Lam Takhong Pumped Storage Unit #3-4 (2x250 MW)

- Clean Coal Thermal Power Plant (800 MW)

- Nuclear Power Plant (1,000 MW)

- Bang Lang Hydroelectric Renovation (12 MW)

In this group, projects that are already allocated to certain sites are:

North Bangkok Combined Cycle Block #1 situates at the site of the former

North Bangkok Thermal Power Plant, Bangkruai Subdistrict, Bangkruai District, Nonthaburi

Province.

- Base Load Plant

- 670 MW Contract Capacity

- Fuelled by Natural Gas

- Scheduled Commercial Operation Date (SCOD) in May 2010

- Approved by the Cabinet on 12 December 2006

19

Wang Noi Combined Cycle Block #4 is located in the same area as the existing

Wang Noi Power Plant, Khao Ngam and Wang Chula Subdistricts, Wang Noi District,

Phranakorn Sri Ayudhaya Province.

- Base Load Plant


- Fuelled by Natural Gas

- Environmental Impact Assessment (EIA) study based on 700 MW

capacity was approved by National Environment Board (NEB) on 19

September 2005. However, EGAT has to conduct further analysis due

to the expansion to 800 MW capacity.

- SCOD in June 2014

Chana Combined Cycle Block #2 is aimed to serve electrical demand in the

lower southern region. It is in the vicinity of the existing Chana Combined Cycle Block #1,

where the load center is.

- Base Load Plant


- Fuelled by Natural Gas from Thailand-Malaysia Joint Development

Area (JDA)

- SCOD in July 2014

Lam Takhong Pumped Storage Unit #3-4 is mounted 300 meters underneath

next to Lam Takhong Pumped Storage Unit #1-2 and planned to be online in June 2017. They

are all driven by water from existing Lam Takhong Reservoir of Royal Irrigation Department.

5.1.2 Power Purchase from IPPs: 4,400 MW

- GHECO-ONE Co., Ltd. (660 MW)

- Siam Energy Co., Ltd. #1-2 (2x800 MW)

- National Power Supply Co., Ltd. #1-4 (4x135 MW)

- Power Generation Supply Co., Ltd. #1-2 (2x800 MW)

On 27 June 2007, the Ministry of Energy (by Energy Policy and Planning Office,

EPPO) and the IPP Power Purchase Proposal Evaluation and Selection Subcommittee had

20

solicited the second round of potential bidders to supply power to EGAT in 2012-2014.

Considering the lowest levelized tariff, the Subcommittee later announced 4 winning bidders

consisting of:

Project No. Company Fuel

Contract Capacity

(MW) SCOD

1 GHECO-One Co., Ltd. Coal 660 Nov 2011

2 Siam Energy Co., Ltd. Gas 1,600 Mar – Sep 2013

3 National Power Supply Co., Ltd. Coal 540 Nov 2013 – Mar 2014

4 Power Generation Supply Co., Ltd. Gas 1,600 Jun – Dec 2014

Total 4,400

5.1.3 New Southern Power Plant: 800 MW

5.1.4 EGAT’s Renewable Energy: 239.2 MW

- Small Hydro Power Plants (187.4 MW)

- Solar Power Plants (1 MW)

- Wind Power Plants (46 MW)

- Municipal Solid Waste (MSW) Power Plants (7.5 MW)

5.1.5 Power Purchase from Small Power Producers (SPP): 3,539.5 MW

- Co-Generation System (3,224 MW)

- Renewable Energy (315 MW)

5.1.6 Power Purchase from Very Small Power Producers (VSPP): 2,249 MW

5.1.7 Power Purchase from Neighboring Countries: 5,668.6 MW

- Nam Theun 2, Lao PDR (920 MW)

- Nam Ngum 2, Lao PDR (596.6 MW)

- Theun Hinboun (Extension Phase), Lao PDR (220 MW)

- Hong Sa Lignite, Lao PDR (1,473 MW)

- Mai Khot, Myanmar (369 MW)

- Nam Ngum 3, Lao PDR (440 MW)

- Unspecified Projects (1,650 MW)

21

5.2 Generating Capacity in 2021-2030 Power projects coming online during this

period are to satisfy the country’s demand, though not yet assigned to particular sites. The

total added capacity of 32,411 MW can be categorized below.

- New Gas Fired Combined Cycle Power Plant (10,400 MW)

- New Clean Coal Thermal Power Plant (6,400 MW)

- New Nuclear Power Plant (4,000 MW)

- EGAT’s Renewable Energy Projects (96 MW)

- Power Purchase Projects from SPPs (3,800 MW)

- Power Purchase Projects from VSPPs (1,718 MW)

- Power Purchase Projects from Neighboring Countries (6,000 MW)

Quantity of the power purchase from neighboring countries shall be considered

upon the MOU made by the concerned parties.

Power Purchase from Lao PDR

The Government of Thailand and the Government of Lao PDR have signed a

number of Memoranda of Understanding (MOUs) to promote collaboration in power project

development in Lao PDR as followings:

- 4 June 1993 to import power up to 1,500 MW

- 19 June 1996 to extend import capacity to 3,000 MW

- 18 December 2006 to extend import capacity to 5,000 MW

- 22 December 2007 to extend import capacity to 7,000 MW

Currently, there are 2 commissioned projects namely Theun Hinboun (214 MW)

and Houay Ho (126 MW), and 3 PPA signed projects which are under construction, Nam

Theun 2 (920 MW), Nam Ngum 2 (597 MW) and Theun Hinboun - Extension Phase (220

MW). Besides, there are 2 Tariff MOU signed projects; Hong Sa (1,473 MW) and Nam Ngum

3 (440 MW).

Power Purchase from the Union of Myanmar On 4 July 1997, the Government of Thailand had made an MOU with the

Government of Myanmar. The essence of the MOU is to encourage power development in

Myanmar up to 1,500 MW to export to Thailand. Thereafter, on 30 May 2005, Governments

22

of the both countries proceeded on the subsequent MOU to develop hydroelectric projects in

Thanlwin river basin. Initially, there are 2 potential projects to sell electricity to Thailand.

(1) Hutgyi Hydroelectric Project (1,190 MW): expected to connect to EGAT

system at Tha Song Yang District, Tak Province

(2) Tasang Hydroelectric Project (7,000 MW): expected to connect to EGAT

system at Mae Eye District, Chiang Mai Province

The other Tariff MOU signed project is Mai Khot Coal Fired Thermal Power Plant

(369 MW totally).

Power Purchase from People’s Republic of China On 12 November 1998, the Government of Thailand and the Government of

People’s Republic of China (PRC) have entered into an MOU that Thailand will purchase

3,000 MW of electricity from projects in China proposed by PRC within the year 2017. Both

countries will cooperate in planning and constructing associated transmission systems as well

as negotiating with Lao PDR on right-of-way and wheeling charge issues.

Power Purchase from the Kingdom of Cambodia

There is no MOU between the Government of Thailand and the Government of

Cambodia. Nevertheless, there are private developers proposing to develop projects and sell

power to Thailand, for example, Koh Kong Coal Fired Power Project which is apportioned

into 2 phases, 1,800 MW each.

5.3 Renewable Energy

PDP 2010 contains 5,347.5 MW of electricity generated from renewable resources,

which can be divided into 2 periods.

The first period (2010-2022) offered 4,049.5 MW of EGAT owned and purchase

projects from SPPs and VSPPs. This amount was based on the Alternative Energy

Development Plan (2008-2022) of the Ministry of Energy (see Chapter 7, Item 7.1) and can be

tabulated in the next page.

23

Unit: MW Year EGAT SPP 1/ VSPP Total

2010 - 465.0 331.0 796.0

2011 38.0 425.0 236.0 699.0

2012 28.7 65.0 162.3 256.0

2013 54.0 - 181.0 235.0

2014 18.0 - 190.5 208.5

2015 14.0 90.0 165.0 269.0

2016 16.5 - 224.5 241.0

2017 10.5 - 227.5 238.0

2018 30.0 - 173.0 203.0

2019 7.5 - 170.0 177.5

2020 22.0 - 188.0 210.0

2021 60.5 - 133.0 193.5

2022 36.0 - 287.0 323.0

Total 335.7 1,045.0 2,668.8 4,049.5 Note: 1/ Include 730 MW of Non-firm SPPs

In the next period (2023-2030), 1,298 MW renewable capacity came from only

VSPPs which was estimated by MEA and PEA purchase plan.

Unit: MW

Year VSPP

2023 145.0

2024 146.0

2025 156.0

2026 157.0

2027 168.0

2028 168.0

2029 179.0

2030 179.0

Total 1,298.0

Details of installed and purchased capacity by energy source are elaborated in

Chapter 7.

24

5.4 Fuel Requirement

Fuel requirement for power generation according to PDP 2010 is tabulated below.

Year Lignite (M.Ton)

Coal (M.Ton)

Gas/LNG 1/ (MMCUFD

)

Heavy Oil

(M.Litre)

Diesel Oil

(M.Litre)

Nuclear (Ton)

2010 15.9 3.6 1,986 226.5 25.74 -

2011 16.4 4.2 2,003 66.0 9.30 -

2012 16.0 5.5 1,978 234.5 9.05 -

2013 16.4 5.5 1,907 364.1 22.73 -

2014 16.1 6.9 1,963 201.3 19.10 -

2015 17.2 7.0 1,862 - 7.20 -

2016 17.0 7.0 1,774 - 7.22 -

2017 16.0 7.0 1,843 - 7.00 -

2018 14.8 7.0 1,943 - 6.30 -

2019 15.1 8.2 1,955 - 6.30 -

2020 15.2 9.2 1,842 - 5.61 18.6

2021 15.2 10.4 1,702 - 5.60 37.1

2022 15.2 11.4 1,722 - 5.60 37.1

2023 15.2 13.6 1,711 - 5.60 37.1

2024 13.9 13.7 1,715 - 5.61 55.7

2025 11.8 13.6 1,755 - 5.60 74.1

2026 10.7 18.0 1,665 - 5.60 74.1

2027 10.7 18.0 1,767 - 5.60 74.1

2028 10.7 22.5 1,531 - 5.61 92.9

2029 8.9 24.6 1,598 - 5.60 92.6

2030 6.9 26.6 1,637 - 5.60 92.6 Note: 1/ Exclude SPP’s and VSPP’s consumption

The electricity generation by fuel type and the fuel requirement are classified in

Appendix 8.

25

Table 5.1Thailand Power Development Plan

PDP 2010Project Names Fuel Capacity Total Commissioning Date

Type (MW) (MW) VSPP - 367 367 January 2010

SPP (Renewables) - 90 90 June 2010

Power Purchase from Lao PDR (Nam Theun 2) Hydro 920 920 March 2010

North Bangkok CC #1 Gas 670 670 May 2010

SPP (Cogeneration) - 90 90 November 2010

VSPP - 258 258 January 2011

Power Purchase from Lao PDR (Nam Ngum 2) Hydro 597 597 January 2011

Chao Phraya Dam #1-2 Hydro 2x6 12 January 2011

EGAT Renewables - 18 18 January 2011


Naresuan Dam Hydro 8 8 October 2011

GHECO-ONE Co., Ltd. Coal 660 660 November 2011


Mae Klong Dam #1-2 Hydro 2x6 12 January 2012

Khun Dan Prakarnchon Dam Hydro 10 10 April 2012

Pasak Jolasid Dam Hydro 7 7 May 2012


SPP (Cogeneration) - 704 704 Jun 2012 - Dec 2012

Power Purchase from Lao PDR (Theun Hinboun Ext.) Hydro 220 220 July 2012


Kwae Noi Dam #1-2 Hydro 2x15 30 January 2013


SPP (Cogeneration) - 720 720 Mar 2013 - Sep 2013

Siam Energy Co., Ltd. #1-2 Gas 2x800 1,600 Mar 2013 - Sep 2013

National Power Supply Co., Ltd. #1-2 Coal 2x135 270 November 2013



National Power Supply Co., Ltd. #3-4 Coal 2x135 270 March 2014

Wang Noi CC #4 Gas 800 800 June 2014

SPP (Cogeneration) - 90 90 June 2014

Power Generation Supply Co., Ltd. #1-2 Gas 2x800 1,600 Jun 2014 - Dec 2014

Chana CC #2 Gas 800 800 July 2014

26

Table 5.1 (Continued)Thailand Power Development Plan




Bang Lang Dam (Renovate) Hydro 12 12 January 2015

Power Purchase from Lao PDR (Hongsa TH #1-2) Coal 2x491 982 May 2015 - Oct 2015



Power Purchase from Myanmar (Mai Khot TH #1-3) Coal 3x123 369 Jan 2016 - Jul 2016

Power Purchase from Lao PDR (Hongsa TH #3) Coal 491 491 February 2016

VSPP - 231 231 June 2016


New Capacity _ South Gas 800 800 July 2016



Power Purchase from Lao PDR (Nam Ngum 3) Hydro 440 440 January 2017

Lam Takhong Pumped Storage #3-4 Hydro 2x250 500 June 2017




SPP (Cogeneration) - 270 270 January 2018

Power Purchase from Neighbouring Countries - 450 450 June 2018





EGAT Clean Coal #1 Coal 800 800 June 2019




EGAT Nuclear Power Plant #1 Nuclear 1,000 1,000 January 2020


27







Power Purchase from Neighbouring Countries - 600 600 January 2021

EGAT Clean Coal #2 Coal 800 800 June 2021




EGAT Gas Fired CC #1 Gas 800 800 January 2022




EGAT Gas Fired CC #2-6 Gas 5x800 4,000 January 2023

EGAT Clean Coal #3 Coal 800 800 January 2023




EGAT Nuclear Power Plant TH #3 Nuclear 1,000 1,000 January 2024










EGAT Clean Coal #4-5 Coal 2x800 1,600 January 2026


28


PDP 2010Power Plant Project Names Fuel Capacity Total Commissioning Date









EGAT Clean Coal #6-7 Coal 2x800 1,600 January 2028











Total Installed Capacity as of December 2009 29,212 MW

Total Added Capacity 54,005 MW

Total Retired Capacity - 17,671 MW

Grand Total Capacity at the End of 2030 65,547 MW

29

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W;

VSPP

2

28.5

MW

; EG

AT R

ENEW

ABLE

S 1

0.5

MW

365.

0

GLO

W E

NER

GY

#1

(PPA

EN

D)

-90

MW

-90.

0

SPP

COG

EN

270

MW

; LA

M T

AKH

ON

G P

S #

3-4

500

MW

770.

0

GLO

W E

NER

GY

#2

(PPA

EN

D)

-90

MW

-90.

0

PEAK

GEN

ERA

TIO

N32

,225

.0M

W

MIN

IMU

M R

ESER

VE M

ARG

IN23

.2%

ADD

ITIO

NAL

CAP

ACIT

Y1,

449.

0M

W

RETI

RED

CAP

ACIT

Y-4

94.0

MW

NET

CAP

ACIT

Y IN

YEA

R95

5.0

MW

TOTA

L CA

PACI

TY42

,373

.9M

W

SPP

COG

EN

270

MW

; VS

PP

176

MW

; EG

AT R

ENEW

ABLE

S

30 M

W-1

63.0

TPT

UTI

LITY

(PP

A EN

D)

-9.

5 M

W-9

.5

PTT

CHEM

ICAL

(PP

A EN

D)

-32

MW

-32.

0

POW

ER I

MPO

RT

450

MW

450.

0PE

AK G

ENER

ATI

ON

33,6

88.0

MW

MIN

IMU

M R

ESER

VE M

ARG

IN17

.3%

ADD

ITIO

NAL

CAP

ACIT

Y92

6.0

MW

RETI

RED

CAP

ACIT

Y-6

80.5

MW

NET

CAP

ACIT

Y IN

YEA

R24

5.5

MW

TOTA

L CA

PACI

TY42

,619

.4M

W

SPP

COG

EN

270

MW

; VS

PP

177

MW

; EG

AT R

ENEW

ABLE

S

7.5

MW

454.

5

MIL

ITAR

Y FA

NG

(PP

A EN

D)

-4.

5 M

W;

EGAT

CLE

AN C

OAL

TH

#1

800

MW

; PO

WER

IM

PORT

60

0 M

W1,

395.

5

GU

LF C

OG

ENER

ATIO

N (P

PA E

ND

) -

90 M

W;

AMAT

A EG

CO P

OW

ER (

PPA

END

) -

90 M

W-1

80.0

PEAK

GEN

ERA

TIO

N34

,988

.0M

W

MIN

IMU

M R

ESER

VE M

ARG

IN15

.0%

ADD

ITIO

NAL

CAP

ACIT

Y1,

854.

5M

W

RETI

RED

CAP

ACIT

Y-1

84.5

MW

NET

CAP

ACIT

Y IN

YEA

R1,

670.

0M

W

TOTA

L CA

PACI

TY44

,289

.4M

W

EGAT

NU

CLEA

R #

1 1

000

MW

; SP

P CO

GEN

27

0 M

W;

VSPP

19

0 M

W;

EGAT

REN

EWAB

LES

22

MW

841.

0BA

NG

KOK

COG

EN (

PPA

END

) -

90 M

W-9

0.0

BPK

POW

ER S

UPP

LY (

PPA

END

)

-8 M

W-8

.0TE

CO (

PPA

END

)

-700

MW

; PO

WER

IM

PORT

6

00 M

W-1

00.0

SAM

UT P

RAKA

RN C

OG

EN (

PPA

END

) -

90 M

W-9

0.0

PEAK

GEN

ERA

TIO

N36

,336

.0M

W

MIN

IMU

M R

ESER

VE M

ARG

IN15

.6%

ADD

ITIO

NAL

CAP

ACIT

Y2,

082.

0M

W

RETI

RED

CAP

ACIT

Y-1

,529

.0M

W

NET

CAP

ACIT

Y IN

YEA

R55

3.0

MW

TOTA

L CA

PACI

TY44

,842

.4M

W

100

0020

000

300

0040

000

500

0060

000

7000

080

000

9000

01

0000

011

0000

PEAK

GEN

ERA

TIO

N

PEAK

GEN

ERA

TIO

N +

15%

DEP

END

ABL

E CA

PACI

TY

SPP

(BAN

G P

A-IN

)

90 M

W;

SPP

(RO

JAN

A PO

WER

2)

90

MW

; SP

P (A

MAT

A PO

WER

) 9

0 M

W;

VSPP

16

7 M

W;

EGAT

REN

EWAB

LES

14

MW

; BA

NG

LAN

G D

AM (

REN

OVA

TE)

12

MW

PPB

TH #

2 (P

PA E

ND

) -

70.2

MW

; SP

P CO

GEN

27

0 M

W;

VSPP

23

0.5

MW

BAN

G P

AKO

NG

CC

#3

(RET

IRE)

-3

14 M

W;

BAN

G P

AKO

NG

CC

#4

(RET

IRE)

-3

14 M

W;

NAM

PHO

NG

CC#

1 (R

ETIR

E)

-325

MW

;

NAM

PHO

NG

CC#

2 (R

ETIR

E)

-325

MW

; SO

UTH

BAN

GKO

K CC

#1

(RET

IRE)

-3

16 M

W;

31

PO

WER

DEV

ELO

PM

ENT

PLA

NPD

P201

0_Ba

se L

oad

GEN

ERAT

ION

SYS

TEM

DEV

ELO

PMEN

T PL

ANN

ING

DEP

ARTM

ENT

LOAD

FO

RECA

ST :

23

Feb

2010

SYST

EM P

LAN

NIN

G D

IVIS

ION

RUN

DAT

E :

Mar

ch 2

5, 2

010

ELEC

TRIC

ITY

GEN

ERAT

ING

AU

THO

RITY

OF

THAI

LAN

D

PEA

K A

ND

CA

PA

CIT

Y (

MW

)

MW

29,2

12.0

EXIS

TIN

G C

AP

AC

ITY

1000

020

000

3000

040

000

5000

06

0000

700

0080

000

9000

010

000

011

000

0

FIGURE 5.1 THAILAND POWER DEVELOPMENT PLAN (PDP 2010) (continued)

JAN

2021

FEB

MA

RA

PRM

AY

JUN

JUL

AU

GS

EPO

CT

NO

VD

ECJA

N20

22FE

BM

AR

APR

MA

YJU

NJU

LA

UG

SEP

OC

TN

OV

DEC

JAN

2023

FEB

MA

RA

PRM

AY

JUN

JUL

AU

GS

EPO

CT

NO

VD

ECJA

N20

24FE

BM

AR

1000

020

000

3000

04

0000

500

0060

000

7000

080

000

9000

010

000

011

0000

EGAT

REN

EWAB

LES

60.

