THAILAND POWER DEVELOPMENT PLAN 2008 – 2021
98
ก ฟ ผ PDP 2007: Revision 2 ก.ฟ.ผ Electricity Generating Authority of Thailand THAILAND POWER DEVELOPMENT PLAN 2008 2021 2008 – 2021 (PDP 2007: Revision 2) Report no. 912000-5204 System Planning Division M 2009 May 2009
Transcript of THAILAND POWER DEVELOPMENT PLAN 2008 – 2021
ก ฟ ผ
PDP 2007: Revision 2ก.ฟ.ผ
Electricity Generating Authority of Thailand
THAILAND POWER DEVELOPMENT PLAN2008 20212008 – 2021
(PDP 2007: Revision 2)
Report no. 912000-5204 System Planning DivisionM 2009May 2009
Thailand Power Development Plan2008 – 20212008 2021
(PDP 2007: Revision 2)
System Planning DivisionElectricity Generating Authority of Thailand
May 2009
Contents Page
1. Introduction 1
2. Summary 4
3. Power Demand Forecasting 15
4. Thailand Power Development Plan (PDP 2007 : Revision 2) 20
5. Project Descriptions 28
6. Nuclear Power Plant 33
7. Power Purchasing from Private Power Companies and Neighboring Countries 37
List of Appendices Page
Appendix 1 Comparison of Thailand Power Development Plans 43
Appendix 2 Thailand Power System 47
Appendix 3 Installed Capacity of Thailand Power System 51
Appendix 4 Existing Transmission System 55
Appendix 5 Power Demand Statistic and Load Forecast 59
Appendix 6 EGAT RPS Power Plant Projects 65
Appendix 7 Summary of Power Purchase from SPPs 69
Appendix 8 Summary of Existing Non-Firm Contract SPP
Classified by Fuel Types 73
Appendix 9 Projection of Energy Generating Capacity
Classified by Power Plant Types 77
Appendix 10 Projection of Energy Generating Capacity
Classified by Fuel Types and Energy Purchase 81
Appendix 11 Transmission System Expansion Projects 85
1
1. Introduction Thailand Power Development Plan 2007 – 2021 (PDP 2007) was formulated by
the Electricity Generating Authority of Thailand (EGAT) under the policy framework of the
Ministry of Energy, in terms of reliability of power supply, fuel diversification, power
purchase from neighboring countries, and power demand forecast, etc. The PDP 2007 was
approved by the National Energy Policy Council (NEPC) and endorsed by the cabinet in June
2007.
Later, the Energy Planning and Policy Office (EPPO) of the Ministry of Energy
had successfully executed the power purchase from the Small Power Producers (SPPs),
including both co-generation and renewable projects, as well as the selection of the
Independent Power Producers (IPPs). Regarding power purchase from neighboring countries,
EGAT has also finalized power purchase deal and entered into either the Power Purchase
Agreement (PPA) or tariff MOU in many projects with their developers.
EGAT under the guidance of the Ministry of Energy reviewed the PDP 2007 to
cope with such current situation, so called “Thailand Power Development Plan 2007-2021:
PDP 2007 Revision 1”. The PDP 2007 Revision 1 was approved by NEPC and endorsed by
the cabinet in December 2007.
However, after 10 months of applying the PDP 2007 Revision 1, the situation and
condition affecting the plan has significantly changed, especially the declined power demand
was found lower than the forecast due to the global economic recession. If the plan remained
unchanged, the power system would reflect with high reserved margin. Furthermore, the
power development projects in Lao PDR, which tariff MOU have expired or were terminated,
are required to review and re-negotiate their proposed tariff.
Therefore, EAGT together with the Ministry of Energy have again reviewed the
PDP 2007 Revision 1 according to the present situation, called “Thailand Power Development
Plan 2007-2021: PDP 2007 Revision 2”
2
The PDP 2007 Revision 2 was endorsed by NEPC on January 16, 2009 and
proposed to the Cabinet on January 28, 2009. The Cabinet assigned NEPC to consider the
necessity of public hearing process on the PDP 2007 Revision 2 and, in the meeting of the
PDP Review Committee on February 2, 2009, EPPO and EGAT was assigned to prepare
information for the PDP workshop in exchanging points of view among relevant stakeholders
and collecting comments for further adjustment of the PDP. The workshop was arranged on
February 11, 2009 in which the following issues on the PDP were discussed.
1. Load forecast applied in this PDP is revised according to the declined power
demand, of which the GDP growths in 2009, 2010 and 2011 were lower projected to 2.0 %,
3.0 % and 4.5 % respectively while the GDP growth projection from 2012 to 2021 is
remained the same as the previous load on March 2007. The load forecast will be executed
again after 8 – 10 months when the consultancy engaged with EPPO finish the long term GDP
forecast considering the change of customer structure such as industry sector.
2. The load forecast was adjusted from the load on March 2007 and has deducted
the energy saving as derived from the potential of the Demand Side Management (DSM)
programs. Besides, energy from the Very Small Power Producers (VSPP) and renewable
energy are also considered on the load. The net energy after deducting the energy from DSM
potential and from VSPP was applied in this PDP. However, the load forecast for the next
PDP will be made based on the latest long term GDP projection while the DSP programs and
the VSPP projects will be considered in more details.
3. The acceleration of power purchase from SPPs reflecting the Government
policy on the economic enhancement since SPPs mainly generate power supporting the
growth of industrial sector.
4. Chana block 2 is a required power plant in the PDP as its role to supply
increased power demand from 2014 in lower part of Southern Thailand.
5. The postponement of large power projects including IPPs, EGAT owned plants
and power purchase from neighboring countries due to the reduced power demand as
maintaining reserved margin at an appropriate level. Moreover, the large power projects
3
usually required oversea funding which is now facing the global economic crisis causing
difficult approval of loan.
The review of the PDP 2007 Revision 2 according to comments collected from the
workshop was then completed and the Ministry of Energy again proposed to NEPC. The
proposed PDP 2007 Revision 2 was endorsed by NEPC on March 9, 2009 and finally
endorsed by the Cabinet on March 24, 2009. The PDP 2007 Revision 2 will be applied only
for the period of 2009 – 2015 to maintain appropriate level of reserved margin, with respect to
the present situation of economic recession, as well as to reduce the investment burden on
unnecessary expansion of power generation and transmission projects to an appropriate level.
Further plan during 2016 – 2021 will be review in the next PDP.
According to the PDP 2007 Revision 2, the country in overview will benefit from
the revised implementation in power sector as following.
1. Thailand power reserved margin can be maintained at appropriate level with
respect to the declined power demand, therefore most of previously planned power plants
were postponed as stated in the PDP.
2. The investment on power generation and transmission projects can be reduced
due to the postponement of power projects of IPPs, EGAT, new unidentified capacities, as
well as power purchase from neighboring countries with respect to the declined power
demand that makes the whole plan investment be reduced.
3. The acceleration of power purchase from SPPs to support the Government
policy on the economic enhancement and reduction of public debt.
4
2. Summary
2.1 Current Status The peak power demand of 2008 occurred on April 21, 2007 of which the
maximum power generation of the country has reached 22,586.2 MW which is 17.9 MW or
0.08 % lower than the record of 2007.
2.1.1 Power Plants
As of December 2008, the total installed capacity is 29,139.5 MW,
comprising 14,268.7 MW (49.0%) from EGAT’s power plants, 14,230.8 MW (48.8%) from
domestic private power producers (IPPs and SPPs) and 640 MW (2.2%) from neighboring
country power purchase. The details of installed capacity of Thailand power system are
shown in Appendix 3.
2.1.2 Transmission Systems
The standard voltage levels of EGAT transmission systems 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 2008 is 30,219 circuit-kilometers. The total number
of high voltage substations is 209 with total transformer capacity of 72,075 MVA. The
summary of transmission line length and number of EGAT’s substations classified by voltage
level are shown in table below:
Voltage Substation Transmission
Number MVA (Circuit-km)
500 kV 10 15,850 3,432
230 kV 68 41,160 13,277
132 kV - 133 9
115 kV 131 14,544 13,459
69 kV - - 19
300 kV HVDC - 388 23
Total 209 72,075 30,219
The details of transmission lines and substations are shown in Appendix 4.
5
2.2 Additional and Updated Information for the Revision of PDP 2007 Additional and updated information and assumptions used for the revision of PDP
2007 are as follows:
2.2.1 The Load Forecast was reviewed to cope with the actual energy
consumption which is lower than the projection. The peak power demand at the end of 2021
was estimated at 44,281 MW which is 4,333 MW lower than that of the PDP 2007 Revision
1. The amended demand forecast is shown in Appendix 5.
2.2.2 The review of the Commercial Operation Dates (COD) of the firm contract
SPPs become earlier than those scheduled in the PDP 2007 Revision 1 responding the
Government policy on the economic enhancement without causing public debt.
2.2.3 The review of the Commercial Operation Dates (COD) of 2 IPPs, Siam
Energy Block 1-2 and National Power Supply Block 1-4, to be postponed for 1 year in order
to maintain the appropriate level of reserved margin and to cope with the present situation of
declined power demand.
2.2.4 The review of the power purchased from the IPP projects in neighboring
countries, especially in Lao PDR. In case of the Nam Theun 1 and Nam Ngum 3 projects,
their tariff MOUs have expired while, in case of the Hong Sa, Nam Ngiep 1 and Nam Ou,
their construction cost have increased until the projects were not viable with the committed
tariff so that they terminated their tariff MOU. All mentioned projects will be renegotiated.
2.2.5 New future capacities were postponed and the capacities of the proposed
nuclear power plants in 2020 and 2021 were reduced from 2,000 MW per year to 1,000 MW
per year in order to maintain the appropriate level of reserved margin and to cope with the
present situation of declined power demand.
2.2.6 The estimated annual energy of power purchase from non-firm SPPs is
365.3 GWh.
6
2.2.7 The power generation from VSPPs which information is given by power
distribution authorities, Provincial Electricity Authority (PEA) and Metropolitan Electricity
Authority (MEA), considered as expected dependable capacity is based on the following
assumption.
− VSPPs with wind and solar power generation are uncertain capacities and no
reliability to assist the system during peak demand period.
− Other VSPPs such as co-generation plants, biogas, waste and biomass can be
partially considered as planning capacity only for an expected dependable portion.
− The possibility of the proposed VSPP projects to be successfully implemented and
energized to the system is considered as 50%.
− The potential of the VSPP projects, except wind and solar power, for their ability
of supplying to the system during peak demand period is assumed as 30%.
− The growth of the expected dependable capacity of VSPPs to be specified in
planning is projected with 50 MW per year.
According to the above mentioned assumption, the expected dependable capacity
of VSPPs can described as follows:
7
Unit in MW
Year Wind and Solar Others; Co-generation, Biogas, Waste and Biomass VSPP
Capacity
in PDP
Proposed
Capacity
Planning
Capacity
Proposed
Capacity
Planning
Capacity
Projected
Capacity
2009 136 - 40 6 - 6
2010 135 - 68 10 - 10
2011 148 - 321 48 - 48
2012 173 - 334 50 - 50
2013 174 - - - 50 50
2014 174 - - - 50 50
2015 26 - - - 50 50
2016 73 - - - 50 50
2017 72 - - - 50 50
2018 74 - - - 50 50
2019 76 - - - 50 50
2020 79 - - - 50 50
2021 82 - - - 50 50
2.2.8 The Combined Heat and Power (CHP), previously expected to increase
installed capacity of 74 MW for the South Bangkok power plant block 2 and 243 MW for the
Wang Noi power plant blocks 1-3, was terminated since it had been found technically
unfeasible and unviable for investment.
2.2.9 The capacity of new power plants with natural gas fuel from 2012 was
adjusted from 700 MW to 800 MW according to the latest power plant technology.
Accordingly, the CODs of all new capacities were rescheduled to maintain the
reserved margin at the level not lower than 15%.
