thailand power development plan (pdp
TRANSCRIPT
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
SPP (Renewables) (Jun) 160 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 (Renewables) (Jun) 65 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
EGAT Renewables (Jan) 24 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
EGAT Renewables (Jan) 18 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
EGAT Renewables (Jan) 14 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
EGAT Renewables (Jan) 17 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
EGAT Renewables (Jan) 11 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
EGAT Renewables (Jan) 30 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
EGAT Renewables (Jan) 8 MW
SPP (Cogeneration) (Jan) 270 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 Renewables (Jan) 22 MW
SPP (Cogeneration) (Jan) 270 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)
Peak Contract Minimum
Year Demand Capacity Reserve Margin
(MW) (MW) (%)
2021 37,856 End of SPP Contract (Feb-Oct) -200 MW
VSPP (Jan) 135 MW
EGAT Renewables (Jan) 61 MW
SPP (Cogeneration) (Jan) 380 MW
EGAT Nuclear Power Plant #2 (Jan) 1000 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 Renewables (Jan) 36 MW
SPP (Cogeneration) (Jan) 360 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
SPP (Cogeneration) (Jan) 360 MW
EGAT Gas Fired CC #2-6 (Jan) 5x800 MW
EGAT Clean Coal #3 (Jan) 800 MW
Power Purchase from Neighbouring Countries (Jan) 600 MW 51,235 16.7
2024 42,236 End of SPP Contract (Feb-Sep) -680 MW
Retirement of Mae Moh TH #4 (Jan) -140 MW
VSPP (Jan) 148 MW
SPP (Cogeneration) (Jan) 360 MW
EGAT Nuclear Power Plant #3 (Jan) 1000 MW
Power Purchase from Neighbouring Countries (Jan) 600 MW 52,523 16.5
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
SPP (Cogeneration) (Jan) 360 MW
EGAT Nuclear Power Plant #4 (Jan) 1000 MW
EGAT Gas Fired CC #7 (Jan) 800 MW
Power Purchase from Neighbouring Countries (Jan) 600 MW 52,782 16.3
Projects
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Table 2.2 (Continued)Thailand Power Development Plan 2021-2030
(PDP 2010)
Peak Contract Minimum
Year Demand Capacity Reserve Margin
(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
SPP (Cogeneration) (Jan) 360 MW
EGAT Gas Fired CC #8-9 (Jan) 2x800 MW
EGAT Clean Coal #4-5 (Jan) 2x800 MW
Power Purchase from Neighbouring Countries (Jan) 600 MW 56,956 15.9
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
SPP (Cogeneration) (Jan) 360 MW
EGAT Gas Fired CC #10 (Jan) 800 MW
Power Purchase from Neighbouring Countries (Jan) 600 MW 56,830 15.4
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
SPP (Cogeneration) (Jan) 360 MW
EGAT Nuclear Power Plant #5 (Jan) 1000 MW
EGAT Gas Fired CC #11-12 (Jan) 2x800 MW
EGAT Clean Coal #6-7 (Jan) 2x800 MW
Power Purchase from Neighbouring Countries (Jan) 600 MW 61,355 16.3
2029 50,959 Retirement of Mae Moh TH #8 (Jan) -270 MW
VSPP (Jan) 179 MW
SPP (Cogeneration) (Jan) 360 MW
EGAT Gas Fired CC #13 (Jan) 800 MW
EGAT Clean Coal #8 (Jan) 800 MW
Power Purchase from Neighbouring Countries (Jan) 600 MW 63,824 16.3
2030 52,890 Retirement of Mae Moh TH #9 (Jan) -270 MW
End of Houay Ho PPA (Jan) -126 MW
VSPP (Jan) 179 MW
SPP (Cogeneration) (Jan) 540 MW
EGAT Clean Coal TH #9 (Jan) 800 MW
Power Purchase from Neighbouring Countries (Jan) 600 MW 65,547 15.0
Total Added Capacity 2021-2030 32,442 MW
Total Retired Capacity 2021-2030 - 11,737 MW
Total Installed Capacity as of December 2009 29,212 MW
Total Added Capacity 2010-2030 54,005 MW
Total Retired Capacity 2010-2030 - 17,671 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%
• Total import from 3 countries - 33%
• Total import from 4 countries - 38%
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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
17
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.