5 M

W2,

175.

5G

LOW

SPP

#1

PRO

JECT

#1

(PPA

EN

D)

-55

MW

-55.

0

EGAT

CLE

AN C

OAL

TH

#2

80

0 M

W80

0.0

GLO

W S

PP #

1 PR

OJE

CT #

2 (P

PA E

ND

) -

55 M

W-5

5.0

NO

NG

KH

AE C

OG

EN (

PPA

END

) -

90 M

W-9

0.0

PEAK

GEN

ERAT

ION

37,8

56.0

MW

MIN

IMU

M R

ESER

VE M

ARG

IN15

.4%

ADD

ITIO

NAL

CAP

ACIT

Y2,

975.

5M

W

RETI

RED

CAP

ACIT

Y-2

00.0

MW

NET

CAP

ACIT

Y IN

YEA

R2,

775.

5M

W

TOTA

L CA

PAC

ITY

47,6

17.9

MW

SPP

COG

EN

360

MW

; VS

PP

294

MW

; EG

AT R

ENEW

ABLE

S 3

6 M

W1,

514.

0

LAEM

CH

ABAN

G P

OW

ER (

PPA

END

) -

60 M

W-6

0.0

AMAT

A PO

WER

(BP

K) (

PPA

END

)

-90

MW

-90.

0

PEAK

GEN

ERAT

ION

39,3

08.0

MW

MIN

IMU

M R

ESER

VE M

ARG

IN16

.0%

ADD

ITIO

NAL

CAP

ACIT

Y2,

090.

0M

W

RETI

RED

CAP

ACIT

Y-7

26.0

MW

NET

CAP

ACIT

Y IN

YEA

R1,

364.

0M

W

TOTA

L CA

PAC

ITY

48,9

81.9

MW

EGAT

GAS

FIR

ED C

C #

2-6

400

0 M

W;

PO

WER

IM

PORT

6

00 M

W;

SPP

COG

EN

360

MW

; VS

PP

146

MW

2,64

4.0

EAST

ERN

PO

WER

(PP

A EN

D)

-3

50 M

W;

THAI

OIL

PO

WER

(PP

A EN

D)

-41

MW

-391

.0

PEAK

GEN

ERAT

ION

40,7

81.0

MW

MIN

IMU

M R

ESER

VE M

ARG

IN16

.7%

ADD

ITIO

NAL

CAP

ACIT

Y5,

906.

0M

W

RETI

RED

CAP

ACIT

Y-3

,653

.0M

W

NET

CAP

ACIT

Y IN

YEA

R2,

253.

0M

W

TOTA

L CA

PAC

ITY

51,2

34.9

MW

EGAT

NU

CLEA

R #

3 1

000

MW

; PO

WER

IM

PORT

60

0 M

W;

SPP

COG

EN

360

MW

; VS

PP

148

MW

1,96

8.0

TLP

COG

ENER

ATIO

N (P

PA E

ND

) -

60 M

W-6

0.0

NAT

ION

AL P

OW

ER S

UPPL

Y 1

(PPA

EN

D)

-90

MW

-90.

0G

LOW

SPP

#2

PRO

JECT

#1

(PPA

EN

D)

-60

MW

-60.

0SA

HA

CO

GEN

(PP

A E

ND

) -9

0 M

W;

THAI

PO

WER

SU

PPLY

#1

(PPA

EN

D)

-4

1 M

W;

GLO

W S

PP #

2 PR

OJE

CT

#2

(PPA

EN

D)

-

-191

.0RO

JAN

A PO

WER

(PP

A EN

D)

-90

MW

; RO

I ET

GR

EEN

(PP

A EN

D)

-8.

8 M

W-9

8.8

NAT

ION

AL P

OW

ER S

UPPL

Y 2

(PPA

EN

D)

-90

MW

-90.

0

GLO

W S

PP #

3 PR

OJE

CT #

1 (P

PA E

ND

) -

90 M

W-9

0.0

POW

ER IM

PORT

60

0 M

W;

SPP

COG

EN

360

MW

; VS

PP

163

MW

2,64

3.0

GLO

W S

PP #

3 PR

OJE

CT #

2 (P

PA E

ND

) -

90 M

W-9

0.0

DAN

CH

ANG

BIO

EN

ERG

Y (P

PA E

ND

) -

27 M

W-2

7.0

PHU

KEA

W B

IO E

NER

GY

(PPA

EN

D)

-29

MW

; IN

DEP

END

ENT

POW

ER (

THAI

LAN

D)

(PPA

EN

D)

-700

MW

-729

.0TH

AI N

ATIO

NAL

PO

WER

(PP

A EN

D)

-90

MW

; SU

GAR

MIT

R KA

LASI

N (

PPA

END

) -

8 M

W-9

8.0

RATC

HAB

URI T

H #

1-2

(PPA

EN

D)

-14

40 M

W-1

,440

.0

POW

ER IM

PORT

60

0 M

W;

SPP

COG

EN

360

MW

; VS

PP

159

MW

4,17

9.0

BIO

MAS

S PO

WER

(PP

A EN

D)

-5

MW

-5.0

EGAT

GAS

FIR

ED C

C #

10

800

MW

; PO

WER

IMPO

RT

600

MW

; SP

P CO

GEN

36

0 M

W;

VSPP

16

9 M

W1,

929.

0M

UNG

CH

ARO

EN G

REEN

PO

WER

(PP

A EN

D)

-8

MW

; SA

TUK

BIO

MAS

S (P

PA E

ND

) -

6.5

MW

-14.

5

RATC

HAB

URI C

C #

1-2

(PPA

EN

D)

-13

60 M

W-1

,360

.0

RATC

HAB

URI C

C #

3 (P

PA E

ND

) -

681

MW

-681

.0

EGAT

CLE

AN C

OAL

TH

#6-

7 1

600

MW

; EG

AT G

AS

FIR

ED C

C #

11-1

2 16

00 M

W;

SPP

CO

GEN

36

0 M

W;

VSPP

1

73

5,31

3.0

GLO

W I

PP (

PPA

END

) -

713

MW

-713

.0

ADVA

NCE

AG

RO #

1 (P

PA E

ND

) -

50 M

W-5

0.0

ADVA

NCE

AG

RO #

2 (P

PA E

ND

) -

25 M

W-2

5.0

2,46

9.0

1,72

3.0

APR

MA

YJU

NJU

LA

UG

SEP

OC

TN

OV

DEC

JAN

2025

FEB

MA

RA

PRM

AY

JUN

JUL

AU

GS

EPO

CT

NO

VD

ECJA

N20

26FE

BM

AR

APR

MA

YJU

NJU

LA

UG

SEP

OC

TN

OV

DEC

JAN

2027

FEB

MA

RA

PRM

AY

JUN

JUL

AU

GS

EPO

CT

NO

VD

ECJA

N20

28FE

BM

AR

APR

MA

YJU

NJU

LA

UG

SEP

OC

TN

OV

DEC

JAN

2029

FEB

MA

RA

PRM

AY

JUN

JUL

AU

GS

EPO

CT

NO

VD

ECJA

N20

30FE

BM

AR

APR

MA

YJU

NJU

LA

UG

SEP

OC

TN

OV

DEC

PEAK

GEN

ERAT

ION

42,2

36.0

MW

MIN

IMU

M R

ESER

VE M

ARG

IN16

.5%

ADD

ITIO

NAL

CAP

ACIT

Y2,

108.

0M

W

RETI

RED

CAP

ACIT

Y-8

19.8

MW

NET

CAP

ACIT

Y IN

YEA

R1,

288.

2M

W

TOTA

L CA

PAC

ITY

52,5

23.1

MW

PEAK

GEN

ERAT

ION

43,9

62.0

MW

MIN

IMU

M R

ESER

VE M

ARG

IN16

.3%

ADD

ITIO

NAL

CAP

ACIT

Y2,

923.

0M

W

RETI

RED

CAP

ACIT

Y-2

,664

.0M

W

NET

CAP

ACIT

Y IN

YEA

R25

9.0

MW

TOTA

L CA

PAC

ITY

52,7

82.1

MW

PEAK

GEN

ERAT

ION

45,6

21.0

MW

MIN

IMU

M R

ESER

VE M

ARG

IN15

.9%

ADD

ITIO

NAL

CAP

ACIT

Y4,

319.

0M

W

RETI

RED

CAP

ACIT

Y-1

45.0

MW

NET

CAP

ACIT

Y IN

YEA

R4,

174.

0M

W

TOTA

L CA

PAC

ITY

56,9

56.1

MW

PEAK

GEN

ERAT

ION

47,3

44.0

MW

MIN

IMU

M R

ESER

VE M

ARG

IN15

.4%

ADD

ITIO

NAL

CAP

ACIT

Y1,

929.

0M

W

RETI

RED

CAP

ACIT

Y-2

,055

.5M

W

NET

CAP

ACIT

Y IN

YEA

R-1

26.5

MW

TOTA

L CA

PAC

ITY

56,8

29.6

MW

PEAK

GEN

ERAT

ION

49,0

39.0

MW

MIN

IMU

M R

ESER

VE M

ARG

IN16

.3%

ADD

ITIO

NAL

CAP

ACIT

Y5,

333.

0M

W

RETI

RED

CAP

ACIT

Y-8

08.0

MW

NET

CAP

ACIT

Y IN

YEA

R4,

525.

0M

W

TOTA

L CA

PAC

ITY

61,3

54.6

MW

PEAK

GEN

ERAT

ION

50,9

59.0

MW

MIN

IMU

M R

ESER

VE M

ARG

IN16

.3%

ADD

ITIO

NAL

CAP

ACIT

Y2,

739.

0M

W

RETI

RED

CAP

ACIT

Y-2

70.0

MW

NET

CAP

ACIT

Y IN

YEA

R2,

469.

0M

W

TOTA

L CA

PAC

ITY

63,8

23.6

MW

PEAK

GEN

ERAT

ION

52,8

90.0

MW

MIN

IMU

M R

ESER

VE M

ARG

IN15

.0%

ADD

ITIO

NAL

CAP

ACIT

Y2,

119.

0M

W

RETI

RED

CAP

ACIT

Y-3

96.0

MW

NET

CAP

ACIT

Y IN

YEA

R1,

723.

0M

W

TOTA

L CA

PAC

ITY

65,5

46.6

MW

PEAK

GEN

ERAT

ION

PEAK

GEN

ERAT

ION

+ 1

5%

DEP

END

ABLE

CAP

ACIT

Y

EGAT

NU

CLEA

R #

2 1

000

MW

; PO

WER

IM

PORT

6

00 M

W;

SPP

COG

EN

380

MW

; VS

PP

135

MW

;

BAN

G P

AKO

NG

TH

#3

(RET

IRE)

-5

76 M

W;

EGAT

GAS

FIR

ED C

C #

1

800

MW

; P

OW

ER I

MPO

RT

600

MW

;

WAN

G N

OI

CC #

1-3

(RET

IRE)

-1

910

MW

; SO

UTH

BAN

GKO

K CC

#2

(RET

IRE)

-5

62 M

W;

BAN

G P

AKO

NG

TH

#4

(RET

IRE)

-57

6 M

W;

THEU

N H

INBO

UN (

PPA

END

) -

214

MW

; EG

AT C

LEAN

CO

AL T

H #

3 8

00 M

W;

MAE

MO

H T

H #

4 (R

ETIR

E)

-140

MW

;

MAE

MO

H T

H #

5-6

(RET

IRE)

-2

80 M

W;

EGAT

NUC

LEAR

#4

100

0 M

W;

EGAT

GAS

FIR

ED C

C #

7 8

00 M

W;

MAE

MO

H T

H #

7 (R

ETIR

E)

-140

MW

; EG

AT C

LEAN

CO

AL T

H #

4-5

160

0 M

W;

EGAT

GAS

FIR

ED C

C #

8-9

16

00 M

W;

KHO

NKA

EN S

UG

AR P

OW

ER (

PPA

END

)

-20

MW

; EG

AT N

UCLE

AR #

5

1000

MW

; PO

WER

IM

PORT

60

0 M

W;

POW

ER IM

PORT

60

0 M

W;

SPP

COG

EN

360

MW

; VS

PP

179

MW

MAE

MO

H T

H #

8 (R

ETIR

E)

-270

MW

; EG

AT C

LEAN

CO

AL T

H #

8 8

00 M

W;

EGAT

GAS

FIR

ED C

C #

13

800

MW

;

EGAT

CLE

AN C

OAL

TH

#9

800

MW

; PO

WER

IM

PORT

60

0 M

W;

SPP

COG

EN

540

MW

; VS

PP

179

MW

MAE

MO

H T

H #

9 (R

ETIR

E)

-270

MW

; H

OUA

Y H

O (

PPA

END

) -

126

MW

;

33

6. Demand Side Management (DSM)

Demand Side Management, in other words, Promotion of Electricity Energy

Efficiency is an approach occurring and widespread in the United States of America in 1970s

amid the world energy crisis inducing the world to realize that the production of energy to

meet demand without the concern of energy efficiency would cause many problems such as

energy resource depletion, environmental problems by fuel combustion, etc. Hence, the

promotion of energy efficiency concept has seriously been researched and published to the

public of various actions for effective implementations. It might be said that DSM is an

alternative for power generation and transmission system planning. Incidentally, Thailand is

the first country in Southeast Asia that has launch DSM program tangibly.

Electricity management in Thailand was basically classified into 2 aspects 1)

Supply-Side Management: the planning, construction and provision of power generation to

meet power demand for customers and 2) Demand-Side Management: the measures to adjust

volume and/or characteristics of electricity consumption (End-use). The two main purposes of

this electricity management are 1) to balance demand-side with supply-side by efficient

technologies or by load pattern adjustment for optimal peak load or peak demand and 2) to

strengthen and promote energy conservation.

DSM programs and measures aim to promote and support target groups of

customers to improve their electricity consumption to conform the power supply of electricity

industry with the remaining of customer benefits and satisfaction or the better, for instance,

reducing the costs of both electricity industry and customers, lowering investment cost of

power plant and transmission system construction, and diminishing environmental impacts of

power program development and power generation development.

6.1 Evaluation of Energy Saving by DSM Programs

Presently, electricity saving (energy saving in general) by DSM program can not

be clearly assessed because DSM programs are just programs that promote and support

customers to optimize their benefits of electricity consumption behavior. However, if DSM

programs’ energy saving is considered for PDP arrangement – with subtraction of the

expected energy saved by DSM programs from the load forecast – the such considered DSM

programs must be the new one with high potential of success, and the expected energy saved

35

by DSM programs has been already excluded from the appliance energy efficiency

improvement portion of the Load Forecast model since an energy saved by each DSM

program cannot be exactly evaluated. Only the number of appliances, produced by

manufacturers, distributed to markets each year, and the average electricity saved by each

type of appliance are estimated from DSM program. Additionally, all new appliances

delivered from manufacturers to markets for replacement are not in use synchronously, so

energy saving target of DSM programs seems to be out of reach. Therefore, before subtraction

of the expected energy saved by DSM programs from the appliance energy efficiency

improvement portion of the load forecast, the energy saving target of DSM programs must be

reduced by the involvement in electricity saving probability, electricity saving potential,

electricity consumptions, and duration. The expected energy saved by DSM programs must

not be included in the appliance energy efficiency improvement portion of the Load Forecast

model in order to avoid the over deduction – of the saving of DSM programs from future

power demand forecast – that will cause an error or incorrect load forecast, inducing

insufficient power capacity provided to meet the future power demand.

6.2 DSM Program Consideration

To adjust power demand forecast accurately and appropriately, DSM programs

having been launched and already exist in the appliance energy efficiency improvement

portion of Load Forecast model are not taken into account for this load forecast – for

example, T8 fluorescent lamp program and Label No.5 program (Air conditioner,

Refrigerator) the energy saving of these two programs are not taken into account into the

appliance energy efficiency improvement portion of this load forecast because the energy

saving of such two programs are hidden under electricity consumption of the Load Forecast

model, in other words this Load Forecast model has already contained electricity saving

growth rate of these DSM programs. Thus, new DSM programs similar to the Label No.5

program are considered already exist in the appliance energy efficiency improvement portion

of the Load Forecast models, and then new Label No. 5 energy saving target can not be

subtracted from this power demand forecast.

Hence, the energy saved by DSM programs to be subtracted from power demand

forecast must be the one from new DSM programs or new-appliance programs influencing

customer electricity consumption behavior nationwide with replacement the old appliances by

the new and higher efficiency ones that have never been on the market before, such as

36

replacing T8 fluorescent lamps with new T5 fluorescent lamps program – this is only a

program that its expected energy saved for subtraction form power demand forecast is

applied. The purpose of the T5 program is to reduce electricity consumption of business and

industrial sectors in order to reduce power demand of the country in terms of peak demand

and energy.

6.3 Reduction of Energy Saving Target by Electrical Usage Characteristic of Appliances

For energy saving target evaluation of DSM programs, it does not reflex a true

picture to assume that all new appliances delivered from manufacturers to markets are in use

synchronously (some appliances are in use and some are not). Thus, the study of appliance

operation probability and appliance operation duration is required. The study of electricity

consumption behavior of each appliance is also necessary to be carried out for receiving

necessary load profile information, in order to determine how much percentage of all energy

required of each appliance at peak period.

Criteria of DSM Programs for Electricity Demand Forecast Deduction 1. The programs must not be continuous programs, for example, energy efficiency

improvement programs that are already included in Load Forecast model.

2. The programs must be new programs that affect electricity consumption

behavior. Up to this time, only the energy saved from T5 fluorescent lamp program promoted

can be subtracted from power demand forecast.

3. In the future, when the short-term DSM program promoting plan ends,

additional DSM programs should be promoted for continuity of efficient electricity

consumption.

6.4 DSM Program for Power Demand Forecast Adjustment

1. The Promotion of New T5 Fluorescent Lamp Program (T8 Fluorescent Lamp Replacement Program)

Program Target: To promote new T5 fluorescent lamps to replace old T8

fluorescent lamps, especially in business and industrial sectors, amounting 83 million lamps

within 2015.

37

Implementation Guidelines: Encouraging both new and old commercial

buildings and industrial buildings to use new T5 fluorescent lamps with financial assistance of

two-years loan provision from EGAT without interest.

Table 6.1 Energy Saving Target of New T5 Fluorescent Lamp Program (Accumulated)

Year 2010 2011 2012 2013 2014 2015 2016 2017 2018

Peak (MW) 43 129 215 344 473 584 498 369 198

Energy (MWh) 210 629 1049 1,678 2,307 2,852 2,433 1,804 965

Source: EPPO

2. Future Energy Saving Target of DSM Programs

DSM program of the new T5 fluorescent lamp program promotion will end in

2018. However, EGAT has already planned further energy saving target of new programs for

the future. The expectation of energy saving rate of 2019 should be trended to improve greater

than that of 2018 of around 21 percent – an average growth of energy saving rate of 2010 to

2018. It is also anticipated that after 2019 the energy saving rate is kept constant throughout

the forecast period. Therefore, during 2019 to 2030, the load forecast of peak demand and

energy demand are approximately reduced by 240 MW per year and 1,170 MWh per year

respectively.

38

7. Renewable Energy

7.1 The 15 Years Alternative Energy Development Plan of the Ministry of Energy

At present, Thailand imports variety forms of energy which worth many millions

Baht. The energy crisis in the past few years has caused energy prices rising up and affected

economic development countrywide. This was because energy is a major economic driving

factor. The crisis also made us realize that energy from some fossil fuels (i.e. oil, natural gas,

etc.) is running out. Therefore, the Ministry of Energy has come up with a policy to develop

the renewable energy (RE) and released the Alternative Energy Development Plan (AEDP)

for a fifteen years period (2008–2022). The objective of AEDP is to increase the portfolio of

renewable energy to 20.3 % of the final energy consumption in 2022. At the end of the plan,

the portion of renewable energy in power generation shall be 2.4% or 5,608 MW. The 15

Years ADEP can be separated into three terms as followings:

(1) Short Term (2008–2011): To promote viable renewable technologies with

high potential resources. The cumulative target to develop the renewable energy during this

period is 3,273 MW or equivalent to 1,587 ktoe.

(2) Medium Term (2012–2016): To promote renewable technology industry

and prototype development of renewable technologies in order to enhance their economic

return on investment. It is also to promote the use of any new technologies, which can

strengthen power generation from alternative energy resources at community level. The

cumulative target to develop the renewable energy during this period is 4,191 MW or

equivalent to 1,907 ktoe.

(3) Long Term (2017–2022): To promote novel renewable technologies with

feasible investment and to extend their practice as distributed generation to local areas. The

cumulative target to develop the renewable energy during this period is 5,608 MW or

equivalent to 2,290 ktoe.