2.3 Thailand Power Development Plan (PDP 2007: Revision 2)
Based on the additional and updated information on the future power sources of
EGAT, IPPs, SPPs and power purchase from neighboring countries as well as load forecast as
8
mentioned, EGAT and the Ministry of Energy have successfully reviewed the PDP 2007 :
Revision 1 as follows:
2.3.1 Projects during 2009-2015 are:
- EGAT power plant projects 3,768.7 MW
- IPP power purchase projects 4,400.0 MW
- SPP power purchase projects 1,985.5 MW
- VSPP power purchase projects 264.0 MW
- Power purchased from neighboring countries 2,186.6 MW
A list of new projects during 2009-2015 is shown in the following table:
Year Power Plants
2009 Retirement of South Bangkok Thermal Power Plant Units 4-5 -559 MW
Retirement of Lankrabue Gas Turbine Power Plant Units 1-11 -220.1 MW
Retirement of Nong Chok Gas Turbine Power Plant Units 1-3 -351 MW
Retirement of Suratthani Gas Turbine Power Plant Units 1-2 -234 MW
VSPP 6 MW
SPP (Renewable) 26.5 MW
South Bangkok Combined Cycle Power Plant Block 3 710 MW
Bang Pakong Combined Cycle Power Plant Block 5 710 MW
Power purchased from Lao PDR (Nam Theun 2) 920 MW
Chao Phraya Dam Small Hydro Unit 1 6 MW
Wind and Solar Power (Undependable) (3) MW
2010 VSPP 10 MW
Chao Phraya Dam Small Hydro Unit 2 6 MW
North Bangkok Combined Cycle Power Plant Block 1 670 MW
Mae Klong Dam Small Hydro Units 1-2 2 x 6 MW
Pasak Jolasid Dam Small Hydro 6.7 MW
Khun Dan Prakarnchon Dam Small Hydro 10 MW
SPP (Co-generation) 90 MW
9
Year Power Plants
2011 Power purchased from Lao PDR (Nam Ngum 2) 596.6 MW
VSPP 48 MW
Kwae Noi Dam Small Hydro Units 1-2 2 x 15 MW
Naresuan Dam Small Hydro 8 MW
SPP (Renewable) 250 MW
Gheco-one Co.,Ltd 660 MW
Retirement of Khanom Thermal Power Plant Unit 1 -69.9 MW
2012 VSPP 50 MW
SPP (Renewable) 65 MW
SPP (Co-generation) 924 MW
Power purchased from Lao PDR (Theun Hinbun-expanded) 220 MW
2013 VSPP 50 MW
National Power Supply Co., Ltd Units 1-2 2 x 135 MW
SPP (Co-generation) 540 MW
Siam Energy Co., Ltd Units 1-2 2 x 800 MW
2014 VSPP 50 MW
National Power Supply Co., Ltd Units 3-4 2 x 135 MW
SPP (Co-generation) 90 MW
Power Generation Supply Co., Ltd Units 1-2 2 x 800 MW
Retirement of Bank Pakong Thermal Power Plant Units 1-2 -1,052 MW
Wang Noi Combined Cycle Power Plant Block 4 800 MW
Chana Combined Cycle Power Plant Block 2 800 MW
2015 Retirement of Rayong Combined Cycle Power Plant Blocks 1-4 -1,175.1 MW
VSPP 50 MW
Power purchased from neighboring countries 450 MW
2.3.2 Projects during 2016-2021 are:
- EGAT new power plants (Coal) 4 x 700 MW
- EGAT new power plants (Nuclear) 2 x 1,000 MW
- VSPP power plants 300 MW
- Power purchased from neighboring countries 2,850 MW
10
- New power plants
− EGAT 4 x 800 MW
− IPP 2 x 800 MW
− Unidentified 6 x 800 MW
The list of all projects in the PDP 2007 : Revision 2 during 2009-2021 is shown in
Table 2.1. The list of new projects categorized by power producers is shown in Table 2.2.
2.3.3 Share of Power Generation Capacity
The share of installed capacity in Thailand power system among EGAT, IPPs and
power purchase from neighboring countries in 2009 is equal to 47.5 %, 47.3 % and 5.2 %
respectively. At the end of 2015, the share will be 41.0 %, 51.6 % and 7.4 % respectively and,
at the end of 2021, it will be 42.5 %, 37.2 % and 11.0 % respectively with a share of new
power plants of 9.3 %.
Year EGAT IPP New Power Plants Power Purchase from Neighboring Countries
Total
MW % MW % MW % MW % MW
2009 2010 2011
14,330.6 15,035.3 15,073.3
47.5 48.6 46.4
14,263.3 14,363.3 15,251.4
47.3 46.4 47.0
- - -
- - -
1,560.0 1,560.0 2,156.6
5.2 5.0 6.6
30,153.9 30,958.6 32,481.3
2012 2013 2014 2015 2016
15,073.3 15,073.3 15,621.3 15,621.3 17,021.3
44.7 41.6 40.3 41.0 42.5
16,290.4 18,750.4 20,760.4 19,635.3 18,937.1
48.3 51.8 53.6 51.6 47.3
- - - -
800.0
- - - -
2.0
2,376.6 2,376.6 2,376.6 2,826.6 3,276.6
7.0 6.6 6.1 7.4 8.2
33,740.3 36,200.3 38,758.3 38,083.2 40,035.0
2017 2018 2019 2020 2021
18,107.3 19,868.3 20,668.3 21,027.3 22,027.3
42.9 44.7 43.8 43.1 42.5
18,807.1 18,815.1 18,676.1 19,438.1 19,288.1
44.5 42.3 39.6 39.8 37.2
1,600.0 1,600.0 3,200.0 3,200.0 4,800.0
3.8 3.6 6.8 6.6 9.3
3,726.6 4,176.6 4,676.6 5,176.6 5,676.6
8.8 9.4 9.9 10.6 11.0
42,241.0 44,460.0 47,221.0 48,842.0 51,792.0
Table 2.1Thailand Power Development Plan
( PDP 2007 : Revision 2 )Peak Capacity Reserve
Year Demand Margin(MW) (MW) (%)
2009 22,886 Retirement of South Bangkok TH # 4-5 (Jan.) -559 MW Retirement of Lankrabue GT # 1-11 (Jan.) -220 MW Retirement of Nong Chok GT # 1-3 (Jan.) -351 MW Retirement of Suratthani GT # 1-2 (Jan.) -234 MW VSPP (Jan.) 6 MW SPP (Renew) (Jan.) 16.5 MW SPP (Renew) (Mar.) 10 MW South Bangkok CC # 3 (Mar.) 710 MW Bang Pakong CC # 5 (Jul.) 710 MW Power purchased from Lao PDR (Nam Theun 2) (Nov.) 920 MW Chao Phraya Dam # 1 (Dec.) 6 MW Wind energy and Solar energy (Dec.) (3) MW 30,153.9 22.4
2010 23,936 VSPP (Jan.) 10 MW Chao Phraya Dam # 2 (Mar.) 6 MW North Bangkok CC # 1 (May.) 670 MW Mae Klong Dam # 1-2 (Aug.,Dec.) 2x6 MW Pasak Jolasid Dam (Oct.) 6.7 MW Khun Dan Prakarnchon Dam (Nov.) 10 MW SPP (Co-Gen) (Nov.) 90 MW 30,958.6 24.0
2011 25,085 Power purchased from Lao PDR (Nam Ngum 2) (Jan.) 596.6 MW VSPP (Jan.) 48 MW Kwae Noi Dam # 1-2 (Jan., Apr.) 2x15 MW Naresuan Dam (Feb.) 8 MW Retirement of Khanom TH # 1 (Jul.) -69.9 MW SPP (Renew) (Aug.) 250 MW Gheco-one Co.,Ltd (Nov.) 660 MW 32,481.3 23.7
2012 26,572 VSPP (Jan.) 50 MW SPP (Renew) (Jan.) 65 MW SPP (Co-Gen) (Jun.) 924 MW Power purchased from Lao PDR (Theun Hinbun-expanded) (J 220 MW 33,740.3 20.3
2013 28,188 VSPP (Jan.) 50 MW Siam Energy Co., Ltd # 1-2 (Mar.,Sep.) 2x800 MW SPP (Co-Gen) (Jun.) 540 MW National Power Supply Co., Ltd # 1-2 (Nov.) 2x135 MW 36,200.3 20.4
2014 29,871 Retirement of Bank Pakong TH # 1-2 (Jan.) -1052 MW VSPP (Jan.) 50 MW National Power Supply Co., Ltd # 3-4 (Mar.) 2x135 MW Wang Noi CC # 4 (Jun.) 800 MW SPP (Co-Gen) (Jun.) 90 MW Power Generation Supply Co., Ltd # 1-2 (Jun., Dec.) 2x800 MW Chana CC # 2 (Jul.) 800 MW 38,758.3 16.6
2015 31,734 Retirement of Rayong CC # 1-4 (Jan.) -1175 MW VSPP (Jan.) 50 MW Power purchased from neighboring countries (Jun.) 450 MW 38,083.2 16.6
Power Plant
Table 2.1 (Cont.)Thailand Power Development Plan
( PDP 2007 : Revision 2 )Peak Capacity Reserve
Year Demand Margin(MW) (MW) (%)
2016 33,673 Retirement of Khanom TH # 2 (Jun.) -70.2 MW Retirement of Khanom CC (Jul.) -678 MW VSPP (Jan.) 50 MW Thermal power plant (Coal)_EGAT # 1-2 (Jan.) 2x700 MW Power purchased from neighboring countries (Mar.) 450 MW New power plant_South (Jul.) 800 MW 40,035.0 16.6
2017 35,668 Retirement of Bang Pakong CC # 3 (Jan.) -314 MW Retirement of SPP (Apr.,Oct.) -180 MW VSPP (Jan.) 50 MW Thermal power plant (Coal)_EGAT # 3-4 (Jan.) 2x700 MW New power plant (Jan.) 800 MW Power purchased from neighboring countries (Jan.) 450 MW 42,241.0 16.6
2018 37,725 Retirement of Bang Pakong CC # 4 (Jan.) -314 MW Retirement of Nam Pong CC # 1 (Jan.) -325 MW Retirement of SPP (Feb.,Apr.) -42 MW VSPP (Jan.) 50 MW South Bangkok CC # 4-5 (Jan.) 2x800 MW Bang Pakong CC # 6 (Jan.) 800 MW Power purchased from neighboring countries (Jan.) 450 MW 44,460.0 15.8
2019 39,828 Retirement of SPP (Jun.,Sep.) -189 MW VSPP (Jan.) 50 MW North Bangkok CC # 2 (Jan.) 800 MW New power plant (Jan.) 2x800 MW Power purchased from neighboring countries (Jan.) 500 MW 47,221.0 17.0
2020 42,024 Retirement of South Bangkok CC # 1 (Jan.) -316 MW Retirement of Nam Pong CC # 2 (Jan.) -325 MW Retirement of power plant of Tri Energy Co. -700 MW Retirement of SPP (Feb.,May.,Aug.) -188 MW VSPP (Jan.) 50 MW Thermal power plant (Nuclear)_EGAT # 1 (Jan.) 1000 MW New power plant _IPP (Jan.) 2x800 MW Power purchased from neighboring countries (Jan.) 500 MW 48,842.0 16.1
2021 44,281 Retirement of SPP (Feb.,Sep.,Oct.) -200 MW VSPP (Jan.) 50 MW Thermal power plant (Nuclear)_EGAT # 2 (Jan.) 1000 MW New power plant (Jan.) 2x800 MW Power purchased from neighboring countries (Jan.) 500 MW 51,792.0 15.3
Total capacity (as of December 2008) 29,139.5 MWTotal added capacity 30,154.8 MWTotal retired capacity - 7,502.3 MWGrand total capacity (at the end of 2021) 51,792.0 MW
Power Plants
Tab
le 2
.2
Lis
t of P
roje
cts a
s Tha
iland
Pow
er D
evel
opm
ent P
lant
dur
ing
2009
- 20
15 (b
y G
ener
ator
s)(P
DP
200
7 : R
evis
ion
2)
EG
AT
's P
roje
cts
Priv
ate
Pow
er C
ompa
ny's
Pro
ject
sPo
wer
pur
chas
ed fr
om n
eigh
bori
ng c
ount
ries
Subt
otal
Cap
acity
/ Sh
are
IPP
SPP
VSP
PSu
btot
al C
apac
ity /
Shar
eSu
btot
al C
apac
ity /
Shar
eM
W%
MW
MW
MW
MW
%M
W%
MW
MW
%20
09 S
outh
Ban
gkok
CC
# 3
710
14,3
30.6
47.5
% V
SPP
614
,263
.347
.3%
Nam
The
un 2
920
1,56
0.0
5.2%
30,1
53.9
22,8
8622
.4%
Ban
g Pa
kong
CC
# 5
710
SPP
(Ren
ew)
26.5
Smal
l Hyd
ro P
ower
Pla
nts
6
Win
d en
ergy
and
Sol
ar e
nerg
y(3
)
2010
Nor
th B
angk
ok C
C #
167
015
,035
.348
.6%
VSP
P10
14,3
63.3
46.4
%-
- 1,
560.
05.