18
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
- 800 MW Contract Capacity
- 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
- 800 MW Contract Capacity
- 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
SPP (Renewables) - 160 160 June 2011
Naresuan Dam Hydro 8 8 October 2011
GHECO-ONE Co., Ltd. Coal 660 660 November 2011
VSPP - 162 162 January 2012
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 (Renewables) - 65 65 June 2012
SPP (Cogeneration) - 704 704 Jun 2012 - Dec 2012
Power Purchase from Lao PDR (Theun Hinboun Ext.) Hydro 220 220 July 2012
VSPP - 187 187 January 2013
Kwae Noi Dam #1-2 Hydro 2x15 30 January 2013
EGAT Renewables - 24 24 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
VSPP - 192 192 January 2014
EGAT Renewables - 18 18 January 2014
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
PDP 2010Project Names Fuel Capacity Total Commissioning Date
Type (MW) (MW) VSPP - 167 167 January 2015
EGAT Renewables - 14 14 January 2015
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
SPP (Cogeneration) - 270 270 June 2015
EGAT Renewables - 17 17 January 2016
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
SPP (Cogeneration) - 270 270 June 2016
New Capacity _ South Gas 800 800 July 2016
VSPP - 229 229 January 2017
EGAT Renewables - 11 11 January 2017
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 June 2017
VSPP - 176 176 January 2018
EGAT Renewables - 30 30 January 2018
SPP (Cogeneration) - 270 270 January 2018
Power Purchase from Neighbouring Countries - 450 450 June 2018
VSPP - 177 177 January 2019
EGAT Renewables - 8 8 January 2019
SPP (Cogeneration) - 270 270 January 2019
Power Purchase from Neighbouring Countries - 600 600 June 2019
EGAT Clean Coal #1 Coal 800 800 June 2019
VSPP - 190 190 January 2020
EGAT Renewables - 22 22 January 2020
SPP (Cogeneration) - 270 270 January 2020
EGAT Nuclear Power Plant #1 Nuclear 1,000 1,000 January 2020
Power Purchase from Neighbouring Countries - 600 600 June 2020
27
Table 5.1 (Continued)Thailand Power Development Plan
PDP 2010Project Names Fuel Capacity Total Commissioning Date
Type (MW) (MW) VSPP - 135 135 January 2021
EGAT Renewables - 61 61 January 2021
SPP (Cogeneration) - 380 380 January 2021
EGAT Nuclear Power Plant #2 Nuclear 1,000 1,000 January 2021
Power Purchase from Neighbouring Countries - 600 600 January 2021
EGAT Clean Coal #2 Coal 800 800 June 2021
VSPP - 294 294 January 2022
EGAT Renewables - 36 36 January 2022
SPP (Cogeneration) - 360 360 January 2022
EGAT Gas Fired CC #1 Gas 800 800 January 2022
Power Purchase from Neighbouring Countries - 600 600 January 2022
VSPP - 146 146 January 2023
SPP (Cogeneration) - 360 360 January 2023
EGAT Gas Fired CC #2-6 Gas 5x800 4,000 January 2023
EGAT Clean Coal #3 Coal 800 800 January 2023