Details can be seen in Appendix 9.

39

7.2 EGAT’s Renewable Energy Projects

The Electricity Generating Authority of Thailand (EGAT) has developed

renewable energy for power generation since 1978. At the beginning, the projects were

majorly relevant to Research and Development (R&D) of generation system prototypes for all

entities involved. Thereafter, they were extended to the public development practices. To

date, EGAT has several generating units of renewable energy such as Wind Turbine Power

Plant at Lam Takhong, Wind Turbine Power Plant at Promthep Alternative Energy Station,

Solar Power Plant at Pha Bong, and Solar Power Plant at Sirindhorn dam. Furthermore,

EGAT has been developing a number of small hydropower projects at existing dams of the

Royal Irrigation Department (RID) since 2004. The main purpose of the projects is to

maximize the utilization of water resource with hydropower generation.

To pursue EGAT’s renewable energy development and to response to the policy of

the Ministry of Energy, EGAT prepared its Renewable Energy Development Plan for Power

Generation (Preliminary Plan) considering 4 renewable resources suitable for EGAT, i.e.

wind energy, solar energy, small hydropower at existing RID dams and biomass.

This preliminary plan took into accounts the practical possibility, impacts over

electricity tariff, public concerns and the Government’s investment including:

1. Generation cost

2. Dependence on foreign technologies and investment

3. Environmental impacts and public concerns

4. Conditions and constraints on connection to the power grid

5. Dependable capacity

6. Potential of project sites

It designated not only commercially feasible power generation from renewable

energy, whose production cost is not higher than the sum of average bulk tariff plus the

Government’s Adder Subsidy, but also semi research prototype projects that promote clean

energy according to Corporate Social Responsibility (CSR) policy and enable the assessment

of each technology’s actual capability. The plan is still under detailed study and subject to be

further amended. It can also be divided into three periods as tabulated in the next page and

more information is elaborated in Appendix 9.

40

Table 7.1 Generating Capacity in EGAT’s Renewable Energy Development Plan

Unit: MW

Short Term (2008–2011)

Medium Term (2012–2016)

Long Term (2017–2022) Total

Small Hydro 48.7 86.0 59.0 193.7

Wind Energy 20.5 19.0 89.0 128.5

Solar Energy 1.0 0.5 0.5 2.0

Municipal Solid Waste (MSW) - 7.5 7.5 15.0

Total 70.2 113.0 156.0 339.2

7.3 Small Power Producers Using Renewable Energy

Small Power Producers (SPPs) are private power producers selling electricity to

EGAT. Their generating capacity is 10–90 MW and employ Combined Heat and Power

(CHP) or Cogeneration systems burning conventional fuels (i.e. natural gas and coal) or

renewable technologies using non-conventional resources (i.e. waste, agricultural residues,

biomass and solar energy) in electricity generation.

The power purchase from SPPs was originated in 1992. The Cabinet endorsed the

initial Regulations for the Purchase of Power from SPPs on 17 March 1992. Later, on 27

October 1993, the National Energy Policy Council (NEPC) had a resolution to raise

maximum contract capacity of each SPP to 90 MW. On 28 November 1995, the Cabinet

agreed to expand the total purchased capacity from SPPs to 1,444 MW and 3,200 MW in

1995 and 1996, respectively. Thereafter, on 9 July 1996, the Cabinet approved the unlimited

purchase capacity and duration from SPPs that generate power from non-conventional

resources such as biomass or residues. Besides, the “Adder” incentive scheme has been

commenced in 2007 to encourage power generation harnessing renewable resources.

According to PDP 2010, the total purchase capacity from SPPs using renewable

technologies during 2010–2015 is 1,045 MW comprising 315 MW of Firm Contracts and 730

MW of Non-Firm Contracts. Details are displayed in Table 7.2.

As of January 2010, the contract capacity of 35 potential SPPs using renewable

energy was 902.923 MW consisting of 395.3 MW Firm Contracts (18 projects) and 507.623

MW Non-Firm Contracts (17 projects).

41

Table 7.2 Purchase Capacity from SPPs Using Renewable Technologies

Unit: MW Fuel Type 2010 2011 2012 – 2015 Total

SPP – Firm Contract Biomass 90 160 65 315

SPP – Non-Firm Contract Biomass 29 - - 29 Biogas 6 - - 6 Solar Energy - 85 90 175 Wind Energy 340 180 - 520

Total 465 425 155 1,045

However, there were only 26 commissioned projects with a total capacity of

384.923 MW including 17 Firm Contracts (305.3 MW) and 9 Non-Firm Contracts (79.623

MW). The other 9 upcoming projects were composed of 1 Firm Contract (90 MW) and 8

Non-Firm Contracts (428.0 MW). Details are attached in Appendix 9.

7.4 Very Small Power Producers Using Renewable Energy

Very Small Power Producers (VSPPs) are private power producers selling

electricity to the Metropolitan Electricity Authority (MEA) or the Provincial Electricity

Authority (PEA) with generating capacity of less than 10 MW. They can be Combined Heat

and Power (CHP) or Cogeneration systems or renewable technologies using non-conventional

resources (i.e. waste, agricultural residues, biomass, and solar energy).

In 2002, the Government of Thailand introduced policies to promote power

generation from non-conventional resources and renewable energy with a very small capacity

of not greater than 1 MW selling electricity to power distribution utilities.

Considering the advancements and high potential of renewable technologies, it

was found that VSPPs using renewable energy are also feasible for the generating capacity

greater than 1 MW. As a result, NEPC agreed to enlarge VSPP’s contract capacity from 1

MW to 10 MW on 4 September 2006. As well as SPPs using renewable technologies, all

VSPPs are applicable to the “Adder” scheme.

42

It was anticipated that power generation from renewable energy will increase

dramatically and be strategically important to the sustainable development of the country.

Consequently, PDP 2010 took much more involve in this matter than the previous PDPs did.

The following considerations are how to cooperate VSPPs in the plan.

− The Period of 2010–2022: The purchased capacity from VSPPs using

renewable energy was framed upon the 15 Years AEDP of the Ministry of Energy. The total

capacity operated by EGAT, SPPs and VSPPs in each year is not less than that allocated in

the AEDP. VSPPs selling power to PEA in 2010–2013 are listed in Appendix 9. The available

projects are:

1. Projects that are completely constructed and awaiting the Electricity

Generating License,

2. Projects that are under construction, and

3. Projects that already submitted security against their electricity selling

proposal

− The Period of 2023–2030: The purchased capacity from VSPPs using

renewable energy is according to the projection of distribution power utilities. The percentage

of electrical energy from renewable technologies is targeted at not less than 5% of the total

production in 2030.

As of December 2009, there were 159 VSPPs using renewable energy with the

total capacity of 350.3 MW connected to distribution utilities. It can be differentiated by fuel

type as followings: 51 solar energy projects (7.8 MW), 41 biogas projects (43.0 MW), 53

biomass projects (287.8 MW), 8 MSW projects (10.8 MW), 3 small hydro projects (0.5 MW),

and 3 wind energy projects (0.4 MW). Details can be seen in Appendix 9.

43

Table 7.3 Purchase Capacity from VSPPs Using Renewable Technologies

Unit: MW

Year Biomass Biogas Solar MSW Wind Small-Hydro Total

2010 235.0 20.0 5.0 44.0 - 27.0 331.0

2011 186.0 17.0 6.0 20.0 50.0 2.0 236.0

2012 44.0 9.0 27.0 20.0 60.0 2.0 162.0

2013 100.0 4.0 34.0 8.0 35.0 - 181.0

2014 50.0 6.0 50.0 10.0 47.5 27.0 190.5

2015 50.0 7.0 50.0 6.0 50.0 2.0 165.0

2016 120.0 4.0 50.0 0.5 50.0 - 224.5

2017 80.0 10.0 50.0 5.0 73.5 9.0 227.5

2018 50.0 7.0 50.0 5.0 61.0 - 173.0

2019 40.0 5.0 50.0 5.0 70.0 - 170.0

2020 60.0 3.0 50.0 5.0 70.0 - 188.0

2021 60.0 3.0 50.0 - 20.0 - 133.0

2022 190.0 2.0 50.0 5.0 40.0 - 287.0

2023 80.0 3.0 50.0 3.0 9.0 - 145.0

2024 80.0 3.0 50.0 3.0 10.0 - 146.0

2025 90.0 3.0 50.0 3.0 10.0 - 156.0

2026 90.0 3.0 50.0 3.0 11.0 - 157.0

2027 100.0 3.0 50.0 3.0 12.0 - 168.0

2028 100.0 3.0 50.0 3.0 12.0 - 168.0

2029 110.0 3.0 50.0 3.0 13.0 - 179.0

2030 110.0 3.0 50.0 3.0 13.0 - 179.0

Total 2,025.0 121.0 922.0 157.5 672.0 69.3 3,966.8

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8. Cogeneration System

8.1 Small Power Producer Using Cogeneration System

On 16 January 2007, the Cabinet endorsed the NEPC’s resolution on 26 December

2006 which extended the capacity of all SPPs from 3,200 MW to 4,000 MW. EGAT then

announced to purchase 500 MW of electricity from cogeneration SPPs under Firm Contract.

There were 28 tenders with 2,191 MW, which was much above the announced capacity. As a

result, on 31 August 2007, NEPC had EGAT pause receiving the proposal from such SPP

projects. On 16 November 2007, NEPC eventually agreed to let the purchased power from

cogeneration SPPs exceed 500 MW, but cumulatively not more than 4,000 MW.

On 24 August 2009, NEPC had a resolution to promote power generation by

cogeneration system. This program was later approved by the Cabinet on 8 September 2009.

Its goal is to receive power from Cogeneration SPPs under Firm Contract up to 2,000 MW in

2015 – 2021 and more in the future years, as described in PDP 2010 and summarized below.

− The Period of 2010–2014: The purchased capacity from Firm and Non-Firm

Contract SPPs is 1,604 MW and 40 MW, respectively. The total capacity is 1,644 MW.

− The Period of 2015–2021: The total purchased capacity from Firm Contract

SPPs using cogeneration system is 2,000 MW; 270 MW is annually scheduled in 2015–2020

and the remaining 380 MW is in 2021.

− The Period of 2022–2030: The annual purchased capacity is forecast to be

360 MW in 2022–2029 and 540 MW in 2030, which makes 3,420 MW in total.

As of January 2010, the contract capacity of 50 potential SPPs using cogeneration

system was 3,600 MW comprising 3,391 MW Firm Contracts (43 projects) and 209 MW

Non-Firm Contracts (7 projects).

Among these, only 31 projects with a total capacity of 1,956 MW were

commissioned including 25 Firm Contracts (1,788 MW) and 6 Non-Firm Contracts (169

MW). The other 19 upcoming projects consisted of 18 Firm Contracts (1,604 MW) and 1

Non-Firm Contract (40 MW). Details are showed in Appendix 9.

45

8.2 Very Small Power Producer Using Cogeneration System

On 6 November 2006, NEPC had a resolution on “National Power Development

Policy and Plan” which was subsequently endorsed by the Cabinet on 21 November 2006. Its

main objective is to support energy conservation and efficiency through a suitable purchase

from cogeneration SPPs, regarding the Regulations for the Purchase of Power from SPPs and

VSPPs.

On 8 September 2009, the Cabinet approved the NEPC’s resolution on 24 August

2006 to promote power generation from cogeneration system. The promotion scheme

encourages power purchase from VSPPs using cogeneration system with unlimited duration

and capacity.

However, the purchased power from cogeneration VSPPs assembled in PDP 2010

is only 113 MW as estimated by distribution utilities.

As of December 2009, there were 17 projects of cogeneration VSPPs with a total

capacity of 70.65 MW. They include 2 commissioned projects (6.0 MW), 11 PPA signed

projects (53.6 MW), 1 approved project (3.6 MW) and 3 under consideration projects (7.45

MW). Details are elaborated in Appendix 9.

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9. Nuclear Power Plant Projects

9.1 Evolution of Nuclear Power Plants

The basic mechanism of nuclear power plants (NPPs) is the same as that of other

thermal power plants. They only harness heat from nuclear fission chain reaction, instead of

fossil fuels. Two major parts in NPPs are:

1. Nuclear Reactor is where nuclear reactions take place and used as an energy

source to boil steam that drives generator’s turbine.

2. Generator is where turbine blades are turned to generate electricity.

Nuclear technologies have been long researched and developed. They can be

divided into 4 generations.

1st Generation Nuclear Reactor: Early Prototypes Reactors (1950-1969)

Studies and researches on NPPs were originated to invent laboratory prototypes

and to acquire practical knowledge including characteristics of reactor core, fuel compounds,

moderators, etc.

2nd Generation Nuclear Reactor: Commercial Power Reactors (1969-1990)

To generate low cost energy, commercial reactors were built upon available

technologies. Although reactors of this generation are not rather complicated, they are widely

accepted and employed; many are still in operation. However, some aspects need continuous

improvements such as security system, endurance, efficiency, construction time and radioactive

wastes.

3rd Generation Nuclear Reactor: Advanced LWRs, and

3rd Generation Nuclear Reactor Plus: Evolutionary Design (1990-2030)

The leading technologies of 2nd Generation, i.e. Pressurized Water Reactor (PWR),

Boiling Water Reactor (BWR) and Pressurized Heavy Water Reactor (PHWR), were further

developed. Construction period were shortened from 7 years to only 3-4 years. Fuel life was

prolonged and thus lessened radioactive waste. Electromechanical equipment was integrated

with natural forces, such as gravity and evaporation (Passive Safety System), and able to work

independently to handle a number of simultaneous emergency incidents.

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9.2 Necessity of NPPs in Thailand

Despite lack of confidence in safety of earlier NPPs, present technologies have

been focused on this matter and much far advanced, and thus more public acceptance. As of

February 2010, there were 436 NPPs in operation in 30 countries and 53 NPPs under

construction worldwide. Consequently, NPP is a competitive option in long term PDP with

several advantages as followings:

1. Serving the Increasing Power Demand

Thailand is a developing country with a sizeable population growth. Its

electrical demand continuously increases. Therefore, NPP is a promising alternative to fulfill

the country’s future electrical needs.

2. Improving National Power System and Energy Security

Fossil fuels are terminable, particularly very limited natural gas in the Gulf of

Thailand. At present, Thailand’s Electricity Supply Industry (ESI) depends largely on natural

gas, more than 70% of total energy generation. To reduce risks of fuel shortage, fuel types and

fuel sources should be better diversified. To raise system reliability, base load power plants

should be steady and efficient. NPPs have more than 80% capacity factor and abundant fuel

supply. Furthermore, they can be operated for 18 consecutive months per one fuel loading. As

a result, NPP is competent option.

3. Enhancing System Efficiency and Reliability

Comparing electricity production from different fuels, it was found that 1 kg

coal yields 3 kWh; 1 kg natural gas yields 4 kWh and; 1 kg Uranium yields 50,000 kWh. High

heat rate and low fuel consumption rate of NPPs makes them very efficient and reliable power

plants.

4. Lowering Risks of Fuel Price

Since global fuel deficiency has fluctuated fossil fuel prices vastly, fuel

diversification becomes very essential. Uranium price is stable, inexpensive and unbound to

crude oil price. Hence, it can lessen uncertainty of fuel costs and electricity tariff.

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5. Being Clean Energy

Unlike fossil fuel fired power plants, NPPs do not discharge greenhouse gases

and other pollutions (NOx, SO2, CO2). EGAT and the Government of Thailand realized that

global warming and climate change is a serious issue, and therefore considered NPP as an

alternative in PDP 2010.

9.3 Progress of NPP Projects in Thailand

On 9 April 2007, the National Energy Policy Council (NEPC) had agreed on the

principle of PDP 2007 introducing NPP as an alternative future supply. Thereafter, NEPC

appointed the Nuclear Power Infrastructure Preparation Committee (NPIPC) and its

subcommittees to carry out preparatory works for nuclear power program which were

reported as Nuclear Power Infrastructure Establishment Plan (NPIEP). On 30 October 2007,

the Nuclear Power Program Development Office (NPPDO) was established under the Ministry

of Energy to coordinate the NPIEP implementation during 2008-2010 including work plan and

budget for NPPDO. On 18 December 2007, the Cabinet appointed the Nuclear Power

Infrastructure Establishment Coordination Committee (NPIECC).

There are 5 sub-committees under NPIECC to coordinate the NPIEP

implementation:

1. The Sub-committee on Legal System, Regulatory System and International

Protocols

2. The Sub-committee on Nuclear Power Utility Planning Coordination

3. The Sub-committee on Industrial and Commercial Infrastructure, Technology

Development and Transfer, and Human Resources Development

4. The Sub-committee on Nuclear Safety and Environmental Issues

5. The Sub-committee on Public Information and Public Acceptance

EGAT, as the major agency in the Sub-committee on Nuclear Power Utility

Planning Coordination, hired Burns and Roe Asia Co., Ltd. to perform feasibility study of NPP

development preparation in Thailand in various aspects. The study lasted for 20 months

starting from 1 October 2008 and covers:

49

Task 1 : Energy Economics and Financing

Task 2 : Technical and Safety Aspects of Nuclear Power

Task 3 : Fuel Cycle and Waste Management

Task 4 : Reactor Technology, Supplier and Fuel Supplier Selection

Task 5 : Site and Environmental Study

Task 6 : Human Resources Development and Management Aspects

9.4 NPPs in PDP 2010

Considering the capacity of NPPs not higher than 10% of system’s capacity, due to

applicable investment plan and implementation procedures, it is concluded that the appropriate

unit size of 1,000 MW entering the system shall not be more than 1 unit each year. Their

commissioning schedule is as below:

Nuclear Power Plant Unit #1 1,000 MW in 2020





50

10. Greenhouse Gas Emission Reduction in Power Sector

10.1 Climate Change

Global Warming is one of the current hot issues discussed throughout the world

due to its vast negative impacts to worldwide population. The obvious impact of global

warming is Climate Change causing many global perilous problems such as temperature and

sea level rise, severe flooding unusual weather and unseasonable rain, inducing the society

and economy concerns.

Climate Change is caused by the solar radiation absorbed by earth surface and sea

water. Normally, some of this solar radiation reflects back out of the earth to the space in

form of heat wave for atmosphere temperature balancing. However, with something called

“Greenhouse Gases” under the surrounding atmosphere, solar radiation reflection is improper

to let the less back to the space and the much still under the atmosphere. This phenomenon,

inducing heat accumulation both on the earth surface and under the atmosphere, is called

“Greenhouse Effect” coming after the increasing of Greenhouse Gases under the atmosphere.

Greenhouse gases (GHG) are Carbon dioxide (CO2,), Methane (CH4),

Chlorofluorocarbons (CFCs), Ozone (O3) and Nitrous oxide (N2O) with properties of well-

absorbed heat wave and infrared radiation. The amount of those concentrated gases directly

affects atmosphere temperature maintainability. Without GHG, the earth temperature will

rapidly change (extremely hot in the daytime and extremely cold at night) with the reason that

GHG absorb heat during daytime and gradually release it at night-time to keep the earth warm

without rapid temperature change. Too much GHG in the atmosphere, the capability of

atmosphere heat absorbing increases, resulting in a high average atmosphere temperature.

Therefore, the GHG emission should be controlled at appropriate amounts.

Some GHG such as Carbon dioxide (CO2) occurs naturally, and are emitted to the

atmosphere through natural processes and human activities, and enters the atmosphere

through the burning of fossil fuels (oil, natural gas, and coal) and deforestation. Methane

(CH4) emission results from livestock, agricultural practices and the decay of organic waste in

municipal solid waste landfills. Nitrous oxide (N2O) is emitted by the process of soil biology

during agricultural activities as synthetic fertilization. Halocarbons (as CFCs), produced as a

51

direct result of human's activities, and having the greatest potential as greenhouse gases, are

resulting from industrial process.

10.2 Carbon Dioxide Emission Control Policies

GHG emission control helps delay the increasing rate of global warming in several

ways, such as limiting amount of GHG from the emission sources. For energy sector, power

generation is a source of CO2 emission increase through the burning of fossil fuels as natural

gas, coal, and oil.

In order to control CO2 amounts emitted from power generation, a policy of the

appropriate proportion of fossil fuels used for electricity generation should be investigated

and defined. However, to maintain the stability of power system as its technical requirements,

an alternative energy is later inquired and selected to reinforce power system when the portion

of fossil fuels used was already adjusted.