0%30
,958
.623
,936
24.0
%
Smal
l Hyd
ro P
ower
Pla
nts
35SP
P (C
o-G
en)
90
2011
Smal
l Hyd
ro P
ower
Pla
nts
3815
,073
.346
.4%
VSP
P48
15,2
51.4
47.0
% N
am N
gum
259
6.6
2,15
6.6
6.6%
32,4
81.3
25,0
8523
.7%
SPP
(Ren
ew)
250
Ghe
co-o
ne C
o.,L
td66
0
2012
--
15,0
73.3
44.7
% V
SPP
5016
,290
.448
.3%
The
un H
inbu
n-ex
pand
ed22
02,
376.
67.
0%33
,740
.326
,572
20.3
%
SPP
(Ren
ew)
65
SPP
(Co-
Gen
)92
4
2013
--
15,0
73.3
41.6
% V
SPP
5018
,750
.451
.8%
--
2,37
6.6
6.6%
36,2
00.3
28,1
8820
.4%
SPP
(Co-
Gen
)54
0
Sia
m E
nerg
y C
o., L
td #
1-2
1,60
0
Nat
iona
l Pow
er S
uppl
y C
o., L
td #
1-2
270
2014
Wan
g N
oi C
C #
480
015
,621
.340
.3%
VSP
P50
20,7
60.4
53.6
%-
-2,
376.
66.
1%38
,758
.329
,871
16.6
%
Cha
na C
C #
280
0SP
P (C
o-G
en)
90
Nat
iona
l Pow
er S
uppl
y C
o., L
td #
3-4
270
Pow
er G
ener
atio
n Su
pply
Co.
, Ltd
# 1
-21,
600
2015
--
15,6
21.3
41.0
% V
SPP
5019
,635
.351
.6%
Pow
er p
urch
ased
from
nei
ghbo
ring
coun
tries
450
2,82
6.6
7.4%
38,0
83.2
31,7
3416
.6%
Add
ition
al C
apac
ity 2
009-
2015
(MW
)3,
768.
7
4,40
0.0
1,
985.
5
264.
0
6,64
9.5
2,
186.
6
12,6
04.8
Tot
al C
apac
ity a
t the
end
of 2
015 (
MW
)(A
fter l
ess r
etire
d ca
paci
ty)
15,6
21.3
15
,306
.7
4,06
4.6
26
4.0
19
,635
.3
2,82
6.6
38
,083
.2
Yea
rT
otal
Cap
acity
Peak
Dem
and
Res
erve
d M
argi
n
Proj
ects
Nam
eM
WPr
ojec
ts N
ame
Proj
ects
Nam
eM
W
Tab
le 2
.2 (C
ontin
ued)
Lis
t of P
roje
cts a
s Tha
iland
Pow
er D
evel
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15
3. Power Demand Forecasting
The load forecast used for the preparation of the PDP 2007: Revision 2 was
amended from the “September 2007 Load Forecast” which was previously amended from
the “March 2007 Load Forecast” prepared by Thailand Load Forecast Subcommittee, as
the following description.
1. The “March 2007 Load Forecast” prepared by Thailand Load Forecast
Subcommittee is based on the following assumption.
1.1 The growth of Gross Domestic Product (GDP) was forecasted by the
Macro Economic Planning Office, the National Economic and Social Development Board
based on the economic projection from 2006 to 2016 used for the respective load forecast
with the annual average GDP growth rate in 2006 – 2016 as shown below.
GDP Growth Rate Projection in 2006 – 2016
Year 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016
GDP (%) 4.6 4.8 5.0 5.2 5.0 5.0 5.3 5.5 5.5 5.8 5.8
The annual average GDP growth rate is referred to the GDP growth rate in the
10th National Economic and Social Development Plan (2007 – 2011) and the 11th National
Economic and Social Development Plan (2012 – 2016) which rate is approximately 5.0 %
and 5.6 % respectively. The main assumption applied for such projection is the growth of
global economic with the rate of 3.5 % - 4.7 % and Dubai Oil Price of 55 – 60 US Dollars
per Barrel.
1.2 The Thailand Load Forecast Subcommittee had projected additional
GDP growth rate from 2017 to 2021 (12th National Economic and Social Development
Plan) equal to the average rate of 5.6 % in the 11th National Economic and Social
Development Plan. The load forecast was considered as base case while low and high
cases were also prepared with respect to the annual GDP growth rate of 0.5 % lower and
higher than the base case respectively.
16
GDP Projection for Load Forecast (%)
March 2007
Year 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021
Low 4.0 4.5 4.7 4.5 4.5 4.8 5.0 5.0 5.3 5.3 5.2 5.1 5.0 5.0 5.0
Base 4.8 5.0 5.2 5.0 5.0 5.3 5.5 5.5 5.8 5.8 5.7 5.6 5.5 5.5 5.5
High 5.0 5.5 5.7 5.5 5.5 5.8 6.0 6.0 6.3 6.3 6.2 6.1 6.0 6.0 6.0
1.3 In the March 2007 Load Forecast, the energy loss in transmission and
distribution system was specified as follows:
- Energy loss in EGAT transmission system was fixed constant for the
whole period of the forecast (2007-2021), equal to 2.5 % of total energy sale.
- Energy loss in distribution system of the Metropolitan Electricity
Authority (MEA) was fixed constant for the whole period of the forecast (2007-2021),
equal to 3.64 % of total energy demand of MEA.
- Energy loss in distribution system of the Provincial Electricity
Authority (PEA) in the period 2007 – 2011 and 2012 – 2021 was 5.1 % and 5.0 % of total
energy demand of PEA respectively.
1.4 The Demand Side Management (DSM) was considered in the March
2007 Load Forecast with various measures for energy saving, i. e. the specification of
different rate of tariff according to Time of Use (TOU) which can reflect the actual cost,
the efficiency specification of electric devices such as the energy label 5 for air conditioner
and refrigerator, the establishment of an energy management company (ESCO), energy
saving project in building and factory. The mentioned measures were expected to reduce
future energy elasticity as of MEA and PEA given in this load forecast. Furthermore, the
Ministry of Energy have launch a project to replace lighting with energy saving light which
was expected to save 330 GWh energy.
1.5 The March 2007 Load Forecast considered the power purchase from the
Very Small Power Producers (VSPP) since it is the Government policy to promote the
power generation from renewable energy. This will increase the quantity of future VSPP
17
which can directly sell electricity to MEA and PEA. The amount of VSPP electricity sold
to MEA and PEA will reduce the energy demand of MEA and PEA to purchase from
EGAT. The expected energy of VSPP selling to MEA and PEA was estimated as follows:
- VSPP in MEA area categorized into two groups
1) Cogeneration or Combined Heat and Power (CHP) is former MEA
large scale power users locating close to the gas pipeline and consumes natural gas. The
energy produced from CHP will be partially consumed in its own factory that reduces their
purchased energy from MEA and the remaining energy will be sold to MEA that reduces
MEA purchased energy from EGAT. It was forecasted that the CHP producers will reduce
311 GWh of the energy purchased from MEA while they could sell 1,351 GWh of energy
to MEA in 2021.
2) Renewable Energy in MEA area is mainly residential power users who
installed solar cell on their roof and generate power for their own consumption while the
remaining energy will be sold to MEA. It was forecasted that this group of VSPP will grow
up 5 % annually and will reduce 3 GWh of the purchased energy from MEA while the
remaining energy selling to MEA will be approximately 17 GWh in 2021.
In conclusion, VSPP in MEA area will reduce 314 GWh of purchased energy
from MEA and reduce 3,107 GWh of the MEA purchased energy from EGAT or
equivalent to the peak power of 231 MW in 2021.
- In PEA area, VSPPs were expected from the SPPs who previously
proposed power purchase with EGAT, both non-firm SPPs who have already operated and
non-firm SPPs who are on progress. Since 2009, there will be new VSPPs to sell energy to
PEA increasing 10 % every year. Therefore, PEA will purchase the total energy of 3,107
GWh from VSPPs or equivalent to the peak power of 740 MW in 2021.
2. The “September 2007 Load Forecast” was amended from the “March 2007
Load Forecast” which energy demand was reviewed based on statistical trend in 2007. It
was expected that the energy demand growth rate of MEA and PEA from 2007 remained
the same as given in continuous growth of the March 2007 Load Forecast as the energy
18
demand during 2007 - 2021 will reduce approximately 2,592 – 5,321 GWh or 1.6 % - 1.9
%. The peak demand was kept as given in the March 2007 Load Forecast.
3. The amendment of “December 2008 Load Forecast” is as follows:
3.1 In the amendment of the December 2008 load forecast for using in
revising the power development plan, the load forecast was reviewed to cope with the
economic growth projection in base case as endorsed by the Thailand Load Forecast
Subcommittee on December 8, 2008. The load forecast was reviewed with the actual data
and the adjustment of the GDP growth rate in base case during 2009 – 2011 to cope with
the global economic recession while the same values of GDP growth rate during 2012 –
2021 as used in the March 2007 load forecast were still applied in this amendment. This
amendment resulted in the reduction of 28,273 GWh on energy demand and 4,333 MW on
peak demand compared with the September 2007 load forecast.
The economic growth rate projection in base case as endorsed by the
Thailand Load Forecast Subcommittee in 2009 – 2011 was estimated to be 2.0 %, 3.0 %
and 4.5% respectively while the growth rates in 2012 – 2021 is equal to the values in the
March 2007 load forecast which annual average is 5.6 %. Besides, the high case and low
case of load forecast were also prepared in which the GDP growth rates in 2009 – 2010 of
the high and low cases are 1.0 % higher and lower than the base case as well as the GDP
growth rates in 2011 - 2021 of the high and low cases are 0.5 % higher and lower than the
base case. Therefore, the GDP growth rates in 2011 - 2021 of the base, high and low cases
remain the same as in the March 2007 load forecast.
GDP Projection for Load Forecast (%)
December 2008
Year 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021
Low - 1.0 2.0 4.0 4.8 5.0 5.0 5.3 5.3 5.2 5.1 5.0 5.0 5.0
Base 3.9 2.0 3.0 4.5 5.3 5.5 5.5 5.8 5.8 5.7 5.6 5.5 5.5 5.5
High - 3.0 4.0 5.0 5.8 6.0 6.0 6.3 6.3 6.2 6.1 6.0 6.0 6.0
19
3.2 The energy demand forecast was carried out using the same elasticity as
in the September 2007 load forecast considering the energy which the distribution
electricity authorities purchase from VSPPs.
3.3 The peak demand forecast was carried out using the same load factor as
in the September 2007 load forecast.
The amended load forecast (December 2008) compared with the September
2007 load forecast indicate the following differences.
September 2007 (1) December 2008 (2) Difference (2)-(1)
Year Peak Energy Peak Energy Peak Energy
(MW) (GWh) (MW) (GWh) (MW) (GWh)
2551 23,490 152,124 22,017 147,229 -1,473 -4,895
2552 24,784 160,798 22,886 150,458 -1,898 -10,340
2553 26,206 170,037 23,936 155,645 -2,270 -14,392
2554 27,540 178,824 25,085 162,884 - 2,455 -15,940
2555 29,172 189,483 26,572 172,593 -2,600 -16,890
2556 30,946 201,148 28,188 183,218 -2,758 -17,930
2557 32,794 213,343 29,871 194,326 -2,923 -19,017
2558 34,840 226,823 31,734 206,604 -3,106 -20,219
2559 36,968 240,803 33,673 219,339 -3,295 -21,464
2560 39,158 255,156 35,668 232,413 -3,490 -22,743
2561 41,417 270,019 37,725 245,950 -3.692 -24,069
2562 43,726 285,158 39,828 259,740 -3,898 -25,418
2563 46,137 300,971 42,024 274,144 -4,113 -26,827
2564 48,614 317,193 44,281 288,920 -4,333 -28,273
20
4. Thailand Power Development Plan (PDP 2007: Revision 2)
This PDP 2007: Revision 1 covers the planning horizon during 2007-2021. The
detail of the plan can be described as follows:
4.1 Power Development Plan: The total additional generation capacity
during the period of 2007-2021 netted the power purchase from SPP, VSPP and the
retirement of aging power plants is 22,652.5 MW. Accounting the contracted capacity of
29,139.5 MW, the total installed capacity by the end of plan in 2021 will be 51,792.0 MW.
The details of power plants, power purchase from IPP, SPP, VSPP andneighboring
countries are shown in Table 4.1 and Figure 4.1 while the detailed capacity by power plant
type is shown in Appendix 9.