Power Purchase from Neighbouring Countries - 600 600 January 2023
VSPP - 148 148 January 2024
SPP (Cogeneration) - 360 360 January 2024
EGAT Nuclear Power Plant TH #3 Nuclear 1,000 1,000 January 2024
Power Purchase from Neighbouring Countries - 600 600 January 2024
VSPP - 163 163 January 2025
SPP (Cogeneration) - 360 360 January 2025
EGAT Nuclear Power Plant #4 Nuclear 1,000 1,000 January 2025
EGAT Gas Fired CC #7 Gas 800 800 January 2025
Power Purchase from Neighbouring Countries - 600 600 January 2025
VSPP - 159 159 January 2026
SPP (Cogeneration) - 360 360 January 2026
EGAT Gas Fired CC #8-9 Gas 2x800 1,600 January 2026
EGAT Clean Coal #4-5 Coal 2x800 1,600 January 2026
Power Purchase from Neighbouring Countries - 600 600 January 2026
28
Table 5.1 (Continued)Thailand Power Development Plan
PDP 2010Power Plant Project Names Fuel Capacity Total Commissioning Date
Type (MW) (MW) VSPP - 169 169 January 2027
SPP (Cogeneration) - 360 360 January 2027
EGAT Gas Fired CC #10 Gas 800 800 January 2027
Power Purchase from Neighbouring Countries - 600 600 January 2027
VSPP - 173 173 January 2028
SPP (Cogeneration) - 360 360 January 2028
EGAT Nuclear Power Plant #5 Nuclear 1,000 1,000 January 2028
EGAT Gas Fired CC #11-12 Gas 2x800 1,600 January 2028
EGAT Clean Coal #6-7 Coal 2x800 1,600 January 2028
Power Purchase from Neighbouring Countries - 600 600 January 2028
VSPP - 179 179 January 2029
SPP (Cogeneration) - 360 360 January 2029
EGAT Gas Fired CC #13 Gas 800 800 January 2029
EGAT Clean Coal #8 Coal 800 800 January 2029
Power Purchase from Neighbouring Countries - 600 600 January 2029
VSPP - 179 179 January 2030
SPP (Cogeneration) - 540 540 January 2030
EGAT Clean Coal #9 Coal 800 800 January 2030
Power Purchase from Neighbouring Countries - 600 600 January 2030
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
30
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FIGURE 5.1 THAILAND POWER DEVELOPMENT PLAN (PDP 2010)
VSPP
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.7M
W
VSPP
18
7 M
W;
KWAI
NO
I D
AM #
1-2
30
MW
; EG
AT R
ENEW
ABLE
S 2
4 M
W24
1.0
SIAM
EN
ERG
Y #
1 8
00 M
W;
SPP
(CH
ACH
UEN
GSA
O C
OG
EN)
90
MW
890.
0SP
P (R
IL C
OG
EN)
90
MW
90.0
SPP
(SIA
M P
OW
ER G
EN 2
) 9
0 M
W;
SPP
(PAT
HUM
CO
GEN
) 9
0 M
W45
0.0
SPP
(CH
P)
90 M
W;
SIAM
EN
ERG
Y #
2 8
00 M
W89
0.0
NAT
ION
AL P
OW
ER S
UPPL
Y #
1-2
2x1
35 M
W27
0.0
PEAK
GEN
ERA
TIO
N27
,188
.0M
W
MIN
IMU
M R
ESER
VE M
ARG
IN25
.4%
ADD
ITIO
NAL
CAP
ACIT
Y2,
831.
0M
W
RETI
RED
CAP
ACIT
Y0.
0M
W
NET
CAP
ACIT
Y IN
YEA
R2,
831.
0M
W
TOTA
L CA
PACI
TY37
,002
.7M
W
BAN
G P
AKO
NG
TH
#1-
2 (R
ETIR
E)
-105
2 M
W;
VSPP
1
91.5
MW
; EG
AT R
ENEW
ABLE
S
18 M
W-8
42.5
NAT
ION
AL P
OW
ER S
UPPL
Y #
3-4
2x1
35 M
W27
0.0
WAN
G N
OI
CC#
4 8
00 M
W;
POW
ER G
EN S
UPPL
Y #
1 8
00 M
W;
SPP
(B G
RIM
) 9
0 M
W1,
690.