Actually, not only fossil fuels, but also alternative energy can be used for

electricity generation to reinforce the power system. The important reason to select the

alternative energy such as hydro power, solar power, wind power, nuclear power, and etc. as

fuels for power generation is their zero CO2 emission. With the individual limitation of each

power generation technology, high generation cost and unreliable power generation,

electricity generation should not rely solely on one fuel source. Fuel diversification for power

generation with appropriate proportion is necessary.

To obtain well-developed power development plan, basic criteria to be generally

considered are national energy policies and technical criteria. More importantly, the climate

change criteria as CO2 emission level of power sector are also taken into account for this PDP

2010 arrangement. Therefore, the CO2 emission control policy was given by the Ministry of

Energy, targeting on reduction of the average CO2 emission level per generation unit (kg

CO2/kWh). The target was set, by 2020, that the average CO2 emission level per generation

unit (kg CO2/kWh) of the PDP 2010 must be lower than that of the PDP 2007: Revision 2,

and then during 2021 to 2030 the average CO2 emission rate must be at a suitable level.

Estimation of CO2 emission amounts of fossil fuel power generation of this PDP

2010 is calculated with reference to the international principles as the 2006 IPCC Guidelines

for National Greenhouse Gas Inventories (more details shown in Table 10.1).

52

Table 10.1 Estimated CO2 Emission Amounts as Power Development Plan

(Unit: kg CO2/kWh)

Year PDP 2007: Revision 2 PDP 2010

2010 0.464 0.482

2011 0.459 0.471

2012 0.459 0.470

2013 0.456 0.462

2014 0.447 0.468

2015 0.440 0.448

2016 0.452 0.423

2017 0.465 0.408

2018 0.456 0.398

2019 0.445 0.401

2020 0.425 0.387

2021 0.406 0.374

2022 - 0.373

2023 - 0.381

2024 - 0.361

2025 - 0.341

2026 - 0.357

2027 - 0.354

2028 - 0.363

2029 - 0.367

2030 - 0.368

53

11. Transmission System Development Plan

Transmission System Development Projects/Investment Plans in PDP 2010 during

2010–2030 consist of:

11.1 Bulk Power Supply Project for the Greater Bangkok Area Phase 2

The Bulk Power Supply Project for the Greater Bangkok Area Phase 2 (BSB2) is

successive from the Phase 1 Project. The project comprises subprojects converting existing

230 kV transmission lines to 500 kV voltage level, adding transformers and reactive power

compensation and constructing new 230 kV substations to cope with the increasing power

demand in metropolitan area. The scope of work of BSB2 is to maintain and increase system

reliability and to support the Metropolitan Electricity Authority (MEA)’s long term distribution

system expansion plan. It is planned to be completed during 2009–2012.

This project was approved by the Cabinet on 8 August 2006.

11.2 Bulk Power Supply Project for the Greater Bangkok Area Phase 3

The Bulk Power Supply Project for the Greater Bangkok Area Phase 3 (BSB3) is

the next phase of EGAT system development to meet the growing demand in Bangkok and its

vicinity. One of the subprojects in BSB3 is the upgrading of existing 500 kV transmission lines

from 230 kV to 500 kV operating level to increase system reliability. It is planned to be

completed during 2014–2016.

11.3 Transmission System Development Project for Power Purchase from Lao

PDR (Nam Ngum 2 Hydro Power Plant)

This project is to construct 500 kV double-circuit transmission lines from Udon

Thani 3 Substation to Thailand-Lao PDR border at Nong Khai Province with a distance of

approximately 80 km to conduct purchased electricity from Nam Ngum 2 Hydro Power

Project (597 MW) to EGAT system. It is planned to be completed in 2010 and initially

energized at 230 kV level.

This project was approved by the Cabinet on 22 August 2006.

11.4 500 kV Transmission System Development Project for IPP Power Plants

54

This project is to construct the third and the forth 500 kV transmission circuits

from Pluak Daeng Substation to Nong Chok T Junction and connect to Wang Noi Substation

to cope with power purchase from Independent Power Producers (IPP) power plants. It is

planned to be completed in 2011.

11.5 Transmission System Expansion Project No. 11

This project is planned to be implemented nationwide except for the Greater

Bangkok Area, of which the reinforcement plan was exclusively proposed. It is aimed to

handle the increasing demand and maintain the system reliability. This project is a subsequence

of Transmission System Expansion Project No.10 (TS.10). Moreover, this project will support

Provincial Electricity Authority (PEA)’s distribution expansion plan to other areas efficiently.

It is planned to be completed during 2010 – 2012.

This project was approved by the Cabinet on 2 October 2007.

11.6 Transmission System Expansion Project No. 12-14

These projects are succeeding programs of transmission system expansion project

No.11 (TS.11). The expected completion year of each project is:

Projects Completion Year

TS.12 2014 – 2016

TS.13 2017 – 2019

TS.14 2020 – 2022


PDR (Theun Hinboun Expansion Phase)

This project is to enhance EGAT’s transmission system by construction of a new

230 kV Nakhon Phanom Substation, re-conducting 230 kV transmission lines from Thailand-

Lao PDR border at Nakhon Phanom Province to Nakhon Phanom 2 Substation and

construction of other 230 kV and 115 kV transmission lines to convey electric power from the

55

existing Theun Hinboun Hydro Power Plant Project and Theun Hinboun Expansion Project,

totally 440 MW, to Thailand. It is planned to be completed in 2012.

11.8 Transmission System Development Project for IPP Power Plants (Phase 2)

This project is to link the awarded IPPs in PDP 2007 Revision 1 to EGAT’s

system, which are anticipated to commission in 2011–2013. These awarded IPPs include

GHECO-One Co.,Ltd, National Power Supply Co.,Ltd, Siam Energy Co.,Ltd and Power

Generation Supply Co.,Ltd, totally 4,400 MW. It is planned to be completed during 2011–

2013.


PDR (Hongsa Lignite-Fired Thermal Power Plant)

This project will be implemented to tackle power import from 3x626 MW

Hongsa Lignite-Fired Thermal Power Plant Project. It is planned to be completed in 2014.

11.10 Transmission System Development Project for Power Purchase from

Myanmar (Mai Khot Coal-Fired Thermal Power Plant)

This project will be implemented to undertake electric power from 3x135 MW

Mai Khot Coal-Fired Thermal Power Plant Project. It is planned to be completed in 2015.

11.11 Transmission System Development Project for EGAT’s New Power Plants

This project is to connect EGAT’s new power plants to the grid. The new power

plant projects are as followings:

Power Plant Fuel Type Capacity (MW) Commissioning

Date

Wang Noi Combined Cycle Power Plant Project Natural Gas 800 June 2014

Chana Combined Cycle Power Plant Project Natural Gas 800 July 2014

56

11.12 Transmission System Development Project for EGAT’s Coal-Fired Thermal

Power Plant

This project is to link EGAT’s future coal-fired thermal power plants to EGAT’s

system, which will diversify fuel sources for power generation, decrease the proportion of

natural gas use and increase system reliability. It is planned to be finished in 2019.

11.13 Transmission System Development Project for EGAT’s Nuclear Power

Plant

This project is to connect EGAT’s future nuclear power plants to EGAT’s

system, which will diversify fuel mix in power generation, reduce percentage of natural gas

share and improve system reliability. It is expected to be completed in 2020.

11.14 Transmission System Development Project for EGAT’s Combined Cycle

Power Plant

This project is to link EGAT’s new combined-cycle power plants to the grid, to

maintain power supply and enhance system reliability. The first 800 MW combined cycle

power plant is scheduled to be on line in 2022.

11.15 Transmission System Development Project for Power Purchase from

Neighboring Countries

This project is targeted to decline the portion of natural gas and other fuel

resources for power generation as well as to follow accomplish the Government’s policy on

collaboration with neighboring countries. To purchase electricity from neighboring countries,

feasibility study for each potential project will be evaluated for the country’s benefits.

11.16 New Transmission Interconnection Project between Su-Ngai Kolok

Substation (EGAT) and Rantau Panjang Substation (TNB)

This project is to construct new transmission interconnection between EGAT’s

Su-Ngai Kolok Substation in Narathiwat Province and TNB’s Rantau Panjang Substation in

Kelantan State, Malaysia, to increase system reliability by importing power from Malaysia via

another route. The scope of work covers 132 kV double-circuit transmission lines from Su-

57

Ngai Kolok Substation to Thailand-Malaysia border at Narathiwat Province and two units of

132/115 kV 100 MVA tie transformer at Su-Ngai Kolok Substation. The maximum import

power is approximately 100 MW. It is expected to be done in September 2010.

11.17 Transmission System Expansion and Renovation Project

This project is to increase system reliability and to enable more efficient power

transmission. EGAT’s substations and transmission lines have been in operation for long time.

Efficiency of substation equipment and transmission lines is decreased as being operated. It is

planned to be finished during 2013-2017.

11.18 Miscellaneous Transmission System Expansion Project for SPP Power

Plants

According to Thai Government’s policy, private sector is encouraged to

participate in power generation from renewable energy. This policy is intended to reduce

imported energy resources and maximize the utilization of domestic renewable energy as well

as promoting more efficient energy use of cogeneration system. Once EGAT agrees to

purchase electricity from any SPP, it will prepare to develop expanded transmission system to

receive power from that SPP as appropriate.

58

Table 11.1 Transmission System Expansion Projects/Investment Plans

during 2010 – 2020 (PDP 2010)

Projects Commissioning A. Approved and On-going Project/Investment Plans

1. Bulk Power Supply for the Greater Bangkok Area Phase 2 2009-2012

2. Transmission System Development for Power Purchase from Lao PDR (Nam Ngum 2 Hydro Power Plant Project)

2010

3. 500 kV Transmission System Development Project for IPP Power Plants

2011

4. Transmission System Expansion Project No.11 (2007-2011) 2010-2012

5. Transmission System Project for IPP Power Projects 2011-2013

6. Transmission System Development for Power Purchase from Lao PDR (Theun Hinboun Expansion Project)

2012

B. Future Project

1. New Transmission Interconnection between Su-ngai Kolok Substation (EGAT) and Rantau Panjang Substation (TNB)

2012

2. Transmission System Expansion and Renovation Project 2013-2017

3. Transmission System Development for Power Purchase from Lao PDR (Hongsa Lignite-Fired Thermal Power Plant Project)

2014

4. Transmission System Development for Power Purchase from Myanmar (Mai Khot Coal-Fired Thermal Power Plant Project)

2015

5. Bulk Power Supply for the Greater Bangkok Area Phase 3 (2010-2016)

2014-2016




9. Miscellaneous Transmission System Expansion for Small Power Producer (SPP) Power Plants

2013-2020

59

Appendices

61

Appendix 1

Comparison of Thailand Power Development Plans

63

COMPARISON BETWEEN THAILAND PDP 2007 REVISION 2 AND PDP 2010

( 2010 - 2021 )

PDP 2007 Revision 2 PDP 2010

Power Plants MW Power Plants MW

2010 VSPP (Jan.) 10 VSPP (Jan) 367

Chao Phraya Dam # 2 (Mar) 6 SPP (Renewables) (Jun) 90

North Bangkok CC #1 (May) 670 Power Purchase from Lao PDR (Nam Theun 2) (Mar) 920

Mae Kllong Dam # 1-2 (Aug, Dec) 2x6 North Bangkok CC #1 (May) 670

Pasak Jolasid Dam (Oct) 6.7 SPP (Cogeneration) (Nov) 90

Khun Dan Prakarnchon Dam (Nov) 10

SPP (Cogeneration) (Nov) 902011 VSPP (Jan) 48 VSPP (Jan) 258

Power Purchase from Lao PDR (Nam Ngum 2) (Jan) 597 EGAT Renewables (Jan) 18

Kwae Noi Dam # 1-2 (Jan, Apr) 2x15 Power Purchase from Lao PDR (Nam Ngum 2) (Jan) 597

Naresuan Dam (Feb) 8 Chao Phraya Dam #1-2 (Jan) 2x6

SPP (Renewables) (Aug) 250 SPP (Renewables) (Jun) 160

GHECO-ONE Co., Ltd. (Nov) 660 Naresuan Dam (Oct) 8

GHECO-ONE Co., Ltd. (Nov) 6602012 VSPP (Jan) 50 VSPP (Jan) 162

SPP (Renewables) (Jan) 65 Mae Klong Dam #1-2 (Jan) 2x6

Power Purchase from Lao PDR (Theun Hinboun Ext.) (Jul) 220 Khun Dan Prakarnchon Dam (Apr) 10

SPP (Cogeneration) (Jun) 924 Pasak Jolasid Dam (May) 7

SPP (Renewables) (Jun) 65

SPP (Cogeneration) (Jun-Dec) 704

Power Purchase from Lao PDR (Theun Hinboun Ext.) (Jul) 2202013 VSPP (Jan) 50 VSPP (Jan) 187

Siam Energy Co., Ltd. #1-2 (Mar, Sep) 2x800 Kwae Noi Dam #1-2 (Jan) 2x15

SPP (Cogeneration) (Jun) 540 EGAT Renewables (Jan) 24

National Power Supply Co., Ltd. #1-2 (Nov) 2x135 SPP (Cogeneration) (Mar-Sep) 720

Siam Energy Co., Ltd. #1-2 (Mar, Sep) 2x800

National Power Supply Co., Ltd. #1-2 (Nov) 2x1352014 VSPP (Jan) 50 VSPP (Jan) 192

National Power Supply Co., Ltd. #3-4 (Mar) 2x135 EGAT Renewables (Jan) 18

Wang Noi CC #4 (Jun) 800 National Power Supply Co., Ltd. #3-4 (Mar) 2x135

SPP (Cogeneration) (Jun) 90 Wang Noi CC #4 (Jun) 800

Power Generation Supply Co., Ltd. #1-2 (Jun, Dec) 2x800 SPP (Cogeneration) (Jun) 90

Chana CC #2 (Jul) 800 Power Generation Supply Co., Ltd. #1-2 (Jun, Dec) 2x800

Chana CC #2 (Jul) 8002015 VSPP (Jan) 50 VSPP (Jan) 167

Power Purchase from Neighbouring Countries (Jun) 450 EGAT Renewables (Jan) 14

Bang Lang Dam (Renovate) (Jan) 12

Power Purchase from Lao PDR (Hongsa TH #1-2) (May, Oct) 2x491

SPP (Cogeneration) (Jun) 2702016 VSPP (Jan) 50 EGAT Renewables (Jan) 17

Thermal Power Plant (Coal)_EGAT #1-2 (Jan) 2x700 Power Purchase from Myanmar (Mai Khot TH #1-3) (Jan, Apr, Jul) 3x123

Power Purchase from Neighbouring Countries (Mar) 450 Power Purchase from Lao PDR (Hongsa TH #3) (Feb) 491

New Power Plant _ South (Jul) 800 VSPP (Jun) 230.5

SPP (Cogeneration) (Jun) 270

New Capacity _ South (Jul) 8002017 VSPP (Jan) 50 VSPP (Jan) 228.5

Thermal Power Plant (Coal)_EGAT #3-4 (Jan) 2x700 EGAT Renewables (Jan) 11

New Power Plant (Jan) 800 Power Purchase from Lao PDR (Nam Ngum 3) (Jan) 440

Power Purchase from Neighbouring Countries (Jan) 450 Lam Takhong Pumped Storage #3-4 (Jun) 2x250

SPP (Cogeneration) (Jun) 2702018 VSPP (Jan) 50 VSPP (Jan) 176

South Bangkok CC #4-5 (Jan) 2x800 EGAT Renewables (Jan) 30

Bang Pakong CC #6 (Jan) 800 SPP (Cogeneration) (Jan) 270

Power Purchase from Neighbouring Countries (Jan) 450 Power Purchase from Neighbouring Countries (Jun) 4502019 VSPP (Jan) 50 VSPP (Jan) 177

North Bangkok CC #2 (Jan) 800 EGAT Renewables (Jan) 8

New Power Plant (Jan) 2x800 SPP (Cogeneration) (Jan) 270

Power Purchase from Neighbouring Countries (Jan) 500 Power Purchase from Neighbouring Countries (Jun) 600

EGAT Clean Coal #1 (Jun) 8002020 VSPP (Jan) 50 VSPP (Jan) 190

EGAT Nuclear Power Plant #1 (Jan) 1000 EGAT Renewables (Jan) 22

New Power Plant_IPP (Jan) 2x800 SPP (Cogeneration) (Jan) 270

Power Purchase from Neighbouring Countries (Jan) 500 EGAT Nuclear Power Plant #1 (Jan) 1000

Power Purchase from Neighbouring Countries (Jun) 6002021 VSPP (Jan) 50 VSPP (Jan) 135

EGAT Nuclear Power Plant #2 (Jan) 1000 EGAT Renewables (Jan) 61

New Power Plant (Jan) 2x800 SPP (Cogeneration) (Jan) 380

Power Purchase from Neighbouring Countries (Jan) 500 EGAT Nuclear Power Plant #2 (Jan) 1000

EGAT Clean Coal #2 (Jun) 800

Power Purchase from Neighbouring Countries (Jan) 600

Year

65

Appendix 2

Map of Thailand Power System

67

Appendix 3

Installed Capacity of Thailand Power System

71

Hydroelectric Power Plant

Bhumibol - 779.2

Sirikit - 500.0

Ubolratana - 25.2

Sirindhorn - 36.0

Chulabhorn - 40.0

Nam Pung - 6.0

Srinagarind - 720.0

Vajiralongkorn - 300.0

Tha Thung Na - 39.0

Kang Krachan - 19.0

Bang Lang - 72.0

Ban Santi - 1.275

Mae Ngat - 9.0

Huai Kum - 1.06

Rajjaprabha - 240.0

Pak Mun - 136.0

Lam Takhong PS - 500.0

Small Hydro Power Plants - 0.445

3,424.180 11.72%

Power Plant

South Bangkok Block 1 Gas 316.0

Block 2 Gas 562.0

Block 3 Gas 710.0

1,588.0

Bang Pakong Unit 1 Gas/Heavy oil 525.5

Unit 2 Gas/Heavy oil 526.5



Bang Pakong Block 3 Gas 314.0

Block 4 Gas 314.0

Block 5 Gas 710.0

3,542.0

Mae Moh Unit 4-7 Lignite 560.0

Unit 8-13 Lignite 1,620.0

2,180.0

Krabi Unit 1 Heavy oil 315.0

315.0

Nam Pong Block 1 Gas 325.0

Block 2 Gas 325.0

650.0

Wang Noi Block 1 Gas 612.0

Block 2 Gas 612.0

Block 3 Gas 686.0

1,910.0

Chana Block 1 Gas 710.0

710.0

10,895.0 37.30%

Diesel Power Plant

Mae Hong Son Diesel 4.4

4.4 0.02%

Renewable Energy Source

Subtotal 4.546 0.02%

14,328.1 49.05%

Subtotal

Subtotal

Subtotal

Subtotal

Subtotal

Subtotal

CAPACITY OF THAILAND POWER SYSTEM(as of December 2009)

Plant Type Fuel TypeCapacity

(MW)

Subtotal

Subtotal

Subtotal

Subtotal

Total Capacity of EGAT

73

Purchased Power

Hydroelectric Power Plant

Theun Hinboun - 214.0

Houay Ho - 126.0

340.0 1.16%

Power Plant

Khanom PPB Unit 1 Gas/Heavy oil 69.9


Block 1 Gas 678.0

818.1

Ratchaburi Unit 1 Gas/Heavy oil 720.0


Block 1 Gas 685.0

Block 2 Gas 675.0

Block 3 Gas 681.0

3,481.0

BLCP Power Co. ,Ltd (BLCP) Unit 1 Bituminous Coal 673.3

Unit 2 Bituminous Coal 673.3

1,346.5

Rayong Block 1 Gas 294.7

Block 2 Gas 287.7

Block 3 Gas 289.8

Block 4 Gas 302.9

1,175.0

Tri Energy Co. ,Ltd (TECO) Block 1 Gas 700.0

700.0

Independent Power Producer (Thailand) Co. ,Ltd (IPT) Block 1 Gas 700.0

700.0

Glow IPP Co. ,Ltd Block 1 Gas 356.5

Block 2 Gas 356.5

713.0

Eastern Power & Electric Co. , Ltd (EPEC) Block 1 Gas 350.0

350.0

Gulf Power Generation Co. ,Ltd Block 1 Gas 734.0

Block 2 Gas 734.0

1,468.0

Ratchaburi Power Co. ,Ltd Block 1 Gas 700.0

Block 2 Gas 700.0

1,400.0

SPP Coal 369.5

Heavy oil 4.5

Gas 1,293.0

1,667.0

13,818.6 47.30%

Renewable Energy Source

SPP Biomass 305.3 1.05%

Gas Turbine Power Plant

SPP Gas 120.0 0.41%

Others

EGAT-TNB - 300.0 1.03%

14,883.9 50.95%

29,212.0 100.00%

Source : System Control and Operation Division and Power Purchase Agreement Division , EGAT

CAPACITY OF THAILAND POWER SYSTEM (con.)