4.2 New Power Plant Projects during 2009 – 2015: The total installed
capacity of the new projects during this period is 12,604.8 MW. The list of projects
categorized by power producers are:
4.2.1 EGAT Projects:
- South Bangkok Combined Cycle Power Plant Block 3 710 MW
- Bang Pakong Combined Cycle Power Plant Block 5 710 MW
- North Bangkok Combined Cycle Power Plant Block 1 670 MW
- Wang Noi Combined Cycle Power Plant Block 4 800 MW
- Chana Combined Cycle Power Plant Block 2 800 MW
3,690 MW
4.2.2 IPP Projects:
- GHECO-One 660 MW
- Siam Energy Block 1-2 2x800 MW
- National Power Supply (NPS) Unit 1-4 4x135 MW
- Power Generation Supply Block 1-2 2x800 MW
4,400 MW
21
4.2.3 Renewable Projects:
- Small Hydropower Plants 78.7 MW
- Solar Energy Power Plants (Non-firm) (1) MW
- Wind Energy Power Plants (Non-firm) (2) MW
78.7 MW
4.2.4 Power Purchased from SPPs:
- SPP - Cogeneration 1,644 MW
- SPP - Renewable energy 341.5 MW
1,985.5 MW
4.2.5 Power Purchased from VSPPs 264 MW
4.2.6 Power Purchased from Neighboring Countries:
- Nam Theun 2 (Lao PDR) 920 MW
- Nam Ngum 2 (Lao PDR) 596.6 MW
- Theun Hinboun – Expansion (Lao PDR) 220 MW
- New Project 450 MW
4.3 New Power Plant Projects during 2016 – 2021: Projects presented in
the plan in this period are all new projects with the total capacity of 17,550 MW as
follows:
4.3.1 EGAT Projects:
- EGAT Coal-Fired Power Plants 2,800 MW
- EGAT New Power Plants 3,200 MW
- EGAT Nuclear Power Plants 2,000 MW
11,200 MW
4.3.2 IPP Projects: the total capacity is 1,600 MW.
4.3.3 New Projects: the total capacity is 4,800 MW.
4.3.4 Power Purchased from VSPPs: the total capacity is 300 MW.
4.3.5 Power Purchased from Neighboring Countries: the total capacity is
2,850 MW.
22
4.4 Fuel Consumption for Power Generation: The estimate of annual fuel
consumption for power generation during 2009-2021 according to the PDP 2007: Revision
2 can be summarized as the following table.
Year Lignite (Mton)
Coal (Mton)
Gas/LNG (mmcfd)
Heavy Oil (Mliters)
Diesel Oil (Mliters)
Nuclear (Ton)
2009 16.3 3.7 2,064 77.51 13.30 -
2010 16.3 3.7 2,025 28.60 8.29 -
2011 16.6 4.4 2,040 - 8.29 -
2012 16.2 5.5 2,064 0.01 8.28 -
2013 16.6 5.6 2,136 - 10.64 -
2014 15.8 6.9 2,138 - 7.20 -
2015 15.7 7.0 2,136 0.03 7.20 -
2016 15.1 10.8 2,284 0.19 7.22 -
2017 15.1 14.5 2,287 0.17 7.00 -
2018 15.1 14.5 2,494 0.28 6.30 -
2019 14.5 14.5 2,701 0.16 6.30 -
2020 14.5 14.6 2,783 0.36 5.62 22.93
2021 13.6 14.5 2,891 0.35 5.60 45.72
Remark: Considering Gas/LNG as fuel for EGAT and IPP new power plants but not
including SPP power plants
(Details of estimation of energy generation classified by fuel types are shown in
the Appendix 10)
Table 4.1
List of Projects as Thailand Power Development Plan 2008-2021
(PDP 2007: Revision 2)
Power Plant Project Names Fuel Types Capacity Total Scheduled
(MW) (MW) VSPP - 6 6 January 2009 SPP (Renew) - 26.5 27 Jan 09 - Mar 09 South Bangkok CC # 3 Gas 710 710 March 2009 Bang Pakong CC # 5 Gas 710 710 July 2009 Power purchased from Lao PDR (Nam Theun 2) Hydro 920 920 November 2009 Wind energy and Solar energy - (3) (3) December 2009 Small Hydro Power Plants Hydro 78.7 79 2009 - 2011 VSPP - 10 10 January 2010 North Bangkok CC # 1 Gas 670 670 May 2010 SPP (Co-Gen) - 90 90 November 2010 Power purchased from Lao PDR (Nam Ngum 2) Hydro 596.6 597 January 2011 VSPP - 48 48 January 2011 SPP (Renew) - 250 250 August 2011 Gheco-one Co.,Ltd Coal 660 660 November 2011 SPP (Renew) - 65 65 January 2012 VSPP - 50 50 January 2012 SPP (Co-Gen) - 924 924 June 2012 Power purchased from Lao PDR (Theun Hinbun-expand Hydro 220 220 July 2012 VSPP - 50 50 January 2013 Siam Energy Co., Ltd # 1-2 Gas 2x800 1,600 Mar 13 - Sep 13 SPP (Co-Gen) - 540 540 June 2013 National Power Supply Co., Ltd # 1-2 Coal 2x135 270 November 2013 VSPP - 50 50 January 2014 National Power Supply Co., Ltd # 3-4 Coal 2x135 270 March 2014 SPP (Co-Gen) - 90 90 June 2014 Wang Noi CC # 4 Gas 800 800 June 2014 Power Generation Supply Co., Ltd # 1-2 Gas 2x800 1,600 Jun 14 - Dec 14 Chana CC # 2 Gas 800 800 July 2014 VSPP - 50 50 January 2015 Power purchased from neighboring countries - 450 450 June 2015
Commissioning Date
23
Table 4.1 (Continued)List of Projects as Thailand Power Development Plan 2008-2021
(PDP 2007: Revision 2)
Power Plant Project Names Fuel Types Capacity Total Scheduled(MW) (MW)
VSPP - 50 50 January 2016 Thermal power plant (Coal)_EGAT # 1-2 Coal 2x700 1,400 January 2016 Power purchased from neighboring countries - 450 450 March 2016 New power plant_South Gas 800 800 July 2016 VSPP - 50 50 January 2017 Thermal power plant (Coal)_EGAT # 3-4 Coal 2x700 1,400 January 2017 New power plant Gas 800 800 January 2017 Power purchased from neighboring countries - 450 450 January 2017 VSPP - 50 50 January 2018 South Bangkok CC # 4-5 Gas 2x800 1,600 January 2018 Bang Pakong CC # 6 Gas 800 800 January 2018 Power purchased from neighboring countries - 450 450 January 2018 VSPP - 50 50 January 2019 North Bangkok CC # 2 Gas 800 800 January 2019 New power plant Gas 2x800 1,600 January 2019 Power purchased from neighboring countries - 500 500 January 2019 VSPP - 50 50 January 2020 Thermal power plant (Nuclear)_EGAT # 1 Nuclear 1000 1,000 January 2020 New power plant _IPP - 2x800 1,600 January 2020 Power purchased from neighboring countries - 500 500 January 2020 VSPP - 50 50 January 2021 Thermal power plant (Nuclear)_EGAT # 2 Nuclear 1000 1,000 January 2021 New power plant Gas 2x800 1,600 January 2021 Power purchased from neighboring countries - 500 500 January 2021
Total installed capacity as of December 2008 29,139.5 MWTotal added capacity 30,154.8 MWTotal retired capacity -7,502.3 MW
Grand total capacity at the end of 2021 51,792.0 MW
Commissioning Date
24
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O_G
REE
N)
6.
5 M
W;
VSPP
6
MW
PO
WER
DEV
ELO
PM
ENT
PLA
NTh
aila
nd P
DP2
007
: Re
visi
on 2
GEN
ERAT
ION
SYS
TEM
DEV
ELO
PMEN
T PL
ANN
ING
DEP
ARTM
ENT
LOAD
FO
RECA
ST :
Dec
embe
r 20
08SY
STEM
PLA
NN
ING
DIV
ISIO
NRU
N D
ATE
: M
arch
24,
200
9EL
ECTR
ICIT
Y G
ENER
ATIN
G A
UTH
ORI
TY O
F TH
AILA
ND
PEA
K A
ND
CA
PA
CIT
Y (
MW
)M
W29
,139
.5EX
ISTI
NG
CA
PA
CIT
Y10
000
2000
030
000
4000
050
000
6000
070
000
8000
090
000
1000
00
JAN
2009
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
JAN
2010
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
JAN
2011
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
JAN
2012
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
JAN
2013
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
JAN
2014
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
FIGURE 4.1 THAILAND POWER DEVE
-1,3
41.6
SPP_
(REN
EW)
10
MW
; SO
UTH
_BAN
GKO
K_CC
#3
71
0 M
W72
0.0
BAN
G_P
AKO
NG
_CC#
5 71
0 M
W71
0.0
IMPO
RT_
FRO
M_L
AOS_
(NT2
)
920
MW
920.
0CH
AO P
HRAY
A D
AM#
1 6
MW
; SO
LAR
(1)
MW
; W
IND
(
2) M
W6.
0
PEAK
GEN
ERAT
ION
22,8
86.0
0M
W
MIN
IMU
M R
ESER
VE M
ARG
IN22
.44
%
ADD
ITIO
NAL
CAP
ACIT
Y2,
378.
50M
W
RET
IRED
CAP
ACIT
Y-1
,364
.10
MW
NET
CAP
ACIT
Y IN
YEA
R1,
014.
40M
W
TOTA
L CA
PACI
TY30
,153
.91
MW
VSPP
1
0 M
W10
.0
CHAO
PH
RAY
A D
AM#
2 6
MW
6.0
NO
RTH
_BAN
GKO
K_CC
#1
67
0 M
W67
0.0
MEA
KLO
NG
DAM
#1
6
MW
6.0
PASA
K JO
LASI
D D
AM
6.7
MW
6.7
SPP_
(CO
-GEN
)
90 M
W;
KHU
N D
AN P
RAK
ARN
CHO
N D
AM
10
MW
100.
0M
EA K
LON
G D
AM#
2 6
MW
6.0
PEAK
GEN
ERAT
ION
23,9
36.0
0M
W
MIN
IMU
M R
ESER
VE M
ARG
IN23
.97
%
ADD
ITIO
NAL
CAP
ACIT
Y80
4.70
MW
RET
IRED
CAP
ACIT
Y0.
00M
W
NET
CAP
ACIT
Y IN
YEA
R80
4.70
MW
TOTA
L CA
PACI
TY30
,958
.61
MW
IMPO
RT_
FRO
M_L
AOS_
(NN
G2)
5
96.6
MW
; KW
AE N
OI
DAM
#1
15
MW
; VS
PP
48
MW
659.
6N
ARES
UAN
DAM
8
MW
8.0
KWAE
NO
I D
AM#
2 15
MW
15.0
PPB_
TH#
1_(P
PA_E
ND
)
-69.
9 M
W-6
9.9
GH
ECO
-ON
E 66
0 M
W66
0.0
PEAK
GEN
ERAT
ION
25,0
85.0
0M
W
MIN
IMU
M R
ESER
VE M
ARG
IN23
.66
%
ADD
ITIO
NAL
CAP
ACIT
Y1,
592.
60M
W
RET
IRED
CAP
ACIT
Y-6
9.90
MW
NET
CAP
ACIT
Y IN
YEA
R1,
522.
70M
W
TOTA
L CA
PACI
TY32
,481
.31
MW
VSPP
5
0 M
W;
SPP_
(REN
EW)
65
MW
115.
0
IMPO
RT_
FRO
M_L
AOS_
(TH
B_EX
T)
220
MW
220.
0PE
AK G
ENER
ATIO
N26
,572
.00
MW
MIN
IMU
M R
ESER
VE M
ARG
IN20
.34
%
ADD
ITIO
NAL
CAP
ACIT
Y1,
259.
00M
W
RET
IRED
CAP
ACIT
Y0.
00M
W
NET
CAP
ACIT
Y IN
YEA
R1,
259.
00M
W
TOTA
L CA
PACI
TY33
,740
.31
MW
VSPP
5
0 M
W50
.0
SIAM
_EN
ERG
Y_#
1 80
0 M
W80
0.0
540.
0
SIAM
_EN
ERG
Y_#
2 80
0 M
W80
0.0
NAT
ION
AL_P
OW
ER_S
UPP
LY_#
1-2
2x
135
MW
270.
0
PEAK
GEN
ERAT
ION
28,1
88.0
0M
W
MIN
IMU
M R
ESER
VE M
ARG
IN20
.43
%
ADD
ITIO
NAL
CAP
ACIT
Y2,
460.
00M
W
RET
IRED
CAP
ACIT
Y0.
00M
W
NET
CAP
ACIT
Y IN
YEA
R2,
460.