0CH
ANA
CC#
2 8
00 M
W80
0.0
POW
ER_G
EN_S
UPPL
Y_#
2 8
00 M
W80
0.0
PEAK
GEN
ERA
TIO
N28
,341
.0M
W
MIN
IMU
M R
ESER
VE M
ARG
IN23
.4%
ADD
ITIO
NAL
CAP
ACIT
Y3,
769.
5M
W
RETI
RED
CAP
ACIT
Y-1
,052
.0M
W
NET
CAP
ACIT
Y IN
YEA
R2,
717.
5M
W
TOTA
L CA
PACI
TY39
,720
.2M
W
RAYO
NG
CC
#1-
4 (P
PA E
ND
) -
1175
.1 M
W;
-982
.1
HO
NG
SA
#1
49
1 M
W49
1.0
SPP
COG
EN
270
MW
270.
0
HO
NG
SA
#2
49
1 M
W49
1.0
PEAK
GEN
ERA
TIO
N29
,463
.0M
W
MIN
IMU
M R
ESER
VE M
ARG
IN26
.0%
ADD
ITIO
NAL
CAP
ACIT
Y1,
445.
0M
W
RETI
RED
CAP
ACIT
Y-1
,175
.1M
W
NET
CAP
ACIT
Y IN
YEA
R26
9.9
MW
TOTA
L CA
PACI
TY39
,990
.1M
W
MAI
GH
OT
#1
123
MW
; EG
AT R
ENEW
ABLE
S 16
.5 M
W13
9.5
HO
NG
SA
#3
49
1 M
W49
1.0
MAI
GH
OT
#2
123
MW
123.
0
430.
3KN
CC
(PPA
EN
D)
-67
8 M
W;
MAI
GH
OT
#3
123
MW
; N
EW C
APAC
ITY
SOUT
H
800
MW
245.
0PE
AK G
ENER
ATI
ON
30,7
54.0
MW
MIN
IMU
M R
ESER
VE M
ARG
IN27
.2%
ADD
ITIO
NAL
CAP
ACIT
Y2,
177.
0M
W
RETI
RED
CAP
ACIT
Y-7
48.2
MW
NET
CAP
ACIT
Y IN
YEA
R1,
428.
8M
W
TOTA
L CA
PACI
TY41
,418
.9M
W
NAM
NG
UM 3
44
0 M
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
32
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
34
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
44
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.
46
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.
47
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.
48
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
Nuclear Power Plant Unit #2 1,000 MW in 2021
Nuclear Power Plant Unit #3 1,000 MW in 2024
Nuclear Power Plant Unit #4 1,000 MW in 2025
Nuclear Power Plant Unit #5 1,000 MW in 2028
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
11.7 Transmission System Development Project for Power Purchase from Lao
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.
11.9 Transmission System Development Project for Power Purchase from Lao
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
6. Transmission System Expansion Project No.12 (2010-2016) 2014-2016
7. Transmission System Expansion Project No.13 (2013-2019) 2017-2019
8. Transmission System Expansion Project No.14 (2016-2022) 2020-2022
9. Miscellaneous Transmission System Expansion for Small Power Producer (SPP) Power Plants
2013-2020
59
60
Appendices
61
62
Appendix 1
Comparison of Thailand Power Development Plans
63
64
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
66
Appendix 2
Map of Thailand Power System
67
68
69
70
Appendix 3
Installed Capacity of Thailand Power System
71
72
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
Unit 3 Gas/Heavy oil 576.0
Unit 4 Gas/Heavy oil 576.0
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
Unit 2 Gas/Heavy oil 70.2
Block 1 Gas 678.0
818.1
Ratchaburi Unit 1 Gas/Heavy oil 720.0
Unit 2 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
76
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
78
Appendix 5
Power Demand Statistic and Load Forecast
79
80
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
86
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
88
Appendix 7
Power Plant Retirement Schedule
89
90
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
92
Appendix 8 Projection of Energy Generation
Classified by Fuel Types
93
94
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
96
Appendix 9 Renewable Energy and Purchasement Plan
From SPP and VSPP
97
98
99
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
104
Appendix 10 Transmission System Expansion Projects
105
106
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
116