(as of December 2009)

Capacity

(MW)

Subtotal

Subtotal

Plant Type Fuel Type

Subtotal

Subtotal

Subtotal

Subtotal

Subtotal

Total Capacity of the Purchased

Grand Total Capacity

Subtotal

Subtotal

Subtotal

Subtotal

Subtotal

Subtotal

74

Appendix 4

Existing Transmission System

75

EXISTING TRANSMISSION LINES AND SUBSTATIONS OF EGAT POWER SYSTEM

( as of December 2009 )

Voltage Levels Substations Transmission Lines

(kV) Number Transformer Capacity (Circuit-kilometers)

(MVA)

Metropolitan Area

500 2 4,050.0 414.6

230 13 14,700.0 810.5

115 - 25.0 -

Subtotal 15 18,775.0 1,225.1

Central Region

500 5 6,000.0 1,844.5

230 25 14,393.3 4,157.8

115 42 5,254.8 2,618.6

69 - - 18.8

Subtotal 72 25,648.1 8,639.7

Northeastern Region

500 1 2,000.0 320.4

230 11 4,300.0 2,151.2

115 37 3,938.0 5,426.8

Subtotal 49 10,238.0 7,898.4

Southern Region

230 13 4,566.7 3,049.6

132 - 133.4 8.7

115 18 2,379.0 2,383.9

300 (HVDC) - 388.0 23.0

Subtotal 31 7,467.1 5,465.3

Northern Region

500 2 3,800.0 1,142.5

230 6 3,900.0 3,223.9

115 34 2,959.5 2,850.4

Subtotal 42 10,659.5 7,216.8

All Regions

500 10 15,850.0 3,722.0

230 68 41,860.0 13,393.0

132 - 133.4 8.7

115 131 14,556.2 13,279.7

69 - - 18.8

300 (HVDC) - 388.0 23.0

Total 209 72,787.7 30,445.2

Remark : 1/ Sa Dao and Klong Ngae Substations are already included in the 115 kV and 230 kV substations

Source : System Control and Operation Division , EGAT

1/

1/

77

Appendix 5

Power Demand Statistic and Load Forecast

79

Peak Energy Load Elasticity

Year Increase Increase Factor

MW % Gwh % %

Actual : NET Generation2007 22,078.79 N/A N/A 143,813.65 4,989.93 3.59 74.36 0.73 2008 22,236.96 158.17 0.72 145,816.50 2,002.85 1.39 74.65 0.57 2009 22,315.35 78.39 0.35 146,182.00 365.50 0.25 74.58 -

Forecast : NET Generation2010 23,249 934 4.18 152,954 6,772 4.63 75.10 1.36 2011 24,568 1,319 5.67 160,331 7,377 4.82 74.50 1.20 2012 25,913 1,345 5.47 168,049 7,718 4.81 74.03 1.14 2013 27,188 1,275 4.92 175,631 7,582 4.51 73.74 1.11 2014 28,341 1,153 4.24 183,452 7,821 4.45 73.89 0.93 2015 29,463 1,122 3.96 191,224 7,772 4.24 74.09 0.95 2016 30,754 1,291 4.38 200,012 8,788 4.60 74.24 1.07 2017 32,225 1,471 4.78 209,329 9,317 4.66 74.15 1.09 2018 33,688 1,463 4.54 218,820 9,491 4.53 74.15 1.11 2019 34,988 1,300 3.86 227,599 8,779 4.01 74.26 0.97 2020 36,336 1,348 3.85 236,956 9,357 4.11 74.44 0.97 2021 37,856 1,520 4.18 246,730 9,774 4.12 74.40 0.99 2022 39,308 1,452 3.84 256,483 9,753 3.95 74.49 0.99 2023 40,781 1,473 3.75 266,488 10,005 3.90 74.60 0.99 2024 42,236 1,455 3.57 276,805 10,317 3.87 74.81 0.99 2025 43,962 1,726 4.09 287,589 10,784 3.90 74.68 0.99 2026 45,621 1,659 3.77 298,779 11,190 3.89 74.76 0.99 2027 47,344 1,723 3.78 310,387 11,608 3.89 74.84 0.99 2028 49,039 1,695 3.58 322,427 12,040 3.88 75.06 0.99 2029 50,959 1,920 3.92 334,921 12,494 3.87 75.03 0.99 2030 52,890 1,931 3.79 347,947 13,026 3.89 75.10 0.99

Average Growth

2008-2010 - 390 1.74 - 3,047 2.08 - -2011-2015 - 1,243 4.85 - 7,654 4.57 - -2016-2020 - 1,375 4.28 - 9,146 4.38 - -2021-2025 - 1,525 3.88 - 10,127 3.95 - -2026-2030 - 1,786 3.77 - 12,072 3.88 - -2010-2030 - 1,456 4.19 - 9,608 4.22 - -

Remark : Include power purchase from VSPP February 2010

MW GWh

POWER DEMAND STATISTIC AND LOAD FORECAST FOR PDP 2010

(EGAT SYSTEM AND PURCHASE FROM VSPP)

February 2010

81

Case : December 2008 Case : February 2010 DifferenceYear (1) (2) (2)-(1)

MW GWh MW GWh MW % GWh %2010 24,264 157,079 23,249 152,954 -1,015 -4.18 -4,125 -2.632011 25,692 165,671 24,568 160,331 -1,124 -4.38 -5,340 -3.222012 27,492 176,762 25,913 168,049 -1,579 -5.74 -8,713 -4.932013 29,148 188,374 27,188 175,631 -1,960 -6.72 -12,743 -6.762014 30,918 200,183 28,341 183,452 -2,577 -8.34 -16,731 -8.362015 32,820 212,753 29,463 191,224 -3,357 -10.23 -21,529 -10.122016 34,797 225,727 30,754 200,012 -4,043 -11.62 -25,715 -11.392017 36,832 239,051 32,225 209,329 -4,607 -12.51 -29,722 -12.432018 38,925 252,824 33,688 218,820 -5,237 -13.45 -34,004 -13.452019 41,062 266,839 34,988 227,599 -6,074 -14.79 -39,240 -14.712020 43,292 281,472 36,336 236,956 -6,956 -16.07 -44,516 -15.822021 45,572 296,414 37,856 246,730 -7,716 -16.93 -49,684 -16.762022 - - 39,308 256,483 - - - -2023 - - 40,781 266,488 - - - -2024 - - 42,236 276,805 - - - -2025 - - 43,962 287,589 - - - -2026 - - 45,621 298,779 - - - -2027 - - 47,344 310,387 - - - -2028 - - 49,039 322,427 - - - -2029 - - 50,959 334,921 - - - -2030 - - 52,890 347,947 - - - -

February 2010

COMPARISON OF LOAD FORECAST

(INCLUDE EGAT SYSTEM AND PURCHASE FROM VSPP)

82

Peak Energy Load Elasticity

Year Increase Increase Factor

MW % GWh % %

Actual : NET Generation2007 22,009.20 N/A N/A 143,740.98 4,940.16 3.56 74.55 0.72 2008 22,018.00 8.80 0.04 145,227.50 1,486.52 1.03 75.09 0.42 2009 22,044.90 26.90 0.12 145,233.00 5.50 0.00 75.00 -

Forecast : NET Generation2010 22,690 645 2.93 150,454 5,221 3.59 75.69 1.05 2011 23,788 1,098 4.84 156,656 6,202 4.12 75.18 1.03 2012 24,995 1,207 5.07 163,914 7,258 4.63 74.86 1.09 2013 26,111 1,116 4.46 170,712 6,798 4.15 74.63 1.02 2014 27,101 990 3.79 177,944 7,232 4.24 74.95 0.89 2015 28,081 980 3.62 185,215 7,271 4.09 75.29 0.92 2016 29,176 1,095 3.90 193,157 7,942 4.29 75.58 1.00 2017 30,453 1,277 4.38 201,761 8,604 4.45 75.63 1.04 2018 31,766 1,313 4.31 210,748 8,987 4.45 75.74 1.09 2019 32,915 1,149 3.62 219,040 8,292 3.93 75.97 0.95 2020 34,102 1,187 3.61 227,853 8,813 4.02 76.27 0.95 2021 35,507 1,405 4.12 237,162 9,309 4.09 76.25 0.98 2022 36,709 1,202 3.39 245,700 8,538 3.60 76.41 0.90 2023 38,058 1,349 3.67 255,143 9,443 3.84 76.53 0.97 2024 39,387 1,329 3.49 264,893 9,750 3.82 76.77 0.97 2025 40,974 1,587 4.03 275,021 10,128 3.82 76.62 0.98 2026 42,498 1,524 3.72 285,586 10,565 3.84 76.71 0.98 2027 44,077 1,579 3.72 296,552 10,966 3.84 76.80 0.98 2028 45,625 1,548 3.51 307,932 11,380 3.84 77.05 0.98 2029 47,393 1,768 3.88 319,734 11,802 3.83 77.01 0.98 2030 49,172 1,779 3.75 332,068 12,334 3.86 77.09 0.98

Average Growth

2008-2010 - 226.93 1.02 - 2,237.67 1.53 - -2011-2015 - 1,078.20 4.36 - 6,952.20 4.24 - -2016-2020 - 1,204.20 3.96 - 8,527.60 4.23 - -2021-2025 - 1,374.40 3.74 - 9,433.60 3.83 - -2026-2030 - 1,639.60 3.72 - 11,409.40 3.84 - -2010-2030 - 1,291.77 3.89 - 8,896.90 4.02 - -

February 2010

MW GWh

TOTAL EGAT GENERATION REQUIREMENT (EXCLUDE VSPP)

February 2010

83

COMPARISON OF TOTAL EGAT GENERATION (EXCLUDE VSPP)

Case : December 2008 Case : February 2010 DifferenceYear (1) (2) (2)-(1)

MW GWh MW GWh MW % GWh %2010 23,936 155,645 22,690 150,454 -1,246 -5.21 -5,191 -3.342011 25,085 162,884 23,788 156,656 -1,297 -5.17 -6,228 -3.822012 26,572 172,593 24,995 163,914 -1,577 -5.93 -8,679 -5.032013 28,188 183,218 26,111 170,712 -2,077 -7.37 -12,506 -6.832014 29,871 194,326 27,101 177,944 -2,770 -9.27 -16,382 -8.432015 31,734 206,604 28,081 185,215 -3,653 -11.51 -21,389 -10.352016 33,673 219,339 29,176 193,157 -4,497 -13.35 -26,182 -11.942017 35,668 232,413 30,453 201,761 -5,215 -14.62 -30,652 -13.192018 37,725 245,950 31,766 210,748 -5,959 -15.80 -35,202 -14.312019 39,828 259,740 32,915 219,040 -6,913 -17.36 -40,700 -15.672020 42,024 274,144 34,102 227,853 -7,922 -18.85 -46,291 -16.892021 44,281 288,920 35,507 237,162 -8,774 -19.81 -51,758 -17.912022 - - 36,709 245,700 - - - -2023 - - 38,058 255,143 - - - -2024 - - 39,387 264,893 - - - -2025 - - 40,974 275,021 - - - -2026 - - 42,498 285,586 - - - -2027 - - 44,077 296,552 - - - -2028 - - 45,625 307,932 - - - -2029 - - 47,393 319,734 - - - -2030 - - 49,172 332,068 - - - -

February 2010

84

Appendix 6

Projection of Generating Capacity

Classified by Power Plant Types

85

PROJ

ECTIO

N OF G

ENER

ATIN

G CAP

ACITY

CLAS

SIFIED

BY PO

WER P

LANT

TYPE

SPD

P 201

0 20

1020

1120

1220

1320

1420

1520

1620

1720

1820

1920

2020

2120

2220

2320

2420

2520

2620

2720

2820

2920

30- E

GA

TM

W3,

424

3,42

4 3,

424

3,42

4 3,

424

3,43

6 3,

436

3,93

6 3,

936

3,93

6 3,

936

3,93

6 3,

936

3,93

6 3,

936

3,93

6 3,

936

3,93

6 3,

936

3,93

6 3,

936

%10

.9

10.4

10

.0

9.3

8.6

8.6

8.3

9.3

9.2

8.9

8.8

8.3

8.0

7.7

7.5

7.5

6.9

6.9

6.4

6.2

6.0

- La

o PD

RM

W1,

260

1,85

7 2,

077

2,07

7 2,

077

3,05

9 3,

550

3,99

0 3,

990

3,99

0 3,

990

3,99

0 3,

990

3,77

6 3,

776

3,77

6 3,

776

3,77

6 3,

776

3,77

6 3,

650

%4.

0 5.

6 6.

1 5.

6 5.

2 7.

7 8.

6 9.

4 9.

4 9.

0 8.

9 8.

4 8.

2 7.

4 7.

2 7.

2 6.

6 6.

6 6.

2 5.

9 5.

6

- M

yanm

arM

W-

-

-

-

-

-

36

9 36

9 36

9 36

9 36

9 36

9 36

9 36

9 36

9 36

9 36

9 36

9 36

9 36

9 36

9 %

-

-

-

-

-

-

0.9

0.9

0.9

0.8

0.8

0.8

0.8

0.7

0.7

0.7

0.7

0.7

0.6

0.6

0.6

- Fo

reig

n Pu

rcha

sed

MW

-

-

-

-

-

-

-

-

450

1,05

0 1,

650

2,25

0 2,

850

3,45

0 4,

050

4,65

0 5,

250

5,85

0 6,

450

7,05

0 7,

650

%-

-

-

-

-

-

-

-

1.

1 2.

4 3.

7 4.

7 5.

8 6.

7 7.

7 8.

8 9.

2 10

.3

10.5

11

.1

11.7

Subt

otal

MW

4,68

4 5,

281

5,50

1 5,

501

5,50

1 6,

495

7,35

5 8,

295

8,74

5 9,

345

9,94

5 10

,545

11

,145

11

,531

12

,131

12

,731

13

,331

13

,931

14

,531

15

,131

15

,605

%

14.9

16

.0

16.1

14

.9

13.9

16

.2

17.8

19

.6

20.5

21

.1

22.2

22

.2

22.8

22

.5

23.1

24

.1

23.4

24

.5

23.7

23

.7

23.8

Oil

- EG

AT

MW

315

315

315

315

315

315

315

315

315

315

315

315

315

315

315

315

315

315

315

315

315

%1.

0 1.

0 0.

9 0.

9 0.

8 0.

8 0.

8 0.

7 0.

7 0.

7 0.

7 0.

7 0.

6 0.

6 0.

6 0.

6 0.

6 0.

6 0.

5 0.

5 0.

5

- SP

PM

W5

5 5

5 5

5 5

5 5

-

-

-

-

-

-

-

-

-

-

-

-

%0.

0 0.

0 0.

0 0.

0 0.

0 0.

0 0.

0 0.

0 0.

0 -

-

-

-

-

-

-

-

-

-

-

-

Oil

/ Gas

- EG

AT

MW

2,20

4 2,

204

2,20

4 2,

204

1,15

2 1,

152

1,15

2 1,

152

1,15

2 1,

152

1,15

2 1,

152

576

-

-

-

-

-

-

-

-

%7.

0 6.

7 6.

5 6.

0 2.

9 2.

9 2.

8 2.

7 2.

7 2.

6 2.

6 2.

4 1.

2 -

-

-

-

-

-

-

-

- IP

PM

W1,

580

1,51

0 1,

510

1,51

0 1,

510

1,51

0 1,

440

1,44

0 1,

440

1,44

0 1,

440

1,44

0 1,

440

1,44

0 1,

440

-

-

-

-

-

-

%5.

0 4.

6 4.

4 4.

1 3.

8 3.

8 3.

5 3.

4 3.

4 3.

3 3.

2 3.

0 2.

9 2.

8 2.

7 -

-

-

-

-

-

Lign

ite-

EGA

TM

W2,

180

2,18

0 2,

180

2,18

0 2,

180

2,18

0 2,

180

2,18

0 2,

180

2,18

0 2,

180

2,18

0 2,

180

2,18

0 2,

040

1,76

0 1,

620

1,62

0 1,

620

1,35

0 1,

080

%7.

0 6.

6 6.

4 5.

9 5.

5 5.

5 5.

3 5.

1 5.

1 4.

9 4.

9 4.

6 4.

5 4.

3 3.

9 3.

3 2.

8 2.

9 2.

6 2.

1 1.

7

Coa

l-

EGA

TM

W-

-

-

-

-

-

-

-

-

80

0 80

0 1,

600

1,60

0 2,

400

2,40

0 2,

400

4,00

0 4,

000

5,60

0 6,

400

7,20

0 %

-

-

-

-

-

-

-

-

-

1.8

1.8

3.4

3.3

4.7

4.6

4.6

7.0

7.0

9.1

10.0

11

.0

- IP

PM

W1,

347

2,00

7 2,

007

2,27

7 2,

547

2,54

7 2,

547

2,54

7 2,

547

2,54

7 2,

547

2,54

7 2,

547

2,54

7 2,

547

2,54

7 2,

547

2,54

7 2,

547

2,54

7 2,

547

%

4.3

6.1

5.9

6.2

6.4

6.4

6.2

6.0

6.0

5.8

5.7

5.4

5.2

5.0

4.9

4.8

4.5

4.5

4.2

4.0

3.9

- SP

PM

W37

0 37

0 37

0 37

0 37

0 37

0 37

0 37

0 36

0 36

0 36

0 36

0 36

0 36

0 90

-

-

-

-

-

-

%

1.2

1.1

1.1

1.0

0.9

0.9

0.9

0.9

0.8

0.8

0.8

0.8

0.7

0.7

0.2

-

-

-

-

-

-

Subt

otal

MW

8,00

0 8,

590

8,59

0 8,

860

8,07

8 8,

078

8,00

8 8,

008

7,99

8 8,

794

8,79

4 9,

594

9,01

8 9,

242

8,83

2 7,

022

8,48

2 8,

482

10,0

82

10,6

12

11,1

42

%25

.5

26.0

25

.1

23.9

20

.3

20.2

19

.3

18.9

18

.8

19.9

19

.6

20.2

18

.4

18.0

16

.8

13.3

14

.9

14.9

16

.4

16.6

17

.0

Gas

- EG

AT

MW

6,86

6 6,

866

6,86

6 6,

866

8,46

6 8,

466

8,46

6 8,

152

7,51

3 7,

513

6,87

2 6,

872

6,87

2 4,

400

4,40

0 4,

400

4,40

0 4,

400

4,40

0 4,

400

4,40

0 %

21.9

20

.8

20.1

18

.6

21.3

21

.2

20.4

19

.2

17.6

17

.0

15.3

14

.4

14.0

8.

6 8.

4 8.

3 7.

7 7.

7 7.

2 6.

9 6.

7

- IP

PM

W9,

225

9,22

5 9,

225

10,8

25

12,4

25

11,2

50

10,5

72

10,5

72

10,5

72

10,5

72

9,87

2 9,

872

9,87

2 9,

522

9,52

2 8,

822

8,82

2 6,

781

6,06

8 6,

068

6,06

8 %

29.4

28

.0

27.0

29

.3

31.3

28

.1

25.5

25

.0

24.8

23

.9

22.0

20

.7

20.2

18

.6

18.1

16

.7

15.5

11

.9

9.9

9.5

9.3

- SP

PM

W1,

293

1,29

3 1,

293

1,29

3 1,

293

1,29

3 1,

293

1,11

3 1,

081

901

721

521

371

330

90

-

-

-

-

-

-

%4.

1 3.

9 3.

8 3.

5 3.

3 3.

2 3.

1 2.

6 2.

5 2.

0 1.

6 1.

1 0.

8 0.

6 0.

2 -

-

-

-

-

-

- New

pow

er p

lant

MW

-

-

-

-

-

-

800

800

800

800

800

800

1,60

0 5,

600

5,60

0 6,

400

8,00

0 8,

800

10,4

00

11,2

00

11,2

00

%-

-

-

-

-

-

1.

9 1.

9 1.

9 1.

8 1.

8 1.

7 3.