00M
W
TOTA
L CA
PACI
TY36
,200
.31
MW
BPK_
TH#
1-2_
(RET
IRE)
-
525.
5,-5
26.5
MW
; VS
PP
50
MW
-1,0
02.0
NAT
ION
AL_P
OW
ER_S
UPP
LY_#
3-4
2x
135
MW
270.
0
WAN
G_N
OI_
CC#
4
800
MW
; PO
WER
_GEN
_SU
PPLY
_#1
80
0 M
W;
SPP_
(CO
-GEN
) 90
MW
1,69
0.0
CHAN
A_CC
#2
80
0 M
W80
0.0
PEAK
GEN
ERAT
ION
29,8
71.0
0M
W
MIN
IMU
M R
ESER
VE M
ARG
IN16
.59
%
ADD
ITIO
NAL
CAP
ACIT
Y3,
610.
00M
W
RET
IRED
CAP
ACIT
Y-1
,052
.00
MW
NET
CAP
ACIT
Y IN
YEA
R2,
558.
00M
W
NO
NG
_CH
OK_
GT#
1-3_
(RET
IRE)
-3
x117
MW
; SU
RAT
_TH
ANI_
GT#
1-2_
(RET
IRE)
-2
x117
MW
; SB
_TH
#4-
5_(R
ETIR
E)
-5
59 M
W;
LKB_
GT#
1-11
_(RET
IRE)
-
220.
1 M
W;
SPP_
(DAN
_CH
ANG
_BIO
)
10 M
W;
SPP_
(DEJ
A_BI
O_G
REE
N)
6.
5 M
W;
VSPP
6
MW
SPP_
(REN
EW)
25
0 M
W25
0.0
SPP_
(CO
-GEN
) 9
24 M
W
924.
0
SPP_
(CO
-GEN
)
540
MW
PO
WER
DEV
ELO
PM
ENT
PLA
NTh
aila
nd P
DP2
007
: Re
visi
on 2
GEN
ERAT
ION
SYS
TEM
DEV
ELO
PMEN
T PL
ANN
ING
DEP
ARTM
ENT
LOAD
FO
RECA
ST :
Dec
embe
r 20
08SY
STEM
PLA
NN
ING
DIV
ISIO
NRU
N D
ATE
: M
arch
24,
200
9EL
ECTR
ICIT
Y G
ENER
ATIN
G A
UTH
ORI
TY O
F TH
AILA
ND
PEA
K A
ND
CA
PA
CIT
Y (
MW
)M
W29
,139
.5EX
ISTI
NG
CA
PA
CIT
Y10
000
2000
030
000
4000
050
000
6000
070
000
8000
090
000
1000
00
JAN
2009
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
JAN
2010
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
JAN
2011
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
JAN
2012
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
JAN
2013
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
JAN
2014
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
JAN
2015
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
JAN
2016
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
JAN
2017
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
JAN
2018
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
FIGURE 4.1 THAILAND POWER DEVELOPMENT PLAN (PDP 2007 : REVISIO
-1,3
41.6
SPP_
(REN
EW)
10
MW
; SO
UTH
_BAN
GKO
K_CC
#3
71
0 M
W72
0.0
BAN
G_P
AKO
NG
_CC#
5 71
0 M
W71
0.0
IMPO
RT_
FRO
M_L
AOS_
(NT2
)
920
MW
920.
0CH
AO P
HRAY
A D
AM#
1 6
MW
; SO
LAR
(1)
MW
; W
IND
(
2) M
W6.
0
PEAK
GEN
ERAT
ION
22,8
86.0
0M
W
MIN
IMU
M R
ESER
VE M
ARG
IN22
.44
%
ADD
ITIO
NAL
CAP
ACIT
Y2,
378.
50M
W
RET
IRED
CAP
ACIT
Y-1
,364
.10
MW
NET
CAP
ACIT
Y IN
YEA
R1,
014.
40M
W
TOTA
L CA
PACI
TY30
,153
.91
MW
VSPP
1
0 M
W10
.0
CHAO
PH
RAY
A D
AM#
2 6
MW
6.0
NO
RTH
_BAN
GKO
K_CC
#1
67
0 M
W67
0.0
MEA
KLO
NG
DAM
#1
6
MW
6.0
PASA
K JO
LASI
D D
AM
6.7
MW
6.7
SPP_
(CO
-GEN
)
90 M
W;
KHU
N D
AN P
RAK
ARN
CHO
N D
AM
10
MW
100.
0M
EA K
LON
G D
AM#
2 6
MW
6.0
PEAK
GEN
ERAT
ION
23,9
36.0
0M
W
MIN
IMU
M R
ESER
VE M
ARG
IN23
.97
%
ADD
ITIO
NAL
CAP
ACIT
Y80
4.70
MW
RET
IRED
CAP
ACIT
Y0.
00M
W
NET
CAP
ACIT
Y IN
YEA
R80
4.70
MW
TOTA
L CA
PACI
TY30
,958
.61
MW
IMPO
RT_
FRO
M_L
AOS_
(NN
G2)
5
96.6
MW
; KW
AE N
OI
DAM
#1
15
MW
; VS
PP
48
MW
659.
6N
ARES
UAN
DAM
8
MW
8.0
KWAE
NO
I D
AM#
2 15
MW
15.0
PPB_
TH#
1_(P
PA_E
ND
)
-69.
9 M
W-6
9.9
GH
ECO
-ON
E 66
0 M
W66
0.0
PEAK
GEN
ERAT
ION
25,0
85.0
0M
W
MIN
IMU
M R
ESER
VE M
ARG
IN23
.66
%
ADD
ITIO
NAL
CAP
ACIT
Y1,
592.
60M
W
RET
IRED
CAP
ACIT
Y-6
9.90
MW
NET
CAP
ACIT
Y IN
YEA
R1,
522.
70M
W
TOTA
L CA
PACI
TY32
,481
.31
MW
VSPP
5
0 M
W;
SPP_
(REN
EW)
65
MW
115.
0
IMPO
RT_
FRO
M_L
AOS_
(TH
B_EX
T)
220
MW
220.
0PE
AK G
ENER
ATIO
N26
,572
.00
MW
MIN
IMU
M R
ESER
VE M
ARG
IN20
.34
%
ADD
ITIO
NAL
CAP
ACIT
Y1,
259.
00M
W
RET
IRED
CAP
ACIT
Y0.
00M
W
NET
CAP
ACIT
Y IN
YEA
R1,
259.
00M
W
TOTA
L CA
PACI
TY33
,740
.31
MW
VSPP
5
0 M
W50
.0
SIAM
_EN
ERG
Y_#
1 80
0 M
W80
0.0
540.
0
SIAM
_EN
ERG
Y_#
2 80
0 M
W80
0.0
NAT
ION
AL_P
OW
ER_S
UPP
LY_#
1-2
2x
135
MW
270.
0
PEAK
GEN
ERAT
ION
28,1
88.0
0M
W
MIN
IMU
M R
ESER
VE M
ARG
IN20
.43
%
ADD
ITIO
NAL
CAP
ACIT
Y2,
460.
00M
W
RET
IRED
CAP
ACIT
Y0.
00M
W
NET
CAP
ACIT
Y IN
YEA
R2,
460.
00M
W
TOTA
L CA
PACI
TY36
,200
.31
MW
BPK_
TH#
1-2_
(RET
IRE)
-
525.
5,-5
26.5
MW
; VS
PP
50
MW
-1,0
02.0
NAT
ION
AL_P
OW
ER_S
UPP
LY_#
3-4
2x
135
MW
270.
0
WAN
G_N
OI_
CC#
4
800
MW
; PO
WER
_GEN
_SU
PPLY
_#1
80
0 M
W;
SPP_
(CO
-GEN
) 90
MW
1,69
0.0
CHAN
A_CC
#2
80
0 M
W80
0.0
POW
ER_G
EN_S
UPP
LY_#
2 80
0 M
W80
0.0
PEAK
GEN
ERAT
ION
29,8
71.0
0M
W
MIN
IMU
M R
ESER
VE M
ARG
IN16
.59
%
ADD
ITIO
NAL
CAP
ACIT
Y3,
610.
00M
W
RET
IRED
CAP
ACIT
Y-1
,052
.00
MW
NET
CAP
ACIT
Y IN
YEA
R2,
558.
00M
W
TOTA
L CA
PACI
TY38
,758
.31
MW
RY_
CC#
1-4_
(PPA
_EN
D)
-1
175.
1 M
W;
VSPP
5
0 M
W-1
,125
.1
IMPO
RT_
POW
ER
45
0 M
W45
0.0
PEAK
GEN
ERAT
ION
31,7
34.0
0M
W
MIN
IMU
M R
ESER
VE M
ARG
IN16
.57
%
ADD
ITIO
NAL
CAP
ACIT
Y50
0.00
MW
RET
IRED
CAP
ACIT
Y-1
,175
.10
MW
NET
CAP
ACIT
Y IN
YEA
R-6
75.1
0M
W
TOTA
L CA
PACI
TY38
,083
.21
MW
EGAT
_CO
AL#
1-2
2
x700
MW
; VS
PP
50
MW
1,45
0.0
IMPO
RT_
POW
ER
45
0 M
W45
0.0
PPB_
TH#
2_(P
PA_E
ND
)
-70.
2 M
W-7
0.2
KN_C
C_(P
PA_E
ND
)
-678
MW
; N
EW_C
APAC
ITY_
SOU
THER
N
800
MW
122.
0PE
AK G
ENER
ATIO
N33
,673
.00
MW
MIN
IMU
M R
ESER
VE M
ARG
IN16
.64
%
ADD
ITIO
NAL
CAP
ACIT
Y2,
700.
00M
W
RET
IRED
CAP
ACIT
Y-7
48.2
0M
W
NET
CAP
ACIT
Y IN
YEA
R1,
951.
80M
W
TOTA
L CA
PACI
TY40
,035
.01
MW
VSPP
5
0 M
W2,
386.
0
GLO
W_E
NER
GY#
1_(P
PA_E
ND
) -9
0 M
W-9
0.0
GLO
W_E
NER
GY#
2_(P
PA_E
ND
) -9
0 M
W-9
0.0
PEAK
GEN
ERAT
ION
35,6
68.0
0M
W
MIN
IMU
M R
ESER
VE M
ARG
IN16
.61
%
ADD
ITIO
NAL
CAP
ACIT
Y2,
700.
00M
W
RET
IRED
CAP
ACIT
Y-4
94.0
0M
W
NET
CAP
ACIT
Y IN
YEA
R2,
206.
00M
W
TOTA
L CA
PACI
TY42
,241
.01
MW
BAN
G P
AKO
NG
CC#
6 80
0 M
W;
IMPO
RT
POW
ER
450
MW
; VS
PP
50
MW
2,26
1.0
TPT_
UTI
LITY
_(PP
A_EN
D)
-1
0 M
W-1
0.0
PTT_
CHEM
ICAL
_(PP
A_EN
D)
-3
2 M
W-3
2.0
PEAK
GEN
ERAT
ION
37,7
25.0
0M
W
MIN
IMU
M R
ESER
VE M
ARG
IN15
.81
%
NO
NG
_CH
OK_
GT#
1-3_
(RET
IRE)
-3
x117
MW
; SU
RAT
_TH
ANI_
GT#
1-2_
(RET
IRE)
-2
x117
MW
; SB
_TH
#4-
5_(R
ETIR
E)
-5
59 M
W;
LKB_
GT#
1-11
_(RET
IRE)
-
220.
1 M
W;
SPP_
(DAN
_CH
ANG
_BIO
)
10 M
W;
SPP_
(DEJ
A_BI
O_G
REE
N)
6.
5 M
W;
VSPP
6
MW
SPP_
(REN
EW)
25
0 M
W25
0.0
SPP_
(CO
-GEN
) 9
24 M
W
924.