3 10

.9

10.7

12

.1

14.1

15

.5

17.0

17

.6

17.1

Subt

otal

MW

17,3

84

17,3

84

17,3

84

18,9

84

22,1

84

21,0

09

21,1

31

20,6

37

19,9

66

19,7

86

18,2

65

18,0

65

18,7

15

19,8

52

19,6

12

19,6

22

21,2

22

19,9

81

20,8

68

21,6

68

21,6

68

%55

.5

52.7

50

.9

51.3

55

.9

52.5

51

.0

48.7

46

.9

44.7

40

.7

37.9

38

.2

38.7

37

.3

37.2

37

.3

35.2

34

.0

34.0

33

.1

- EG

AT

MW

4 4

4 4

4 4

4 4

4 4

4 4

4 4

4 4

4 4

4 4

4 %

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

- SP

PM

W12

0 12

0 12

0 12

0 12

0 12

0 12

0 12

0 12

0 12

0 12

0 12

0 12

0 12

0 -

-

-

-

-

-

-

%

0.4

0.4

0.4

0.3

0.3

0.3

0.3

0.3

0.3

0.3

0.3

0.3

0.2

0.2

-

-

-

-

-

-

-

Subt

otal

MW

124

124

124

124

124

124

124

124

124

124

124

124

124

124

4 4

4 4

4 4

4 %

0.4

0.4

0.4

0.3

0.3

0.3

0.3

0.3

0.3

0.3

0.3

0.3

0.3

0.2

0.0

0.0

0.0

0.0

0.0

0.0

0.0

- EG

AT

MW

5 43

71

12

5 14

3 15

7 17

4 18

4 21

4 22

2 24

4 30

4 34

0 34

0 34

0 34

0 34

0 34

0 34

0 34

0 34

0 %

0.0

0.1

0.2

0.3

0.4

0.4

0.4

0.4

0.5

0.5

0.5

0.6

0.7

0.7

0.7

0.6

0.6

0.6

0.6

0.5

0.5

- SP

PM

W30

5 30

5 30

5 30

5 30

5 30

5 30

5 30

5 30

5 30

5 29

7 29

7 29

7 29

7 24

8 18

4 17

9 16

4 69

69

69

%

1.0

0.9

0.9

0.8

0.8

0.8

0.7

0.7

0.7

0.7

0.7

0.6

0.6

0.6

0.5

0.4

0.3

0.3

0.1

0.1

0.1

Subt

otal

MW

310

348

377

431

449

463

479

490

520

527

541

602

638

638

588

524

519

504

409

409

409

%1.

0 1.

1 1.

1 1.

2 1.

1 1.

2 1.

2 1.

2 1.

2 1.

2 1.

2 1.

3 1.

3 1.

2 1.

1 1.

0 0.

9 0.

9 0.

7 0.

6 0.

6

- R

enew

able

MW

90

250

315

315

315

315

315

315

315

315

315

315

315

315

315

315

315

315

315

315

315

%0.

3 0.

8 0.

9 0.

9 0.

8 0.

8 0.

8 0.

7 0.

7 0.

7 0.

7 0.

7 0.

6 0.

6 0.

6 0.

6 0.

6 0.

6 0.

5 0.

5 0.

5

- C

ogen

erat

ion

MW

90

90

794

1,51

4 1,

604

1,87

4 2,

144

2,41

4 2,

684

2,95

4 3,

224

3,60

4 3,

964

4,32

4 4,

684

5,04

4 5,

404

5,76

4 6,

124

6,48

4 7,

024

%0.

3 0.

3 2.

3 4.

1 4.

0 4.

7 5.

2 5.

7 6.

3 6.

7 7.

2 7.

6 8.

1 8.

4 8.

9 9.

6 9.

5 10

.1

10.0

10

.2

10.7

Subt

otal

MW

180

340

1,10

9 1,

829

1,91

9 2,

189

2,45

9 2,

729

2,99

9 3,

269

3,53

9 3,

919

4,27

9 4,

639

4,99

9 5,

359

5,71

9 6,

079

6,43

9 6,

799

7,33

9 %

0.6

1.0

3.2

4.9

4.8

5.5

5.9

6.4

7.0

7.4

7.9

8.2

8.7

9.1

9.5

10.2

10

.0

10.7

10

.5

10.7

11

.2

MW

367

625

787

974

1,16

6 1,

333

1,56

3 1,

792

1,96

8 2,

145

2,33

5 2,

470

2,76

4 2,

910

3,05

8 3,

221

3,38

0 3,

549

3,72

2 3,

901

4,08

0 %

1.2

1.9

2.3

2.6

2.9

3.3

3.8

4.2

4.6

4.8

5.2

5.2

5.6

5.7

5.8

6.1

5.9

6.2

6.1

6.1

6.2

MW

300

300

300

300

300

300

300

300

300

300

300

300

300

300

300

300

300

300

300

300

300

%1.

0 0.

9 0.

9 0.

8 0.

8 0.

8 0.

7 0.

7 0.

7 0.

7 0.

7 0.

6 0.

6 0.

6 0.

6 0.

6 0.

5 0.

5 0.

5 0.

5 0.

5

- EG

AT

MW

-

-

-

-

-

-

-

-

-

-

1,00

0 2,

000

2,00

0 2,

000

3,00

0 4,

000

4,00

0 4,

000

5,00

0 5,

000

5,00

0 %

-

-

-

-

-

-

-

-

-

-

2.2

4.2

4.1

3.9

5.7

7.6

7.0

7.0

8.2

7.8

7.6

MW

31,3

49

32,9

92

34,1

72

37,0

03

39,7

20

39,9

90

41,4

19

42,3

74

42,6

19

44,2

89

44,8

42

47,6

18

48,9

82

51,2

35

52,5

23

52,7

82

56,9

56

56,8

30

61,3

55

63,8

24

65,5

47

%10

0.0

100.

0 10

0.0

100.

0 10

0.0

100.

0 10

0.0

100.

0 10

0.0

100.

0 10

0.0

100.

0 10

0.0

100.

0 10

0.0

100.

0 10

0.0

100.

0 10

0.0

100.

0 10

0.0

Uni

tsY

ear

Hyd

ro/

Fore

ign

Purc

hase

d

VSP

P

EGA

T - T

NB

, H

VD

C

Pow

er P

lant

Typ

es

Nuc

lear

Tota

l

Ther

mal

Com

bine

Cyc

le

Gas

Tur

bine

and

Die

sel

Ren

ewab

le E

nerg

y

SPP

( Add

ition

al

Purc

hase

)

87

Appendix 7

Power Plant Retirement Schedule

89

Retirement Schedule

Power Plant Retirement Date

EGAT Power PlantThermal

Mae Moh # 4 140 31 December 2023# 5 140 31 December 2024# 6 140 31 December 2024# 7 140 31 December 2025# 8 270 31 December 2028# 9 270 31 December 2029# 10 270 31 December 2030# 11 270 31 December 2031# 12 270 31 December 2034# 13 270 31 December 2035

Bang Pakong # 1 525.5 31 December 2013# 2 526.5 31 December 2013# 3 576 31 December 2021# 4 576 31 December 2022

Krabi # 1 315 31 December 2033

Combine CycleBang Pakong # 3 314 31 December 2016

# 4 314 31 December 2017

Nam Pong # 1 325 31 December 2017# 2 325 31 December 2019

South Bangkok # 1 316 31 December 2019# 2 562 31 December 2022

Wang Noi # 1 612 31 December 2022# 2 612 31 December 2022# 3 686 31 December 2022

Chana # 1 710 31 December 2033

Private Power PlantThermal

Khanom PPB # 1 69.9 18 June 2011# 2 70.2 18 June 2016

Ratchaburi # 1 720 30 October 2025# 2 720 30 October 2025

BLCP Power Co.,Ltd (BLCP) # 1 673.25 30 September 2031# 2 673.25 31 January 2032

Combine CycleRayong # 1 294.7 6 December 2014

# 2 287.7 6 December 2014# 3 289.8 6 December 2014# 4 302.9 6 December 2014

Khanom PPB # 1 678 18 June 2016

Ratchaburi # 1 685 17 April 2027

# 2 675 17 April 2027

# 3 681 31 October 2027Independent Power Producer (Thailand) Co. ,Ltd (IPT)# 1 700 14 August 2025Eastern Power & Electric Co. ,Ltd (EPEC) # 1 350 24 March 2023Tri Energy Co.,Ltd (TECO) # 1 700 30 June 2020Glow IPP Co.,Ltd # 1 713 30 January 2028Ratchaburi Power Co.,Ltd # 1 700 28 February 2033

# 2 700 31 May 2033Gulf Power Generation Co.,Ltd # 1 734 28 February 2032

# 2 734 29 February 2033

Capacity(MW)

91

Appendix 8 Projection of Energy Generation

Classified by Fuel Types

93

PROJ

ECTIO

N OF G

ENER

ATIN

G CAP

ACITY

CLAS

SIFIED

BY FU

EL TY

PES

PDP

2010

Yea

r20

1020

1120

1220

1320

1420

1520

1620

1720

1820

1920

2020

2120

2220

2320

2420

2520

2620

2720

2820

2920

30-

EGA

TG

Wh

5,91

4 5,

782

5,66

8 5,

775

5,71

5 5,

815

5,81

5 5,

960

6,06

5 6,

065

6,06

5 6,

065

6,06

5 6,

065

6,06

5 6,

065

6,06

5 6,

065

6,06

5 6,

065

6,06

5 %

3.9

3.6

3.4

3.3

3.1

3.0

2.9

2.9

2.8

2.7

2.6

2.5

2.4

2.3

2.2

2.1

2.0

2.0

1.9

1.8

1.7

- La

o PD

RG

Wh

7,95

1 10

,511

11

,239

11

,402

11

,439

14

,349

22

,109

24

,496

24

,496

24

,499

24

,529

24

,505

24

,502

23

,263

23

,289

23

,254

23

,114

23

,252

22

,916

22

,858

22

,637

%

5.2

6.6

6.7

6.5

6.2

7.5

11.1

11

.7

11.2

10

.8

10.4

9.

9 9.

6 8.

7 8.

4 8.

1 7.

7 7.

5 7.

1 6.

8 6.

5

- M

yanm

arG

Wh

-

-

-

-

-

-

2,06

7 2,

819

2,81

8 2,

818

2,82

7 2,

817

2,81

5 2,

813

2,82

1 2,

814

2,81

2 2,

811

2,67

3 2,

647

2,81

1 %

-

-

-

-

-

-

1.0

1.4

1.3

1.2

1.2

1.1

1.1

1.1

1.0

1.0

0.9

0.9

0.8

0.8

0.8

- Fo

reig

n Pu

rcha

seG

Wh

-

-

-

-

-

-

-

-

1,45

5 4,

250

7,33

0 11

,549

14

,628

17

,708

20

,788

23

,867

26

,947

30

,027

33

,106

36

,186

39

,266

%

-

-

-

-

-

-

-

-

0.7

1.9

3.1

4.7

5.7

6.6

7.5

8.3

9.0

9.7

10.3

10

.8

11.3

Subt

otal

GW

h13

,865

16

,293

16

,907

17

,177

17

,153

20

,163

29

,990

33

,275

34

,834

37

,632

40

,750

44

,935

48

,010

49

,849

52

,962

56

,001

58

,938

62

,155

64

,760

67

,756

70

,778

%

9.1

10.2

10

.1

9.8

9.4

10.5

15

.0

15.9

15

.9

16.5

17

.2

18.2

18

.7

18.7

19

.1

19.5

19

.7

20.0

20

.1

20.2

20

.3

- EG

AT

GW

h39

,365

41

,426

39

,636

35

,123

40

,384

37

,455

36

,914

37

,148

35

,907

35

,897

33

,495

32

,405

31

,877

24

,559

24

,694

22

,456

13

,214

13

,037

5,

244

4,72

1 5,

418

%25

.7

25.8

23

.6

20.0

22

.0

19.6

18

.5

17.8

16

.4

15.8

14

.1

13.1

12

.4

9.2

8.9

7.8

4.4

4.2

1.6

1.4

1.6

MM

CFD

860

900

837

738

827

713

701

709

678

678

621

602

592

458

459

419

247

244

98

88

101

- IP

PG

Wh

55,5

77

54,7

45

56,7

21

58,8

26

57,1

31

59,2

46

53,3

08

53,5

23

60,2

91

60,9

44

58,2

20

51,8

80

47,4

85

24,3

06

24,5

02

22,7

76

15,7

41

15,2

72

2,67

0 1,

598

2,52

3 %

36.3

34

.1

33.8

33

.5

31.1

31

.0

26.7

25

.6

27.6

26

.8

24.6

21

.0

18.5

9.

1 8.

9 7.

9 5.

3 4.

9 0.

8 0.

5 0.

7

MM

CFD

1,12

6 1,

102

1,14

0 1,

169

1,13

6 1,

149

1,02

1 1,

019

1,15

0 1,

163

1,10

6 98

6 90

1 45

4 45

7 42

6 29

5 28

7 52

31

49

- SP

PG

Wh

9,27

5 9,

301

9,20

7 9,

123

9,05

6 9,

902

9,90

2 9,

272

8,47

3 8,

049

6,36

7 5,

286

4,15

9 3,

225

1,38

4 47

3 -

-

-

-

-

%

6.1

5.8

5.5

5.2

4.9

5.2

5.0

4.4

3.9

3.5

2.7

2.1

1.6

1.2

0.5

0.2

-

-

-

-

-

- New

pow

er p

lant

GW

h-

-

-

-

-

-

2,

869

6,18

3 6,

185

6,19

2 6,

215

6,17

6 12

,362

42

,821

42

,956

48

,797

60

,003

66

,081

72

,915

77

,658

78

,217

%

-

-

-

-

-

-

1.4

3.0

2.8

2.7

2.6

2.5

4.8

16.1

15

.5

17.0

20

.1

21.3

22

.6

23.2

22

.5

MM

CFD

-

-

-

-

-

-

53

115

115

115

115

114

230

798

799

911

1,12

3 1,

236

1,38

2 1,

478

1,48

7

Subt

otal

GW

h10

4,21

6 10

5,47

1 10

5,56

4 10

3,07

2 10

6,57

1 10

6,60

3 10

2,99

4 10

6,12

6 11

0,85

6 11

1,08

2 10

4,29

7 95

,747

95

,883

94

,911

93

,537

94

,503

88

,958

94

,390

80

,829

83

,977

86

,159

%

68.1

65

.8

62.8

58

.7

58.1

55

.8

51.5

50

.7

50.7

48

.8

44.0

38

.8

37.4

35

.6

33.8

32

.9

29.8

30

.4

25.1

25

.1

24.8

MM

CFD

1,98

6 2,

003

1,97

8 1,

907

1,96

3 1,

862

1,77

4 1,

843

1,94

3 1,

955

1,84

2 1,

702

1,72

2 1,

711

1,71

5 1,

755

1,66

5 1,

767

1,53

1 1,

598

1,63

7

- EG

AT

GW

h64

3 20

5 72

7 1,

130

625

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

%0.

4 0.

1 0.

4 0.

6 0.

3 -

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

MLi

ters

166.

52

66.0

4 23

4.47

36

4.11

20

1.35

-

- -

- -

- -

- -

- -

- -

- -

-

- IP

PG

Wh

234

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

%0.

2 -

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

MLi

ters

60.0

0 -

- -

- -

- -

- -

- -

- -

- -

- -

- -

-

- SP

PG

Wh

33

33

33

33

33

32

32

32

32

16

-

-

-

-

-

-

-

-

-

-

-

%0.

0 0.

0 0.

0 0.

0 0.

0 0.

0 0.

0 0.

0 0.

0 0.

0 -

-

-

-

-

-

-

-

-

-

-

Subt

otal

GW

h91

0 23

8 76

0 1,

163

658

32

32

32

32

16

-

-

-

-

-

-

-

-

-

-

-

%0.

6 0.

2 0.

5 0.

7 0.

4 0.

0 0.

0 0.

0 0.

0 0.

0 -

-

-

-

-

-

-

-

-

-

-

MLi

ters

227

66

234

364

201

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

- EG

AT

GW

h11

2 28

28

91

81

26

26

26

23

23

21

21

21

21

21

21

21

21

21

21

21

%

0.1

0.0

0.0

0.1

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

MLi

ters

25.7

4 9.

30

9.05

22

.73

19.1

0 7.

20

7.22

7.

00

6.30

6.

30

5.61

5.

60

5.60

5.

60

5.61

5.

60

5.60

5.

60

5.61

5.

60

5.60

- EG

AT

GW

h16

,359

17

,075

16

,693

17

,079

16

,739

17

,153

17

,202

17

,153

17

,153

17

,153

17

,202

17

,153

17

,153

17

,153

16

,107

13

,875

12

,782

12

,782

12

,819

10

,652

8,

522

%10

.7

10.7

9.

9 9.

7 9.

1 9.

0 8.

6 8.

2 7.

8 7.

5 7.

3 7.

0 6.

7 6.

4 5.

8 4.

8 4.

3 4.

1 4.

0 3.

2 2.

5

MTo

ns15

.94

16.4

2 16

.04

16.4

2 16

.08

17.1

9 16

.98

16.0

3 14

.84

15.0

8 15

.22

15.1

7 15

.17

15.1

7 13

.89

11.7

7 10

.68

10.6

8 10

.72

8.90

6.

92

- EG

AT

GW

h-

-

-

-

-

-

-

-

-

3,

375

6,12

5 9,

476

12,2

00

18,2

61

18,3

02

18,2

37

30,4

24

30,3

29

42,5

38

48,4

65

53,9

31

%-

-

-

-

-

-

-

-

-

1.

5 2.

6 3.

8 4.

8 6.

9 6.

6 6.

3 10

.2

9.8

13.2

14

.5

15.5

M

Tons

-

-

-

-

-

-

-

-

-

1.23

2.

23

3.45

4.

44

6.64

6.

66

6.63

11

.07

11.0

3 15

.48

17.6

3 19

.62

- IP

PG

Wh

10,0

26

11,4

43

15,1

08

15,0

54

18,2

56

19,4

61

19,5

15

19,4

64

19,4

62

19,4

64

19,5

21

19,4

64

19,4

64

19,4

55

19,5

14

19,4

51

19,4

48

19,4

52

19,4

83

19,4

27

19,4

37

%6.

6 7.

1 9.

0 8.

6 10

.0

10.2

9.

8 9.

3 8.

9 8.

6 8.

2 7.

9 7.

6 7.

3 7.

1 6.

8 6.

5 6.

3 6.

0 5.

8 5.

6

MTo

ns3.

65

4.16

5.

47

5.50

6.

88

6.99

7.

01

6.99

6.

99

6.99

7.

01

6.99

6.

99

6.98

7.

01

6.98

6.

98

6.98

6.

99

6.97

6.

98

- SP

PG

Wh

2,29

4 2,

323

2,36

0 2,

420

2,36

9 2,

593

2,59

3 2,

593

2,52

9 2,

523

2,52

3 2,

523

2,52

3 2,

523

1,47

2 15

8 -

-

-

-

-

%

1.5

1.5

1.4

1.4

1.3

1.4

1.3

1.2

1.2

1.1

1.1

1.0

1.0

1.0

0.5

0.1

-

-

-

-

-

Subt

otal

GW

h12

,320

13

,766

17

,468

17

,473

20

,625

22

,054

22

,108

22

,057

21

,991

25

,362

28

,170

31

,463

34

,187

40

,239

39

,288

37

,845

49

,871

49

,781

62

,021

67

,892

73

,368

%

8.1

8.6

10.4

10

.0

11.2

11

.5

11.1

10

.5

10.1

11

.1

11.9

12

.8

13.3

15

.1

14.2

13

.2

16.7

16

.0

19.2

20

.3

21.1

MTo

ns3.

65

4.16

5.

47

5.50

6.

88

6.99

7.

01

6.99

6.

99

8.22

9.

24

10.4

3 11

.43

13.6

3 13

.66

13.6

2 18

.05

18.0

2 22

.47

24.6

1 26

.60

- EG

AT

GW

h46

30

4 31

6 40

3 50

1 69

5 77

5 82

1 90

7 92

8 1,

044

1,21

2 1,

293

1,29

3 1,

293

1,29

3 1,

293

1,29

3 1,

293

1,29

2 1,

292

%0.

0 0.

2 0.

2 0.

2 0.

3 0.

4 0.

4 0.

4 0.

4 0.

4 0.

4 0.

5 0.

5 0.

5 0.

5 0.

5 0.

4 0.

4 0.

4 0.

4 0.

4

- SP

P Fi

rmG

Wh

2,17

0 2,

223

2,30

8 2,

420

2,24

9 1,

999

1,99

9 1,

999

1,99

9 1,

999

1,96

2 1,

943

1,94

3 1,

943

1,71

6 1,

418

1,13

4 1,

018

796

343

343

%1.

4 1.

4 1.