0
SPP_
(CO
-GEN
)
540
MW
BPK_
CC#
3_(R
ETIR
E)
-31
4 M
W;
NEW
_CAP
ACIT
Y 80
0 M
W;
EGAT
_CO
AL#
3-4
2
x700
MW
; IM
PORT_
POW
ER
45
0 M
W;
BPK_
CC#
4_(R
ETIR
E)
-31
4 M
W;
NPO
_CC#
1_(R
ETIR
E)
-32
5 M
W;
SOU
TH B
ANG
KOK
CC#
4-5
2x
800
MW
;
PO
WER
DEV
ELO
PM
ENT
PLA
NTh
aila
nd P
DP2
007
: Re
visi
on 2
GEN
ERAT
ION
SYS
TEM
DEV
ELO
PMEN
T PL
ANN
ING
DEP
ARTM
ENT
LOAD
FO
RECA
ST :
Dec
embe
r 20
08SY
STEM
PLA
NN
ING
DIV
ISIO
NRU
N D
ATE
: M
arch
24,
200
9EL
ECTR
ICIT
Y G
ENER
ATIN
G A
UTH
ORI
TY O
F TH
AILA
ND
PEA
K A
ND
CA
PA
CIT
Y (
MW
)M
W29
,139
.5EX
ISTI
NG
CA
PA
CIT
Y10
000
2000
030
000
4000
050
000
6000
070
000
8000
090
000
1000
00
JAN
2009
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
JAN
2010
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
JAN
2011
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
JAN
2012
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
JAN
2013
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
JAN
2014
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
JAN
2015
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
JAN
2016
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
JAN
2017
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
JAN
2018
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
JAN
2019
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
JAN
2020
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
JAN
2021
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
1000
020
000
3000
040
000
5000
060
000
7000
080
000
9000
010
0000
FIGURE 4.1 THAILAND POWER DEVELOPMENT PLAN (PDP 2007 : REVISION 2)
-1,3
41.6
SPP_
(REN
EW)
10
MW
; SO
UTH
_BAN
GKO
K_CC
#3
71
0 M
W72
0.0
BAN
G_P
AKO
NG
_CC#
5 71
0 M
W71
0.0
IMPO
RT_
FRO
M_L
AOS_
(NT2
)
920
MW
920.
0CH
AO P
HRAY
A D
AM#
1 6
MW
; SO
LAR
(1)
MW
; W
IND
(
2) M
W6.
0
PEAK
GEN
ERAT
ION
22,8
86.0
0M
W
MIN
IMU
M R
ESER
VE M
ARG
IN22
.44
%
ADD
ITIO
NAL
CAP
ACIT
Y2,
378.
50M
W
RET
IRED
CAP
ACIT
Y-1
,364
.10
MW
NET
CAP
ACIT
Y IN
YEA
R1,
014.
40M
W
TOTA
L CA
PACI
TY30
,153
.91
MW
VSPP
1
0 M
W10
.0
CHAO
PH
RAY
A D
AM#
2 6
MW
6.0
NO
RTH
_BAN
GKO
K_CC
#1
67
0 M
W67
0.0
MEA
KLO
NG
DAM
#1
6
MW
6.0
PASA
K JO
LASI
D D
AM
6.7
MW
6.7
SPP_
(CO
-GEN
)
90 M
W;
KHU
N D
AN P
RAK
ARN
CHO
N D
AM
10
MW
100.
0M
EA K
LON
G D
AM#
2 6
MW
6.0
PEAK
GEN
ERAT
ION
23,9
36.0
0M
W
MIN
IMU
M R
ESER
VE M
ARG
IN23
.97
%
ADD
ITIO
NAL
CAP
ACIT
Y80
4.70
MW
RET
IRED
CAP
ACIT
Y0.
00M
W
NET
CAP
ACIT
Y IN
YEA
R80
4.70
MW
TOTA
L CA
PACI
TY30
,958
.61
MW
IMPO
RT_
FRO
M_L
AOS_
(NN
G2)
5
96.6
MW
; KW
AE N
OI
DAM
#1
15
MW
; VS
PP
48
MW
659.
6N
ARES
UAN
DAM
8
MW
8.0
KWAE
NO
I D
AM#
2 15
MW
15.0
PPB_
TH#
1_(P
PA_E
ND
)
-69.
9 M
W-6
9.9
GH
ECO
-ON
E 66
0 M
W66
0.0
PEAK
GEN
ERAT
ION
25,0
85.0
0M
W
MIN
IMU
M R
ESER
VE M
ARG
IN23
.66
%
ADD
ITIO
NAL
CAP
ACIT
Y1,
592.
60M
W
RET
IRED
CAP
ACIT
Y-6
9.90
MW
NET
CAP
ACIT
Y IN
YEA
R1,
522.
70M
W
TOTA
L CA
PACI
TY32
,481
.31
MW
VSPP
5
0 M
W;
SPP_
(REN
EW)
65
MW
115.
0
IMPO
RT_
FRO
M_L
AOS_
(TH
B_EX
T)
220
MW
220.
0PE
AK G
ENER
ATIO
N26
,572
.00
MW
MIN
IMU
M R
ESER
VE M
ARG
IN20
.34
%
ADD
ITIO
NAL
CAP
ACIT
Y1,
259.
00M
W
RET
IRED
CAP
ACIT
Y0.
00M
W
NET
CAP
ACIT
Y IN
YEA
R1,
259.
00M
W
TOTA
L CA
PACI
TY33
,740
.31
MW
VSPP
5
0 M
W50
.0
SIAM
_EN
ERG
Y_#
1 80
0 M
W80
0.0
540.
0
SIAM
_EN
ERG
Y_#
2 80
0 M
W80
0.0
NAT
ION
AL_P
OW
ER_S
UPP
LY_#
1-2
2x
135
MW
270.
0
PEAK
GEN
ERAT
ION
28,1
88.0
0M
W
MIN
IMU
M R
ESER
VE M
ARG
IN20
.43
%
ADD
ITIO
NAL
CAP
ACIT
Y2,
460.
00M
W
RET
IRED
CAP
ACIT
Y0.
00M
W
NET
CAP
ACIT
Y IN
YEA
R2,
460.
00M
W
TOTA
L CA
PACI
TY36
,200
.31
MW
BPK_
TH#
1-2_
(RET
IRE)
-
525.
5,-5
26.5
MW
; VS
PP
50
MW
-1,0
02.0
NAT
ION
AL_P
OW
ER_S
UPP
LY_#
3-4
2x
135
MW
270.
0
WAN
G_N
OI_
CC#
4
800
MW
; PO
WER
_GEN
_SU
PPLY
_#1
80
0 M
W;
SPP_
(CO
-GEN
) 90
MW
1,69
0.0
CHAN
A_CC
#2
80
0 M
W80
0.0
POW
ER_G
EN_S
UPP
LY_#
2 80
0 M
W80
0.0
PEAK
GEN
ERAT
ION
29,8
71.0
0M
W
MIN
IMU
M R
ESER
VE M
ARG
IN16
.59
%
ADD
ITIO
NAL
CAP
ACIT
Y3,
610.
00M
W
RET
IRED
CAP
ACIT
Y-1
,052
.00
MW
NET
CAP
ACIT
Y IN
YEA
R2,
558.
00M
W
TOTA
L CA
PACI
TY38
,758
.31
MW
RY_
CC#
1-4_
(PPA
_EN
D)
-1
175.
1 M
W;
VSPP
5
0 M
W-1
,125
.1
IMPO
RT_
POW
ER
45
0 M
W45
0.0
PEAK
GEN
ERAT
ION
31,7
34.0
0M
W
MIN
IMU
M R
ESER
VE M
ARG
IN16
.57
%
ADD
ITIO
NAL
CAP
ACIT
Y50
0.00
MW
RET
IRED
CAP
ACIT
Y-1
,175
.10
MW
NET
CAP
ACIT
Y IN
YEA
R-6
75.1
0M
W
TOTA
L CA
PACI
TY38
,083
.21
MW
EGAT
_CO
AL#
1-2
2
x700
MW
; VS
PP
50
MW
1,45
0.0
IMPO
RT_
POW
ER
45
0 M
W45
0.0
PPB_
TH#
2_(P
PA_E
ND
)
-70.
2 M
W-7
0.2
KN_C
C_(P
PA_E
ND
)
-678
MW
; N
EW_C
APAC
ITY_
SOU
THER
N
800
MW
122.
0PE
AK G
ENER
ATIO
N33
,673
.00
MW
MIN
IMU
M R
ESER
VE M
ARG
IN16
.64
%
ADD
ITIO
NAL
CAP
ACIT
Y2,
700.
00M
W
RET
IRED
CAP
ACIT
Y-7
48.2
0M
W
NET
CAP
ACIT
Y IN
YEA
R1,
951.
80M
W
TOTA
L CA
PACI
TY40
,035
.01
MW
VSPP
5
0 M
W2,
386.
0
GLO
W_E
NER
GY#
1_(P
PA_E
ND
) -9
0 M
W-9
0.0
GLO
W_E
NER
GY#
2_(P
PA_E
ND
) -9
0 M
W-9
0.0
PEAK
GEN
ERAT
ION
35,6
68.0
0M
W
MIN
IMU
M R
ESER
VE M
ARG
IN16
.61
%
ADD
ITIO
NAL
CAP
ACIT
Y2,
700.
00M
W
RET
IRED
CAP
ACIT
Y-4
94.0
0M
W
NET
CAP
ACIT
Y IN
YEA
R2,
206.
00M
W
TOTA
L CA
PACI
TY42
,241
.01
MW
BAN
G P
AKO
NG
CC#
6 80
0 M
W;
IMPO
RT
POW
ER
450
MW
; VS
PP
50
MW
2,26
1.0
TPT_
UTI
LITY
_(PP
A_EN
D)
-1
0 M
W-1
0.0
PTT_
CHEM
ICAL
_(PP
A_EN
D)
-3
2 M
W-3
2.0
PEAK
GEN
ERAT
ION
37,7
25.0
0M
W
MIN
IMU
M R
ESER
VE M
ARG
IN15
.81
%
ADD
ITIO
NAL
CAP
ACIT
Y2,
900.
00M
W
RET
IRED
CAP
ACIT
Y-6
81.0
0M
W
NET
CAP
ACIT
Y IN
YEA
R2,
219.
00M
W
TOTA
L CA
PACI
TY44
,460
.01
MW
NO
RTH
BAN
GKO
K CC
#2
80
0 M
W;
NEW
_CAP
ACIT
Y
2x80
0 M
W;
IMPO
RT_
POW
ER
50
0 M
W;
VSPP
5
0 M
W2,
950.
0
MIL
ITAR
Y_FA
NG
_(PP
A_EN
D)
-9
MW
-9.0
GU
LF_C
OG
ENER
ATIO
N_(
PPA_
END
) -9
0 M
W;
AMAT
A_EG
CO_P
OW
ER_(
PPA_
END
) -9
0 M
W-1
80.0
PEAK
GEN
ERAT
ION
39,8
28.0
0M
W
MIN
IMU
M R
ESER
VE M
ARG
IN17
.01
%
ADD
ITIO
NAL
CAP
ACIT
Y2,
950.
00M
W
RET
IRED
CAP
ACIT
Y-1
89.0
0M
W
NET
CAP
ACIT
Y IN
YEA
R2,
761.
00M
W
TOTA
L CA
PACI
TY47
,221
.01
MW
NEW
_CAP
ACIT
Y_IP
P 2x
800
MW
; IM
PORT_
POW
ER
50
0 M
W;
VSPP
5
0 M
W2,
509.
0BA
NG
KOK_
COG
EN_(
PPA_
END
) -9
0 M
W-9
0.0
BPK_
POW
ER_S
UPP
LY_(
PPA_
END
)
-8 M
W-8
.0TE
CO_(
PPA_
END
) -7
00 M
W-7
00.0
SAM
UTP
RAK
ARN
_CO
GEN
_(PP
A_EN
D)
-9
0 M
W-9
0.0
PEAK
GEN
ERAT
ION
42,0
24.0
0M
W
MIN
IMU
M R
ESER
VE M
ARG
IN16
.12
%
ADD
ITIO
NAL
CAP
ACIT
Y3,
150.
00M
W
RET
IRED
CAP
ACIT
Y-1
,529
.00
MW
NET
CAP
ACIT
Y IN
YEA
R1,
621.
00M
W
TOTA
L CA
PACI
TY48
,842
.01
MW
EGAT
_NU
CLEA
R#
2 10
00 M
W;
NEW
_CAP
ACIT
Y
2x80
0 M
W;
IMPO
RT_
POW
ER
50
0 M
W;
VSPP
5
0 M
W3,
150.
0G
LOW
_SPP
#1_
PRO
J_1_
(PPA
_EN
D)
-5
5 M
W-5
5.0
GLO
W_S
PP#
1_PR
OJ_
2_(P
PA_E
ND
) -5
5 M
W-5
5.0
NO
NG
_KH
AE_C
OG
EN_(
PPA_
END
)
-90
MW
-90.
0
PEAK
GEN
ERAT
ION
44,2
81.0
0M
W
MIN
IMU
M R
ESER
VE M
ARG
IN15
.31
%
ADD
ITIO
NAL
CAP
ACIT
Y3,
150.
00M
W
RET
IRED
CAP
ACIT
Y-2
00.0
0M
W
NET
CAP
ACIT
Y IN
YEA
R2,
950.
00M
W
TOTA
L CA
PACI
TY51
,792
.01
MW
PEAK
GEN
ERAT
ION
NO
NG
_CH
OK_
GT#
1-3_
(RET
IRE)
-3
x117
MW
; SU
RAT
_TH
ANI_
GT#
1-2_
(RET
IRE)
-2
x117
MW
; SB
_TH
#4-
5_(R
ETIR
E)
-5
59 M
W;
LKB_
GT#
1-11
_(RET
IRE)
-
220.
1 M
W;
SPP_
(DAN
_CH
ANG
_BIO
)
10 M
W;
SPP_
(DEJ
A_BI
O_G
REE
N)
6.
5 M
W;
VSPP
6
MW
SPP_
(REN
EW)
25
0 M
W25
0.0
SPP_
(CO
-GEN
) 9
24 M
W
924.
0
SPP_
(CO
-GEN
)
540
MW
BPK_
CC#
3_(R
ETIR
E)
-31
4 M
W;
NEW
_CAP
ACIT
Y 80
0 M
W;
EGAT
_CO
AL#
3-4
2
x700
MW
; IM
PORT_
POW
ER
45
0 M
W;
BPK_
CC#
4_(R
ETIR
E)
-31
4 M
W;
NPO
_CC#
1_(R
ETIR
E)
-32
5 M
W;
SOU
TH B
ANG
KOK
CC#
4-5
2x
800
MW
;
NPO
_CC#
2_(R
ETIR
E)
-32
5 M
W;
SB_C
C#1_
(RET
IRE)
-
316
MW
; EG
AT_N
UCL
EAR#
1 10
00 M
W;
PO
WER
DEV
ELO
PM
ENT
PLA
NTh
aila
nd P
DP2
007
: Re
visi
on 2
GEN
ERAT
ION
SYS
TEM
DEV
ELO
PMEN
T PL
ANN
ING
DEP
ARTM
ENT
LOAD
FO
RECA
ST :
Dec
embe
r 20
08SY
STEM
PLA
NN
ING
DIV
ISIO
NRU
N D
ATE
: M
arch
24,
200
9EL
ECTR
ICIT
Y G
ENER
ATIN
G A
UTH
ORI
TY O
F TH
AILA
ND
PEA
K A
ND
CA
PA
CIT
Y (
MW
)M
W29
,139
.5EX
ISTI
NG
CA
PA
CIT
Y10
000
2000
030
000
4000
050
000
6000
070
000
8000
090
000
1000
00
JAN
2009
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
JAN
2010
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
JAN
2011
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
JAN
2012
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
JAN
2013
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
JAN
2014
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
JAN
2015
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
JAN
2016
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
JAN
2017
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
JAN
2018
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
JAN
2019
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
JAN
2020
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
JAN
2021
FEB
MA
RA
PR
MA
YJU
NJU
LA
UG
SEP
OC
TN
OV
DEC
1000
020
000
3000
040
000
5000
060
000
7000
080
000
9000
010
0000
FIGURE 4.1 THAILAND POWER DEVELOPMENT PLAN (PDP 2007 : REVISION 2)
-1,3
41.6
SPP_
(REN
EW)
10
MW
; SO
UTH
_BAN
GKO
K_CC
#3
71
0 M
W72
0.0
BAN
G_P
AKO
NG
_CC#
5 71
0 M
W71
0.0
IMPO
RT_
FRO
M_L
AOS_
(NT2
)
920
MW
920.
0CH
AO P
HRAY
A D
AM#
1 6
MW
; SO
LAR
(1)
MW
; W
IND
(
2) M
W6.
0
PEAK
GEN
ERAT
ION
22,8
86.0
0M
W
MIN
IMU
M R
ESER
VE M
ARG
IN22
.44
%
ADD
ITIO
NAL
CAP
ACIT
Y2,
378.
50M
W
RET
IRED
CAP
ACIT
Y-1
,364
.10
MW
NET
CAP
ACIT
Y IN
YEA
R1,
014.
40M
W
TOTA
L CA
PACI
TY30
,153
.91
MW
VSPP
1
0 M
W10
.0
CHAO
PH
RAY
A D
AM#
2 6
MW
6.0
NO
RTH
_BAN
GKO
K_CC
#1
67
0 M
W67
0.0
MEA
KLO
NG
DAM
#1
6
MW
6.0
PASA
K JO
LASI
D D
AM
6.7
MW
6.7
SPP_
(CO
-GEN
)
90 M
W;
KHU
N D
AN P
RAK
ARN
CHO
N D
AM
10
MW
100.
0M
EA K
LON
G D
AM#
2 6
MW
6.0
PEAK
GEN
ERAT
ION
23,9
36.0
0M
W
MIN
IMU
M R
ESER
VE M
ARG
IN23
.97
%
ADD
ITIO
NAL
CAP
ACIT
Y80
4.70
MW
RET
IRED
CAP
ACIT
Y0.
00M
W
NET
CAP
ACIT
Y IN
YEA
R80
4.70
MW
TOTA
L CA
PACI
TY30
,958
.61
MW
IMPO
RT_
FRO
M_L
AOS_
(NN
G2)
5
96.6
MW
; KW
AE N
OI
DAM
#1
15
MW
; VS
PP
48
MW
659.
6N
ARES
UAN
DAM
8
MW
8.0
KWAE
NO
I D
AM#
2 15
MW
15.0
PPB_
TH#
1_(P
PA_E
ND
)
-69.
9 M
W-6
9.9
GH
ECO
-ON
E 66
0 M
W66
0.0
PEAK
GEN
ERAT
ION
25,0
85.0
0M
W
MIN
IMU
M R
ESER
VE M
ARG
IN23
.66
%
ADD
ITIO
NAL
CAP
ACIT
Y1,
592.
60M
W
RET
IRED
CAP
ACIT
Y-6
9.90
MW
NET
CAP
ACIT
Y IN
YEA
R1,
522.
70M
W
TOTA
L CA
PACI
TY32
,481
.31
MW
VSPP
5
0 M
W;
SPP_
(REN
EW)
65
MW
115.
0
IMPO
RT_
FRO
M_L
AOS_
(TH
B_EX
T)
220
MW
220.
0PE
AK G
ENER
ATIO
N26
,572
.00
MW
MIN
IMU
M R
ESER
VE M
ARG
IN20
.34
%
ADD
ITIO
NAL
CAP
ACIT
Y1,
259.
00M
W
RET
IRED
CAP
ACIT
Y0.
00M
W
NET
CAP
ACIT
Y IN
YEA
R1,
259.
00M
W
TOTA
L CA
PACI
TY33
,740
.31
MW
VSPP
5
0 M
W50
.0
SIAM
_EN
ERG
Y_#
1 80
0 M
W80
0.0
540.
0
SIAM
_EN
ERG
Y_#
2 80
0 M
W80
0.0
NAT
ION
AL_P
OW
ER_S
UPP
LY_#
1-2
2x
135
MW
270.
0
PEAK
GEN
ERAT
ION
28,1
88.0
0M
W
MIN
IMU
M R
ESER
VE M
ARG
IN20
.43
%
ADD
ITIO
NAL
CAP
ACIT
Y2,
460.
00M
W
RET
IRED
CAP
ACIT
Y0.
00M
W
NET
CAP
ACIT
Y IN
YEA
R2,
460.
00M
W
TOTA
L CA
PACI
TY36
,200
.31
MW
BPK_
TH#
1-2_
(RET
IRE)
-
525.
5,-5
26.5
MW
; VS
PP
50
MW
-1,0
02.0
NAT
ION
AL_P
OW
ER_S
UPP
LY_#
3-4
2x
135
MW
270.
0
WAN
G_N
OI_
CC#
4
800
MW
; PO
WER
_GEN
_SU
PPLY
_#1
80
0 M
W;
SPP_
(CO
-GEN
) 90
MW
1,69
0.0
CHAN
A_CC
#2
80
0 M
W80
0.0
POW
ER_G
EN_S
UPP
LY_#
2 80
0 M
W80
0.0
PEAK
GEN
ERAT
ION
29,8
71.0
0M
W
MIN
IMU
M R
ESER
VE M
ARG
IN16
.59
%
ADD
ITIO
NAL
CAP
ACIT
Y3,
610.
00M
W
RET
IRED
CAP
ACIT
Y-1
,052
.00
MW
NET
CAP
ACIT
Y IN
YEA
R2,
558.
00M
W
TOTA
L CA
PACI
TY38
,758
.31
MW
RY_
CC#
1-4_
(PPA
_EN
D)
-1
175.
1 M
W;
VSPP
5
0 M
W-1
,125
.1
IMPO
RT_
POW
ER
45
0 M
W45
0.0
PEAK
GEN
ERAT
ION
31,7
34.0
0M
W
MIN
IMU
M R
ESER
VE M
ARG
IN16
.57
%
ADD
ITIO
NAL
CAP
ACIT
Y50
0.00
MW
RET
IRED
CAP
ACIT
Y-1
,175
.10
MW
NET
CAP
ACIT
Y IN
YEA
R-6
75.1
0M
W
TOTA
L CA
PACI
TY38
,083
.21
MW
EGAT
_CO
AL#
1-2
2
x700
MW
; VS
PP
50
MW
1,45
0.0
IMPO
RT_
POW
ER
45
0 M
W45
0.0
PPB_
TH#
2_(P
PA_E
ND
)
-70.
2 M
W-7
0.2
KN_C
C_(P
PA_E
ND
)
-678
MW
; N
EW_C
APAC
ITY_
SOU
THER
N
800
MW
122.
0PE
AK G
ENER
ATIO
N33
,673
.00
MW
MIN
IMU
M R
ESER
VE M
ARG
IN16
.64
%
ADD
ITIO
NAL
CAP
ACIT
Y2,
700.
00M
W
RET
IRED
CAP
ACIT
Y-7
48.2
0M
W
NET
CAP
ACIT
Y IN
YEA
R1,
951.
80M
W
TOTA
L CA
PACI
TY40
,035
.01
MW
VSPP
5
0 M
W2,
386.
0
GLO
W_E
NER
GY#
1_(P
PA_E
ND
) -9
0 M
W-9
0.0
GLO
W_E
NER
GY#
2_(P
PA_E
ND
) -9
0 M
W-9
0.0
PEAK
GEN
ERAT
ION
35,6
68.0
0M
W
MIN
IMU
M R
ESER
VE M
ARG
IN16
.61
%
ADD
ITIO
NAL
CAP
ACIT
Y2,
700.
00M
W
RET
IRED
CAP
ACIT
Y-4
94.0
0M
W
NET
CAP
ACIT
Y IN
YEA
R2,
206.
00M
W
TOTA
L CA
PACI
TY42
,241
.01
MW
BAN
G P
AKO
NG
CC#
6 80
0 M
W;
IMPO
RT
POW
ER
450
MW
; VS
PP
50
MW
2,26
1.0
TPT_
UTI
LITY
_(PP
A_EN
D)
-1
0 M
W-1
0.0
PTT_
CHEM
ICAL
_(PP
A_EN
D)
-3
2 M
W-3
2.0
PEAK
GEN
ERAT
ION
37,7
25.0
0M
W
MIN
IMU
M R
ESER
VE M
ARG
IN15
.81
%
ADD
ITIO
NAL
CAP
ACIT
Y2,
900.
00M
W
RET
IRED
CAP
ACIT
Y-6
81.0
0M
W
NET
CAP
ACIT
Y IN
YEA
R2,
219.
00M
W
TOTA
L CA
PACI
TY44
,460
.01
MW
NO
RTH
BAN
GKO
K CC
#2
80
0 M
W;
NEW
_CAP
ACIT
Y
2x80
0 M
W;
IMPO
RT_
POW
ER
50
0 M
W;
VSPP
5
0 M
W2,
950.
0
MIL
ITAR
Y_FA
NG
_(PP
A_EN
D)
-9
MW
-9.0
GU
LF_C
OG
ENER
ATIO
N_(
PPA_
END
) -9
0 M
W;
AMAT
A_EG
CO_P
OW
ER_(
PPA_
END
) -9
0 M
W-1
80.0
PEAK
GEN
ERAT
ION
39,8
28.0
0M
W
MIN
IMU
M R
ESER
VE M
ARG
IN17
.01
%
ADD
ITIO
NAL
CAP
ACIT
Y2,
950.
00M
W
RET
IRED
CAP
ACIT
Y-1
89.0
0M
W
NET
CAP
ACIT
Y IN
YEA
R2,
761.
00M
W
TOTA
L CA
PACI
TY47
,221
.01
MW
NEW
_CAP
ACIT
Y_IP
P 2x
800
MW
; IM
PORT_
POW
ER
50
0 M
W;
VSPP
5
0 M
W2,
509.