4 1.

4 1.

2 1.

1 1.

0 1.

0 0.

9 0.

9 0.

8 0.

8 0.

8 0.

7 0.

6 0.

5 0.

4 0.

3 0.

3 0.

1 0.

1

- SP

P N

on F

irmG

Wh

601

515

515

515

515

1,80

6 1,

806

1,80

6 1,

806

1,80

6 1,

806

1,80

6 1,

806

1,80

6 1,

806

1,80

6 1,

806

1,80

6 1,

806

1,80

6 1,

806

%0.

4 0.

3 0.

3 0.

3 0.

3 0.

9 0.

9 0.

9 0.

8 0.

8 0.

8 0.

7 0.

7 0.

7 0.

7 0.

6 0.

6 0.

6 0.

6 0.

5 0.

5

Subt

otal

GW

h2,

817

3,04

3 3,

139

3,33

9 3,

265

4,50

1 4,

580

4,62

6 4,

713

4,73

3 4,

812

4,96

2 5,

043

5,04

3 4,

815

4,51

7 4,

234

4,11

7 3,

896

3,44

1 3,

441

%1.

8 1.

9 1.

9 1.

9 1.

8 2.

4 2.

3 2.

2 2.

2 2.

1 2.

0 2.

0 2.

0 1.

9 1.

7 1.

6 1.

4 1.

3 1.

2 1.

0 1.

0

- Ren

ewab

leG

Wh

385

806

1,38

7 2,

348

2,34

8 2,

348

2,34

8 2,

348

2,34

8 2,

348

2,34

8 2,

348

2,34

8 2,

348

2,34

8 2,

348

2,34

8 2,

348

2,34

8 2,

348

2,34

8 %

0.3

0.5

0.8

1.3

1.3

1.2

1.2

1.1

1.1

1.0

1.0

1.0

0.9

0.9

0.9

0.8

0.8

0.8

0.7

0.7

0.7

GW

h10

5 63

1 1,

984

8,61

3 10

,978

12

,345

14

,237

16

,129

18

,809

20

,702

22

,594

25

,257

27

,780

30

,303

32

,825

35

,348

37

,871

40

,394

42

,917

45

,440

49

,224

%

0.1

0.4

1.2

4.9

6.0

6.5

7.1

7.7

8.6

9.1

9.5

10.2

10

.8

11.4

11

.9

12.3

12

.7

13.0

13

.3

13.6

14

.2

Subt

otal

GW

h49

1 1,

437

3,37

1 10

,961

13

,326

14

,692

16

,584

18

,477

21

,157

23

,049

24

,941

27

,605

30

,127

32

,650

35

,173

37

,696

40

,219

42

,742

45

,265

47

,788

51

,572

%

0.3

0.9

2.0

6.2

7.3

7.7

8.3

8.8

9.7

10.1

10

.5

11.2

11

.8

12.3

12

.7

13.1

13

.5

13.8

14

.0

14.3

14

.8

- Ren

ewab

leG

Wh

1,50

2 2,

636

3,06

4 3,

718

4,28

0 4,

732

5,19

3 6,

199

6,65

4 7,

063

7,57

1 8,

004

9,15

4 9,

683

10,2

14

10,7

97

11,3

82

12,0

20

12,6

59

13,3

51

14,0

44

%1.

0 1.

6 1.

8 2.

1 2.

3 2.

5 2.

6 3.

0 3.

0 3.

1 3.

2 3.

2 3.

6 3.

6 3.

7 3.

8 3.

8 3.

9 3.

9 4.

0 4.

0

GW

h50

92

12

3 25

3 28

0 33

0 36

1 42

1 47

0 54

7 58

4 61

6 68

0 71

4 75

0 82

2 86

3 86

7 88

8 88

8 88

8 %

0.0

0.1

0.1

0.1

0.2

0.2

0.2

0.2

0.2

0.2

0.3

0.3

0.3

0.3

0.3

0.3

0.3

0.3

0.3

0.3

0.3

Subt

otal

GW

h1,

552

2,72

7 3,

187

3,97

1 4,

560

5,06

1 5,

554

6,62

1 7,

124

7,61

0 8,

155

8,62

0 9,

834

10,3

97

10,9

64

11,6

20

12,2

45

12,8

87

13,5

47

14,2

39

14,9

32

%1.

0 1.

7 1.

9 2.

3 2.

5 2.

7 2.

8 3.

2 3.

3 3.

3 3.

4 3.

5 3.

8 3.

9 4.

0 4.

0 4.

1 4.

2 4.

2 4.

3 4.

3

GW

h31

3 25

3 93

1 1,

305

475

939

941

939

939

939

941

939

939

939

941

939

939

939

941

939

939

%0.

2 0.

2 0.

6 0.

7 0.

3 0.

5 0.

5 0.

5 0.

4 0.

4 0.

4 0.

4 0.

4 0.

4 0.

3 0.

3 0.

3 0.

3 0.

3 0.

3 0.

3

- EG

AT

GW

h-

-

-

-

-

-

-

-

-

-

7,

666

15,2

86

15,2

86

15,2

86

22,9

98

30,5

73

30,5

73

30,5

73

38,3

29

38,2

16

38,2

16

%-

-

-

-

-

-

-

-

-

-

3.

2 6.

2 6.

0 5.

7 8.

3 10

.6

10.2

9.

9 11

.9

11.4

11

.0

Tons

-

-

-

-

-

-

-

-

-

-

18.5

8 37

.05

37.0

5 37

.05

55.7

4 74

.10

74.1

0 74

.10

92.9

1 92

.63

92.6

3 G

Wh

152,

954

160,

331

168,

049

175,

631

183,

452

191,

224

200,

012

209,

329

218,

820

227,

599

236,

956

246,

730

256,

483

266,

488

276,

805

287,

589

298,

779

310,

387

322,

428

334,

922

347,

948

Impo

rted

Coa

l

Ren

ewab

le E

nerg

y

Nuc

lear

SPP

( Add

ition

al

Purc

hase

)

EGA

T - T

NB

, H

VD

C

- Cog

ener

atio

n

VSP

P

- Cog

ener

atio

n

Tota

l

Fuel

Typ

esU

nits

Hyd

ro /

Fore

ign

Purc

hase

d

Nat

ural

Gas

/ LN

G

Hea

vy O

il

Die

sel

Lign

ite

95

Appendix 9 Renewable Energy and Purchasement Plan

From SPP and VSPP

97

Ad

der R

ate fo

r S

PP

s a

nd

V

SP

Ps U

sin

g R

en

ew

ab

le E

nerg

y

En

erg

y S

ou

rce

Co

un

try

wid

e E

xcep

t

Th

e 3

M

ost S

ou

th

ern

Pro

vin

ces

(B

ah

t/k

Wh

)

Th

e 3

M

ost

So

uth

ern

Pro

vin

ces

(B

ah

t/k

Wh

)

Area

s U

sin

g

Diesel E

ng

in

es

(B

ah

t/k

Wh

)

Su

bsid

ized

Perio

d

(Y

ea

rs)

Biom

ass

Cont

ract

Cap

acity

1

MW

Cont

ract

Cap

acity

> 1

MW

0.5

0.3

1.5

1.3

1.5

1.3

7

Biog

as Cont

ract

Cap

acity

1

MW

Cont

ract

Cap

acity

> 1

MW

0.5

0.3

1.5

1.3

1.5

1.3

7

Smal

l, M

icro

& M

ini H

ydro

elec

tric

50 k

W

Cont

ract

Cap

acity

< 2

00 k

WCo

ntra

ct C

apac

ity <

50

kW0.

81.

51.

82.

51.

82.

57

Was

te-A

naer

obic

Dig

estio

n / L

andf

ill

- The

rmal

Pro

cess

2.5

3.5

3.5

4.5

3.5

4.5

7

Win

d En

ergy

Cont

ract

Cap

acity

5

0 kW

Cont

ract

Cap

acity

> 5

0 kW

4.5

3.5

6.0

5.0

6.0

5.0

10

Sola

r Ene

rgy

8.0

9.5

9.5

10So

urce

: Res

olut

ion

of th

e 12

4th(2

/200

9) M

eetin

g of

NEP

C o

n 9th

Mar

ch 2

009

100

List of SPPs During Consideration of Purchasing

(as of 31 January 2010)

Unit : MW

Fuel Type Capacity Contracted Capacity

Existing Projects

- Firm 3,389.1 2,092.3

Natural gas 2,260.8 1,413.0

Coal 703.0 369.5

Heavy Oil 10.4 4.5

Black Liquor 32.9 25.0

Rice Husk and Wood Residue 211.6 167.5

Bagasse. 160.5 104.0

Palm cluster , Palm fiber , Palm shell 9.9 8.8

- Non-Firm 707.8 248.6

Natural gas 355.0 110.0

Coal 165.2 59.0

By-product gas from crude oil refinery 2.0 1.7

Rice Husk and Wood Residue 9.0 5.9

Bagasse. 157.6 66.0

Waste Gas 19.0 6.0

Subtotal 4,096.9 2,340.9

Future Projects

- Firm

- Project during 2010 - 2014

- Already Coordinated with EGAT 2,372.3 1,694.0

- Under Coordination with EGAT 250.0 225.0

- Project during 2015 - 2021 - 2,000.0

- Project during 2022 - 2030 - 3,420.0

- Non-Firm

- Already Coordinated with EGAT 620.6 468.0

- Under Coordination with EGAT - 300.0

Subtotal 3,242.9 8,107.0

Total SPP Projects

Firm 6,011.4 9,431.3

Non-Firm 1,328.4 1,016.6

Grand Total 7,339.8 10,447.9

Source : Power Purchase Agreement Division and System Planning Division , EGAT

101

No.

of

Proj

ects

Inst

alle

d C

ap.

(MW

)

Con

trac

t

Cap

. (M

W)

No.

of

Proj

ects

Inst

alle

d C

ap.

(MW

)

Con

trac

t

Cap

. (M

W)

No.

of

Proj

ects

Inst

alle

d C

ap.

(MW

)

Con

trac

t

Cap

. (M

W)

No.

of

Proj

ects

Inst

alle

d C

ap.

(MW

)

Con

trac

t

Cap

. (M

W)

Com

mer

cial

Fue

lsC

oal

-

-

-

-

-

-

4

14

7.9

24.0

2

19.0

6.0

N

atur

al G

as3

7.

8

7.5

1

3.

6

3.6

7

36

.8

29

.6

-

-

-

Tota

l : C

omm

erci

al F

uels

3

7.8

7.

5

1

3.6

3.

6

11

18

4.6

53.6

2

19.0

6.0

A

ltern

ativ

e En

ergy

Sou

rces

1So

lar

Ener

gy13

5

64

9.2

63

7.6

94

415.

3

39

8.4

291

1,42

1.8

1,

331.

9

51

7.

8

7.7

PV

52

13

8.7

12

9.6

67

275.

8

26

6.7

25

98

.1

93

.3

51

7.8

7.

7

T

herm

al83

510.

5

508.

0

27

13

9.5

131.

6

26

6

1,

323.

7

1,23

8.6

-

-

-

-

Para

bolic

Tro

ugh

11

64

.5

62

.0

7

51

.1

45

.0

46

286.

9

27

2.3

-

-

-

- St

irlin

g E

ngin

e46

276.

0

276.

0

8

48.0

48.0

149

874.

3

87

4.3

-

-

-

- O

ther

s (S

olar

The

rmal

)7

56

.0

56

.0

10

28.4

26.6

71

16

2.5

92.0

-

-

-

- U

nspe

cifie

d T

echn

olog

y19

114.

0

114.

0

2

12.0

12.0

-

-

-

-

-

-

2Bi

ogas

21

68

.5

61

.6

31

52.4

44.8

32

80

.7

69

.2

41

51.0

43.0

M

anur

e-

-

-

2

0.

2

0.1

4

1.

4

1.3

8

1.

6

1.3

Ind

ustr

ial S

ewag

e20

66.6

60.6

19

46

.3

39

.1

25

76.1

64.7

29

47

.6

40

.1

Str

aw-

-

-

4

1.

3

1.3

-

-

-

4

1.8

1.

7

O

ther

s (P

arag

rass

or B

uffa

lo G

rass

, Bio

gas)

1

1.9

1.

0

6

4.7

4.

3

3

3.2

3.

2

-

-

-

3

Biom

ass

65

53

9.9

41

3.7

36

275.

0

21

3.4

201

1,97

0.9

1,

495.

9

53

72

0.0

287.

8

Pal

m F

iber

, Pal

m S

hell

-

-

-

2

2.8

2.

0

1

9.5

8.

0

1

12.0

8.5

Jat

roph

a Fi

ber

-

-

-

1

9.5

8.

0

1

9.5

8.

0

-

-

-

Bag

asse

2

38.0

8.0

1

18

.0

6.

0

12

25

8.0

92.0

29

53

0.8

164.

3

Bag

asse

+ R

ice

Hus

k-

-

-

-

-

-

-

-

-

1

39

.4

8.

0

R

ice

Hus

k9

75

.6

63

.5

7

62

.7

53

.2

35

314.

9

26

7.9

13

71

.5

67

.4

Ric

e H

usk

+ W

ood

Res

idue

/ W

ood

Chi

p10

92.1

73.5

3

29.3

24.0

93

91

6.8

742.

5

2

27

.1

14

.5

Ric

e H

usk

+ C

ornc

ob-

-

-

-

-

-

1

9.0

7.

8

-

-

-

Saw

dust

-

-

-

-

-

-

-

-

-

1

0.6

0.

6

C

ocon

ut F

iber

2

2.4

2.

0

3

19.5

16.2

1

6.0

5.

0

-

-

-

Cor

ncob

/ C

orn

Res

idue

1

1.8

1.

8

-

-

-

1

9.

9

8.0

1

-

-

Cor

ncob

+ R

ice

Hus

k1

9.

9

8.0

-

-

-

1

6.0

5.

4

-

-

-

Pal

m C

lust

er2

17

.5

12

.3

3

22

.0

20

.0

6

48

.5

36

.5

4

26

.5

18

.2

Bar

k1

7.

5

6.8

-

-

-

1

6.0

5.

5

-

-

-

Str

aw-

-

-

1

0.

2

0.2

-

-

-

-

-

-

Cas

sava

(Fib

er+

Rhi

zom

e)-

-

-

-

-

-

4

21.9

17.6

-

-

-

Fas

t Gro

win

g T

ree

-

-

-

1

1.4

1.

0

5

24.3

21.3

-

-

-

Woo

d R

esid

ue /

Woo

d C

hip

37

29

5.1

23

7.9

11

80.2

65.9

38

32

5.5

265.

6

1

12

.0

6.

2

O

ther

s-

-

-

3

29

.4

17

.0

1

5.

1

4.8

-

-

-

4M

unic

ipal

Was

te20

140.

4

120.

6

13

74

.6

59

.5

14

108.

6

96

.4

8

12

.5

10

.8

Gas

Eng

ine

6

24.2

22.8

5

15.3

15.0

5

32.9

31.3

6

6.3

5.

8

S

team

Fer

bine

3

22.0

18.8

6

48.2

39.0

8

70.5

60.1

2

6.2

5.

0

G

asifi

catio

n1

6.

0

6.0

1

1.

2

1.0

1

5.

1

5.0

-

-

-

U

nspe

cifie

d T

echn

olog

y10

88.2

73.0

1

9.9

4.

5

-

-

-

-

-

-

5Sm

all,

Min

i and

Mic

ro H

ydro

1

0.0

0.

0

1

5.0

5.

0

5

1.3

1.

3

3

0.6

0.

5

<

50

kW1

0.

0

0.0

-

-

-

1

0.0

0.

0

2

0.1

0.

1

5

0 - 2

00 k

W-

-

-

-

-

-

2

0.2

0.

2

-

-

-

> 2

00 k

W *

-

-

-

1

5.0

5.

0

2

1.1

1.

1

1

0.5

0.

5

6W

ind

Ener

gy13

94.1

85.3

7

18.1

17.8

5

26.4

25.0

3

0.4

0.

4

7U

sed

Veg

etab

le O

il*-

-

-

-

-

-

1

0.0

0.

0

-

-

-

To

tal :

Alte

rnat

ive

Ener

gy S

ourc

es25

5

1,

492.

1

1,

318.

8

18

2

84

0.4

738.

8

54

9

3,

609.

7

3,01

9.6

15

9

79

2.3

350.

3

Gra

nd T

otal

258

1,49

9.9

1,32

6.2

183

844.

0

74

2.4

560

3,79

4.3

3,

073.

2

161

811.

3

35

6.3

Pres

ent S

tatu

s of V

SPP

Cla

ssifi

ed b

y Fu

el T

ype

(Inc

ludi

ng M

EA a

nd P

EA)

(As o

f 31

Janu

ary

2010

)

Und

er C

onsid

erat

ion

Proc

ess

App

rove

d (W

aitin

g fo

r PP

A S

ign)

PPA

Sig

ned

(Wai

ting

for

CO

D)

Alr

eady

Com

miss

ione

d

Fuel

Typ

e/T

echn

olog

y

102

SCO

D o

f Hig

h Po

tent

ial V

SPPs

Cla

ssifi

ed b

y En

ergy

Sou

rce

(As o

f 31

Jan

uary

201

0)

SCO

D

2010

2011

2012

2013

No.

of

Purc

hase

Cap

.N

o. o

fPu

rcha

se C

ap.

No.

of

Purc

hase

Cap

.N

o. o

fPu

rcha

se C

ap.

No.

of

Purc

hase

Cap

.

Proj

ects

(MW

)Pr

ojec

ts(M

W)

Proj

ects

(MW

)Pr

ojec

ts(M

W)

Proj

ects

(MW

)

Bio

mas

s19

130.8

4

28.

8

6

43.

6

-

-

29

203.2

B

ioga

s8

19.

0

6

16.

2

-

-

-

-

14

35.2

Sola

r E

nerg

y1

1.3

2

5.6

11

26.0

5

33.0

19

65.

8

W

aste

5

36.0

-

-

-

-

-

-

5

36.0

Win

d E

nerg

y-

-

1

4.8

3

20.7

-

-

4

25.5

Hyd

ro3

1.1

-

-

-

-

-

-

3

1.1

T

otal

36

18

8.2

13

55.4

20

90

.3

5

33.0

74

36

6.9

Sourc

e : Pro

vincia

l Elec

tricity

Autho

rity (P

EA)

Ene

rgy

Sour

ce

Tot

al

103

Appendix 10 Transmission System Expansion Projects

105

DETA

ILS OF

TRAN

SMISS

ION S

YSTE

M EX

PANS

ION P

ROGR

AM( P

DP 20

10 )

Item

sN

ame

of T

rans

mis

sion

Lin

es a

nd S

ubst

atio

nsL

engt

hN

umbe

r of

V

olta

geC

ondu

ctor

Siz

eC

omm

issi

onin

g

Dat

e

(k

m)

Cir

cuit

(kV

)(M

CM

)(Y

ear)

A.

TRAN

SMISS

ION E

XPAN

SION P

ROJE

CTS A

SSOC

IATE

D WITH

GENE

RATIO

N PRO

JECT

S1.

FUTU

RE PR

OJEC

TS

1.1 C

OAL-F

IRED

THER

MAL P

OWER

PLAN

T PRO

JECT

S

1

.1.1

Coa

l-F

ired

The

rmal

Pow

er P

lant

Uni

t 1-6

(6x

800

MW

)-

-50

04x

1272

2019

-202

6

1.1

.2 C

oal-

Fir

ed T

herm

al P

ower

Pla

nt U

nit 7

-11

(5x8

00 M

W)

--

500

4x12

7220

28-2

030

S

ubto

tal

-

1.2

NUC

LEAR

POWE

R PLA

NT PR

OJEC

TS

1

.2.1

Nuc

lear

Pow

er P

lant

Uni

t 1-5

(5x

1000

MW

)-

-50

04x

1272

2020

-202

8

S

ubto

tal

-

1.3

COM

BINED

CYCL

E POW

ER PL

ANT P

ROJE

CTS

1.3

.1 C

ombi

ned

Cyc

le P

ower

Pla

nt B

lock

1-6

(6x

800

MW

)-

-23

0/50

02x

1272

/ 4x

1272

2022

-202

5

1.3

.2 C

ombi

ned

Cyc

le P

ower

Pla

nt B

lock

7-1

2 (6

x800

MW

)-

-23

0/50

02x

1272

/ 4x

1272

2026

-202

9

S

ubto

tal

-

Not

es :

1/

Und

er s

tudy

for

tran

smis

sion

sys

tem

dev

elop

men

t

1/1/

1/1/

1/1/

1/1/

1/1/

107

DE

TA

IL

S O

F T

RA

NS

MIS

SIO

N S

YS

TE

M E

XP

AN

SIO

N P

RO

GR

AM

(C

on

t.)

( P

DP

2010 )

Item

sN

ame

of T

rans

miss

ion

Line

s and

Sub

statio

nsLe

ngth

Num

ber o

f V

olta

geCo

nduc

tor S

ize

Com

miss

ioni

ng

Dat

e

(k

m)

Circ

uit

(kV

)(M

CM)

(Yea

r)

B.

TR

AN

SM

IS

SIO

N S

YS

TE

M E

XP

AN

SIO

N P

RO

JE

CT

S

1. O

NG

OIN

G P

RO

JE

CT

S

1.1 T

ran

sm

ission

S

ystem

E

xp

an

sion

P

roject N

o. 10

1.1

.1 A

dditi

onal

Tra

nsfo

rmer

s Ins

talla

tion

at E

xisti

ng S

ubsta

tions

--

--

2010

1.1

.2 M

iscel

lane

ous S

yste

m E

xpan

sion

--

--

2010

S

ubto

tal

-

1.2 B

ulk

P

ow

er S

up

ply for th

e G

reater B

an

gk

ok

A

rea P

hase 2

1.2

.1

Impr

ovem

ent o

f Sai

Noi

and

Ban

gkok

Noi

Sub

statio

ns-

-23

0-

2010

1.2

.2

Shun

t Cap

acito

r Ins

talla

tions

--

--

2009

-201

0

1.2

.3

Misc

ella

neou

s Sys

tem

Exp

ansio

n-

--

-20

09-2

010

1.2

.4

Non

g Ch

ok -

On

Nuc

h(1

8.0)

250

04x

1272

2010

1.2

.5

Sect

ioin

aliz

ing

of 2

30 k

V B

ang

Pako

ng -

Bang

Phl

i

and

ext

endi

ng to

Khl

ong

Dan

Sub

statio

n an

d

Con

struc

ting

Bang

Pak

ong

- Klo

ng D

an -

Bang

Phl

i44

223

02x

1272

2010

-201

1

1.2

.6

Add

ition

al T

rans

form

ers I

nsta

llatio

n at

Exi

sting

Sub

statio

ns-

--

-20

10-2

012

Subt

otal

4

4 km

(or 8

8.0

circ

uit-k

ilom

eter

s) a

nd 1

New

subs

tatio

n

Not

es :

1/

On

the e

xisti

ng ri

ght-o

f-way

2/ N

ew su

bsta

tion

3/ U

pgra

ding

ope

ratin

g vo

ltage

from

230

kV

to 5

00 k

V

3/

1/

2/

3/

108

DET

AIL

S O

F TR

AN

SMIS

SIO

N S

YST

EM E

XPA

NSI

ON

PR

OG

RA

M (C

ont.)

( PD

P 20

10)

Item

sN

ame o

f Tra

nsm

issio

n Li

nes a

nd S

ubsta

tions

Leng

thN

umbe

r of

Vol

tage

Cond

ucto

r Siz

eCo

mm

issio

ning

Dat

e

(k

m)

Circ

uit

(kV

)(M

CM)

(Yea

r)

1

.3

500

kV T

rans

mis

sion

Sys

tem

Dev

elop

men

t Pro

ject

for I

PP P

ower

Pla

nts

1.3

.1 P

luak

Dae

ng -

Non

g Ch

ok T

Junc

tion,

third

and

four

th ci

rcui

ts15

92

500

4x12

7220

11

Subt

otal

1

59.0

km

(or 3

18.0

circ

uit-k

ilom

eter

s)

1

.4

Tra

nsm

issi

on S

yste

m D

evel

opm

ent f

or P

ower

Pur

chas

e fro

m L

ao P

DR

(Nam

Ngu

m 2

Hyd

ro P

ower

Pla

nt P

roje

ct)

1.4

.1

Thai

/Lao

bor

der (

Non

g K

hai)

- Udo

n Th

ani 3

802

500

4x12

7220

10

Subt

otal

8

0.0

km (o

r 160

.0 ci

rcui

t-kilo

met

ers)

and

1 N

ew su

bsta

tion

1

.5

Tra

nsm

issi

on S

yste

m E

xpan

sion

Pro

ject

s N

o.11

Cen

tral

Reg

ion

1.5.

1 R

ayon

g 3

- Ray

ong

115

.42

115

2x79

520

10

1.5.

2 K

anch

anab

uri 1

- K

anch

anab

uri 2

142

115

2x79

520

10

1.5.

3 S

ectio

naliz

ing

Wan

g N

oi -

Sara

buri

2

and

exte

ndin

g to

Sar

abur

i 5 S

ubsta

tion

54

230

2x12

7220

11

1.5.

4 T

ha W

ung

- Lop

Bur

i 113

211

52x

795

2011

and

Tha T

ako

- Cha

i Bad

an90

211

579

520

11

1.5.

5 R

atch

abur

i 3 -

Sam

ut S

akho

n 4

- Sam

ut S

akho

n 3

- Sam

Phr

an 2

40/2

5.5/

15.5

2/4/

423

0/23

04x

1272

/2x1

272

2011

(Inva

r)

and

Sam

ut S

akho

n 1

- Sam

ut S

akho

n 3

- Sam

Phr

an 1

(7.1

)/(15

.5)

-11

5/11

52x

795

2011

Not

es :

1/

On

the e

xisti

ng ri

ght-o

f-way

2/ N

ew su

bsta

tion

3/ U

pgra

ding

ope

ratin

g vo

ltage

from

230

kV

to 5

00 k

V

4/ Q

uadr

uple

-circ

uit s

teel

tow

ers

2/1/1/ 1/

1/2/ 1/

3/

1/

3/3/

4/

3/

3/3/

4/4/

109

DETA

ILS OF

TRAN

SMISS

ION S

YSTE

M EX

PANS

ION P

ROGR

AM (C

ont.)

( PDP

2010

)

Nam

e of

Tra

nsm

issio

n Li

nes a

nd S

ubsta

tions

Leng

thN

umbe

r of

Vol

tage

Cond

ucto

r Siz

eCo

mm

issio

ning

Dat

e

(k

m)

Circ

uit

(kV

)(M

CM)

(Yea

r)

Nort

heaste

rn Re

gion

1.5

.6

Udo

n Th

ani 2

- N

ong

Bua

Lam

Phu

(55.

2)1

115

795

2010

a

nd N

ong

Bua

Lam

Phu

- Lo

ei80

211

579

520

11

1.5

.7

Nam

Pho

ng 2

- U

don

Than

i 3

852

500

4x12

7220

11

1.5

.8

Sect

iona

lizin

g La

m T

akho

ng -

Nak

hon

Ratc

hasim

a 2

and

ext

endi

ng to

Sik

hiu

Subs

tatio

n5

423

02x

1272

(GA

P)20

11

and

Sik

hiu

- Nak

hon

Ratc

hasim

a 3

452

230

2x12

7220

11

1.5

.9

Sur

in 2

- ( S

urin

1) -

Bur

i Ram

2/46

223

012

7220

11

1.5

.10

Ro

i Et 1

- M

aha

Sara

kham

382

115

2x79

520

11

Sout

hern R

egion

1.5

.11

Kra

bi -

Phan

gnga

2 -

Phuk

et 3

98/(7

6.9)

2/2

230/

230

2x12

72/1

272

2011

1/ N

ew su

bsta

tion

2/ O

n th

e ex

istin

g rig

ht-o

f-w

ay

3/ I

nitia

lly e

nerg

ized

at 1

15 k

V

4/ I

nitia

lly e

nerg

ized

at 2

30 k

V

5/ L

ine

strin

ging

on

the

exis

ting

stee

l tow

ers

6/ U

pgra

ding

ope

ratin

g vo

ltage

from

230

kV

to 5

00 k

V

1/

1/

1/

1/1

4/ 3/2/ 2/

1/1/

2/2/

5/

6/

110

DETA

ILS

OF

TRAN

SMIS

SIO

N SY

STEM

EXP

ANSI

ON

PROG

RAM

(Con

t.)( P

DP 20

10 )

Item

sN

ame

of T

rans

miss

ion

Line

s and

Sub

statio

nsLe

ngth

Num

ber o

f V

olta

geCo

nduc

tor S

ize

Com

miss

ioni

ng

Dat

e

(km

)Ci

rcui

t(k

V)

(MCM

)(Y

ear)

Nor

ther

n Re

gion

1.5

.12

A

dditi

onal

Tra

nsfo

rmer

s Ins

talla

tion

at E

xisti

ng S

ubsta

tions

--

--

2010

-201

2

1.5

.13

Sh

unt C

apac

itor I

nsta

llatio

ns-

--

-20

10-2

012

1.5

.14

M

iscel

lane

ous S

yste

m E

xpan

sion

(78.

8)1

115

2x79

520

10-2

012

1.5

.15

M

ae M

oh 3

- M

ae M

oh 4

- La

mph

un 2

1/10

42/

423

0/23

04x

1272

/2x1

272

2011

a

nd M

ae M

oh 3

- La

mpa

ng 1

a

nd L

amph

un 1

- La

mph

un 2

(35.

3)/(7

.5)

-11

52x

795/

795

2011

1.5

.16

Se

ctio

naliz

ing

Mae

Moh

3 -

Chia

ng R

ai a

nd e

xten

ding

to P

haya

o Su

bsta

tion

14

230

1272

2011

1.5

.17

Se

ctio

naliz

ing

Phits

anul

ok 2

- N

akho

n Sa

wan

and

ext

endi

ng to

Phi

chit

Subs

tatio

n23

223

012

7220

11

Subt

otal

7

46.4

km

(or 1

,778

.8 c

ircui

t-kilo

met

ers)

and

6 N

ew su

bsta

tion

1.

6 T

rans

miss

ion S

ystem

Dev

elopm

ent f

or P

ower

Pur

chas

e fro

m L

ao P

DR (T

heun

Hin

boun

Exp

ansio

n Pr

oject)

1.6

.1

Thai

/Lao

Bor

der (

Nak

hon

Phan

om) -

Nak

hon

Phan

om 2

(7.5

)2

230

1272

(Inv

ar)

2012

1.6

.2

Nak

hon

Phan

om 2

- N

akho

n Ph

anom

Junc

tion

22

230

1272

2012

1.6

.3

Pha

ng K

hon

- Sak

on N

akho

n 1

522

115

477

2012

Subt

otal

5

4.0

km (o

r 108

.0 c

ircui

t-kilo

met

ers)

and

1 N

ew su

bsta

tion

Not

es :

1/

New

subs

tatio

n2/

On

the e

xisti

ng ri

ght-o

f-way

3/ Q

uadr

uple

-circ

uit s

teel

tow

ers

4/

Line

strin

ging

on

the e

xisti

ng st

eel t

ower

s

5/ O

n th

e exi

sting

righ

t-of-w

ay (M

ae M

oh 3

- La

mpa

ng 1

- La

mph

un 1

- La

mph

un 2

)6/

Qua

drup

le-c

ircui

t ste

el to

wer

s, in

itial

ly d

oubl

e-ci

rcui

t lin

e stri

ngin

g

7/ R

e-co

nduc

torin

g to

be I

NV

AR

Type

8/ U

pgra

ding

ope

ratin

g vo

ltage

from

230

kV

to 5

00 k

V

2/

1/

6/

5/2/

2/3/ 3/

1/ 1/ 1/

1/

4/

1/

2/

7/

111

DETA

ILS OF

TRAN

SMISS

ION S

YSTE

M EX

PANS

ION P

ROGR

AM (C

ont.)

( PDP

2010)

Item

sN

ame

of T

rans

miss

ion

Line

s and

Sub

statio

nsLe

ngth

Num

ber o

f V

olta

geCo

nduc

tor S

ize

Com

miss

ioni

ng

Dat

e

(k

m)

Circ

uit

(kV

)(M

CM)

(Yea

r)

1.7

Tran

smissi

on Sys

tem Pr

oject f

or IPP

Powe

r Proj

ects

A)

GH

ECO

-One

Co.

,Ltd

(Coa

l), N

ikom

Map

Ta

Phut

1.7

.1

Nik

om M

ap T

a Ph

ut S

ubsta

tion

Expa

nsio

in-

-23

0-

2011

1.7

.2

Nik

om M

ap T

a Ph

ut -

Rayo

ng 2

(11)

223

02x

450m

m2 (Z

TACI

R)20

11

1.7

.3

Kla

eng

- Cha

ntha

buri

561

115

795

2012

B)

Siam

Ene

rgy

Co.,L

td (G

as),

Bang

Khl

a

1.7

.4

Sec

tiona

liziin

g of

Plu

ak D

aeng

- N

ong

Chok

Dou

ble-

circ

uit a

nd e

xten

ding

to0.

14

500

4x12

7220

12

Ba

ng K

hla

Subs

tatio

in to

be

Plua

k D

aeng

- Ba

ng K

hla

- Non

g Ch

ok(2

rout

es)

1.7

.5

Con

truct

ing

from

Ban

g K

hla

- Pow

er P

lant

0.3

250

04x

795

2012

(2 ro

utes

)

C)

Nat

iona

l Pow

er S

uppl

y Co

.,Ltd

(Coa

l), P

hano

m S

arak

ham

1.7

.6

Sec

tiona

liziin

g of

Plu

ak D

aeng

- W

ang

Noi

(1 c

ircui

t) an

d ex

tend

ing

to0.

12

500

4x12

7220

13

Ph

anom

Sar

akha

m S

ubsta

tioin

to b

e Pl

uak

Dae

ng -

Phan

om S

arak

ham

- W

ang

Noi

1.7

.7

Con

truct

ing

from

Pha

nom

Sar

akha

m -

Pow

er P

lant

122

500

4x79

520

13

Not

es :

1/

New

subs

tatio

n2/

On

the

exist

ing

right

-of-w

ay

3/ C

onstr

uctin

g th

e sin

gle-

circ

uit t

rans

miss

ion

line

on th

e do

uble

-circ

uit s

teel

tow

ers

1/

2/2/

3/

1/1/

1/

1/ 1/

1/

112

DETA

ILS OF

TRAN

SMISS

ION S

YSTE

M EX

PANS

ION P

ROGR

AM (C

ont.)

( PDP

2010

)

Item

sN

ame

of T

rans

miss

ion

Line

s and

Sub

statio

nsLe

ngth

Num

ber o

f V

olta

geCo

nduc

tor S

ize

Com

miss

ioni

ng

Dat

e

(k

m)

Circ

uit

(kV

)(M

CM)

(Yea

r)

D) P

ower

Gen

erat

ion

Supp

ly C

o.,L

td (G

as),

Non

g Sa

eng

1.7

.8

Sec

tiona

liziin

g of

Tha

Tak

o - W

ang

Noi

Dou

ble-

circ

uit a

nd e

xten

ding

to0.

14

500

4x79

520

13

Ph

achi

2 S

ubsta

tion

to b

e Th

a Ta

ko -

Phac

hi 2

-Wan

g N

oi(2

rout

es)

1.7

.9

Con

truct

ing

from

Pha

chi 2

- Po

wer

Pla

nt1

250

04x

795

2013

1.7

.10

Sec

tiona

liziin

g of

Tha

Tak

o - N

ong

Chok

Sin

gle-

circ

uit a

nd e

xten

ding

to5

150

04x

795

2013

Ph

achi

2 S

ubsta

tion

to b

e Th

a Ta

ko -

Phac

hi 2

(sin

gle-

circ

uit)

1.7

.11

Con

struc

ting

from

Pha

chi 2

- (P

hach

i 2 J

unct

ion)

- W

ang

Noi

Junc

tion

212

500

4x12

7220

13

D

oubl

e-ci

rcui

t

Subt

otal

9

5.6

km (o

r 130

.6 c

ircui

t-kilo

met

ers)

and

3 N

ew su

bsta

tions

1/

113

DE

TA

ILS

OF

TR

AN

SMIS

SIO

N S

YST

EM

EX

PA

NSI

ON

PR

OG

RA

M (

Con

t.)

( P

DP

201

0)

Item

sN

ame

of

Tra

nsm

issi

on L

ines

and S

ubst

atio

ns

Len

gth

Num

ber

of

Volt

age

Conduct

or

Siz

eC

om

mis

sionin

g

Dat

e

(k

m)

Cir

cuit

(kV

)(M

CM

)(Y

ear)

2. F

UT

UR

E P

RO

JEC

T

2

.1 T

rans

mis

sion

Sys

tem

Dev

elop

men

t fo

r P

ower

Pur

chas

e fr

om L

ao P

DR

(H

ongs

a L

igni

te-F

ired

The

rmal

Pow

er P

lant

Pro

ject

)

2.1

.1

Thai

/Lao

Bord

er (

Nan

) -

Nan

(D

ouble

-cir

cuit

)105

2500

4x1272

2014

2.1

.2

C

onst

ruct

ing f

rom

N

an -

Mae

Moh 3

(D

ouble

-cir

cuit

)165

2500

4x1272

2014

2.1

.3

R

econst

ruct

ion o

f M

ae M

oh 3

-T

ha

Tak

o s

ingle

-cir

cuit

326

2500

4x1272

2014

t

o b

e double

-cir

cuit

S

ubto

tal

596.0

km

(or

1,1

92.0

cir

cuit

-kil

om

eter

s)

2

.2

Tra

nsm

issi

on S

yste

m D

evel

opm

ent

for

Pow

er P

urch

ase

from

Mya

nmar

(M

ai K

hot

Coa

l-F

ired

The

rmal

Pow

er P

lant

Pro

ject

)

2

.2.1

Thai

/Myan

mar

Bord

er

(Chia

ng R

ai)

- M

ae C

han

30

4230

1272

2015

on Q

uad

ruple

-cir

cuit

ste

el t

ow

ers

2

.2.2

Const

ruct

ing f

rom

Mae

Chan

- C

hia

ng R

ai (

double

-cir

cuit

)50

2230

1272

2015

S

ubto

tal

80.0

km

(or

220.0

cir

cuit

-kil

om

eter

s)

No

tes

:

1/

On

th

e ex

isti

ng

rig

ht-

of-

way

1/

1/

1/

1/

1/

2/

114

DE

TA

ILS

OF

TR

AN

SMIS

SIO

N S

YST

EM

EX

PAN

SIO

N P

RO

GR

AM

(Con

t.)( P

DP

2010

)

Item

sN

am

e o

f T

ransm

issio

n L

ines a

nd S

ubsta

tions

Length

Num

ber

of

Volt

age

Conducto

r S

ize

Com

mis

sio

nin

g

Date

(k

m)

Cir

cuit

(kV

)(M

CM

)(Y

ear)

2

.3

New

Tra

nsm

issio

n In

terc

onne

ctio

n be

twee

n Su

-nga

i Kol

ok S

ubst

atio

n (E

GA

T) a

nd R

anta

u Pa

njan

g Su

bsta

tion

(TN

B)

2

.3.1

Thai/

Mala

ysia

Bord

er

(Nara

thiw

at)

-

Su-n

gai

Kolo

k (

double

-cir

cuit

)12

2132

795

2012

2

.3.2

I

nsta

llati

on 2

unit

s o

f 115/1

32 k

V

100 M

VA

at

Su-n

gai

Kolo

k S

ubsta

tion

--

--

2012

2

.3.3

Str

ingin

g

Nara

thiw

at

- S

u-n

gai

Kolo

k

2nd c

ircuit

50

1115

477

2012

S

ubto

tal

62.0

km

(or

74.0

cir

cuit

-kil

om

ete

rs)

2

.4

Tra

nsm

issio

n Sy

stem

Exp

ansio

n an

d R

enov

atio

n Pr

ojec

t

2

.4.1

Develo

pm

ent

and E

xpansio

n S

ubsta

tions

--

230/1

15

-2013-2

017

2

.4.2

Develo

pm

ent

and E

xpansio

n T

ransm

issio

n L

ines

230/1

15

2013-2

017

S

ubto

tal

T

ota

l

L

ength

1,9

17.0

km

(or

4,0

69.4

cir

cuit

-kil

om

ete

rs)

and 1

2 N

ew

substa

tions

No

tes :

1/

Un

der

stu

dy

fo

r tr

an

sm

issio

n s

yste

m d

ev

elo

pm

en

t

2/

No

t in

clu

din

g o

f le

ng

th t

ran

sm

issio

n l

ines a

nd

New

su

bsta

tio

ns o

f F

easib

ilit

y S

tud

y P

roje

ct

1/

1/

2/

1/

1/

1/

2/

1/

1/

1/

1/

1/

115

thailand power development plan (pdp

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