0BA
NG
KOK_
COG
EN_(
PPA_
END
) -9
0 M
W-9
0.0
BPK_
POW
ER_S
UPP
LY_(
PPA_
END
)
-8 M
W-8
.0TE
CO_(
PPA_
END
) -7
00 M
W-7
00.0
SAM
UTP
RAK
ARN
_CO
GEN
_(PP
A_EN
D)
-9
0 M
W-9
0.0
PEAK
GEN
ERAT
ION
42,0
24.0
0M
W
MIN
IMU
M R
ESER
VE M
ARG
IN16
.12
%
ADD
ITIO
NAL
CAP
ACIT
Y3,
150.
00M
W
RET
IRED
CAP
ACIT
Y-1
,529
.00
MW
NET
CAP
ACIT
Y IN
YEA
R1,
621.
00M
W
TOTA
L CA
PACI
TY48
,842
.01
MW
EGAT
_NU
CLEA
R#
2 10
00 M
W;
NEW
_CAP
ACIT
Y
2x80
0 M
W;
IMPO
RT_
POW
ER
50
0 M
W;
VSPP
5
0 M
W3,
150.
0G
LOW
_SPP
#1_
PRO
J_1_
(PPA
_EN
D)
-5
5 M
W-5
5.0
GLO
W_S
PP#
1_PR
OJ_
2_(P
PA_E
ND
) -5
5 M
W-5
5.0
NO
NG
_KH
AE_C
OG
EN_(
PPA_
END
)
-90
MW
-90.
0
PEAK
GEN
ERAT
ION
44,2
81.0
0M
W
MIN
IMU
M R
ESER
VE M
ARG
IN15
.31
%
ADD
ITIO
NAL
CAP
ACIT
Y3,
150.
00M
W
RET
IRED
CAP
ACIT
Y-2
00.0
0M
W
NET
CAP
ACIT
Y IN
YEA
R2,
950.
00M
W
TOTA
L CA
PACI
TY51
,792
.01
MW
PEAK
GEN
ERAT
ION
PEAK
GEN
ERAT
ION
+ 1
5%
DEP
END
ABLE
CAP
ACIT
Y
INST
ALLE
D C
APAC
ITY
NO
NG
_CH
OK_
GT#
1-3_
(RET
IRE)
-3
x117
MW
; SU
RAT
_TH
ANI_
GT#
1-2_
(RET
IRE)
-2
x117
MW
; SB
_TH
#4-
5_(R
ETIR
E)
-5
59 M
W;
LKB_
GT#
1-11
_(RET
IRE)
-
220.
1 M
W;
SPP_
(DAN
_CH
ANG
_BIO
)
10 M
W;
SPP_
(DEJ
A_BI
O_G
REE
N)
6.
5 M
W;
VSPP
6
MW
SPP_
(REN
EW)
25
0 M
W25
0.0
SPP_
(CO
-GEN
) 9
24 M
W
924.
0
SPP_
(CO
-GEN
)
540
MW
BPK_
CC#
3_(R
ETIR
E)
-31
4 M
W;
NEW
_CAP
ACIT
Y 80
0 M
W;
EGAT
_CO
AL#
3-4
2
x700
MW
; IM
PORT_
POW
ER
45
0 M
W;
BPK_
CC#
4_(R
ETIR
E)
-31
4 M
W;
NPO
_CC#
1_(R
ETIR
E)
-32
5 M
W;
SOU
TH B
ANG
KOK
CC#
4-5
2x
800
MW
;
NPO
_CC#
2_(R
ETIR
E)
-32
5 M
W;
SB_C
C#1_
(RET
IRE)
-
316
MW
; EG
AT_N
UCL
EAR#
1 10
00 M
W;
26
27
4.5 EGAT Renewable Energy
The renewable energy projects of EGAT with the total capacity of 81.7 MW
was concurred by the Committee on Energy Policy Administration (CEPA) on 20
November 2006 and was approved by the National Energy Policy Committee (NEPC) on 4
December 2006. The approved EGAT renewable energy projects comprised as following
and the details are given in Appendix 6.
- Small Hydropower Plants 78.7 MW
- Solar Energy Power Plant 1.0 MW
- Wind Energy Power Plants 2.0 MW
81.7 MW
4.6 Coal Supply Plan for 4 EGAT’s Coal-fired Power Plants
EGAT has prepared the procurement of high quality imported coal by
contacting with the potential coal producers in Indonesia, Vietnam and Australia for the
supply of high quality coal throughout the power plant lives.
28
5. Project Descriptions
The description of projects in the PDP 2007: Revision 2 for the commissioning
during 2009-2015 can be described as follows:
5.1 500 kV Transmission System Development for Power Purchase
from Nam Theun 2 Hydroelectric Project
The scope of work for the transmission line portion in Thailand comprises the
construction of 500 kV double circuit lines from Roi Et 2 substation to Thailand/Lao PDR
Border in Mukdaharn province, a distance of approximately 166 km, for the power
purchase from the Nam Theun 2 Hydroelectric Project with the installed capacity of 920
MW and commercial operation date in 2009.
The project was approved by the Cabinet on 23 November 2004.
5.2 Bulk Power Supply for the Greater Bangkok Area Phase 2
The Bulk Power supply for the Greater Bangkok Area Phase 2 (BSB2) is a
successive project of the phase 1 project by constructing new 230 kV terminal substations
to supply to Metropolitan Electricity Authority (MEA) to cope with the increasing demand
of the metropolitan area. The project consists of the construction and upgrade of the
existing transmission facilities as well as the conversion of existing lines from 230 kV to
500 kV voltage levels, which will supply the electricity in the Greater Bangkok Area with
a high stability and reliability. The scope of reinforcement of EGAT’s transmission system
was designed to effectively support the expansion of MEA’s long-term distribution system
reinforcement plan and scheduled to complete during 2009 - 2011.
The project was approved by the cabinet on 8 August 2006.
5.3 Renovation of Aging Hydropower Project
As the turbine-generator of small hydropower projects including Ubol Ratana,
Sirindhorn, Chulabhorn, Nam Pung and Kaeng Krachan were operated for long time and
run over their ages, they need refurbishment to extend their service lives, maintain
operational efficiency and availability while reducing maintenance cost in the long run
while the associated dams are still serviceable with the following consideration:
− Improve and increase efficiency
− Lower cost compared with new power plant
29
− To be completed during 2008 - 2010
The project was approved by the Cabinet on 4 January 2005.
5.4 South Bangkok Combined Cycle Power Plant Block 3 Project
The project is one of EGAT new natural gas-fried combined cycle power plants
which site is the compound of the existing South Bangkok Power Plant in Samut Prakan
Province, outskirt of Bangkok. The project description is:
− Base load power plant
− Contracted capacity is 710 MW
− Fuel is natural gas
− To be completed in March 2009
− The project was approved by the Cabinet on 25 October 2005
5.5 Bang Pakong Combined Cycle Power Plant Block 5 Project
The project is one of EGAT new natural gas-fried combined cycle power plants
which site is the compound of the existing Bang Pakong Power Plant, Chachoengsao
Province. The project description is:
− Base load power plant
− Contracted capacity is 710 MW
− Fuel is natural gas
− To be completed in July 2009
− The project was approved by the Cabinet on 25 July 2006
5.6 North Bangkok Combined Cycle Power Plant Block 1 Project
The project is one of EGAT new natural gas-fried combined cycle power plants
which is constructed at the existing site of North Bangkok Power Plant at Bang Kruai
Subdistrict, Nonthaburi Province.
− Base load power plant
− Contracted capacity is 670 MW
− Fuel is natural gas
− To be completed in May 2010
− The project was approved by the Cabinet on 12 December 2006
30
5.7 500 kV Transmission System Project for Power Purchase from Nam Ngum
2 Hydroelectric Power Project
The project is the construction of 500 kV double circuit transmission line
portion in Thailand from Udon Thani 3 substation to Thailand-Lao PDR Border, a distance
of approximately 80 km but initially energized at 230 kV to purchase power of 597 MW
from the Nam Ngum 2 Hydroelectric Project, which is scheduled to be completed by 2010.
The Project was approved by the Cabinet on 22 August 2006.
5.8 500 kV Transmission System Projects to Purchase Power from Private
Power Plants
The project is the construction of 500 kV transmission line from Pluak Daeng
substation to Nong Chok connection and to Wang Noi substation, the 3rd and 4th circuit (2nd
line) to reinforce the main transmission system and support power purchase from private
power producers that strengthen the stability and reliability of the power system. The
project is scheduled to complete in 2011.
5.9 Transmission System Expansion Projects No.11
The project includes the expansion and improvement of the transmission system
in provincial area to cope with increasing demand nationwide except the Greater Bangkok
Area and to maintain reliability of power supply. The project, continued from the
Transmission System Expansion Projects No.10 (TS10), will assist the Provincial
Electricity Authority (PEA) to effectively expand distribution system to the required area.
The project is scheduled to complete during 2010-2011.
The project was approved by the Cabinet on 2 October 2007.
5.10 Transmission System Expansion Projects No. 12 - 14
The projects include the expansion and improvement of the transmission system
in provincial area to cope with increasing demand nationwide except the Greater Bangkok
Area and to maintain reliability of power supply. The projects, continued from the
Transmission System Expansion Projects No.11 (TS11), will assist the Provincial
Electricity Authority (PEA) to effectively expand distribution system to the required area.
The expected completion dates of the projects are:
31
Projects Commissioning Date TS. 12 2012–2013
TS. 13 2014–2015
TS. 14 2016–2017
5.11 Transmission System Development for Power Purchase from Theun
Hinboun Expansion Project
The project is the transmission system in Thailand with the construction of new
Nakon Panom 2 substation with replacing new 230 kV transmission line from Thailand-
Lao PDR border in Nakon Panom province to the Nakon Panom 2 substation and
constructing additional 230 kV and 115 kV transmission lines for 440 MW power purchase
from the existing and expansion Theun Hinboun hydroelectric power project. The project
is scheduled to complete in 2012.
5.12 Transmission System Projects to Purchases Power from Independent
Power Producers (IPP)
The project is the transmission system to purchase power from the Independent
Power Producers (IPP), as referred to the PDP 2007: Revision 1 including 4 awarded IPPs,
Gheco-One, Siam Energy, National Power Supply and Power Generation Supply, with the
total capacity of 4,400 MW and Commercial Operation Date (COD) during 2011 – 2013.
the transmission project will connect the IPP projects to EGAT power system and is
scheduled to complete during 2011-2013.
5.13 500 kV Transmission System to Supply Upper Northern System Project
The project is 500 kV double circuit transmission line construction from the
new Mae Moh 5 substation to Chieng Mai province with a distance of approximately 145
km to cope with the increasing demand of the upper part of Northern Region of Thailand,
in Chieng Mai and Lampun, as well as to enhance the system stability and reliability in the
area. The project is scheduled to complete by 2018.
32
5.14 EGAT New Power Project (2012-2015)
The new generating capacities to be developed by EGAT are as follows:
COD Power Plant Capacity (MW)
June 2014 Wang Noi CC Power Plant Block 4 800
July 2014 Chana CC Power Plant Block 2 800
33
6. Nuclear Power Plant
6.1 The Need for Nuclear Power Plants in Thailand
Electricity is one of the vital infrastructures for living, business and industry to
enhance the competitiveness of the country. The present energy situation indicates
inconsistent tendency so that the consideration of long term power development plan has to
deal with various factors as well as respond to the national energy policy. As possible
alternative of power generation in Thailand is limited, nuclear power plant becomes an
attractive alternative for the consideration of long term power development plan.
Advantages: Nuclear power plant has many advantages as it is a large-scale
power plant with high power stability as well as its security of fuel supply because the plant
can operate up to 18 months for each fuel refill and there is abundance of naturally occurring
uranium to be used as nuclear fuel. Furthermore, the nuclear power plant is clean with no
emission of green house gas to pollute environment while the plant is reliable and high
efficiency with lower rate of fuel consumption than other types of power plant while its low
fuel cost could give low tariff.
Disadvantages: Nuclear power plant requires high investment cost with the risk of
accident that could cause danger from radiation leakage. Furthermore, the nuclear power plant
is difficult to achieve public acceptance so that an appropriate preparation for safety and
effective implementation is necessary.
At present, there are 438 nuclear power plants in operation in 30 countries
worldwide, most of which are in USA and Europe, and 18 plants under construction. In
Thailand, the development of nuclear power plant as an alternative power source is necessary
due to the following reason.
− Supply increasing power demand
− Strengthen the stability of national power and energy system
− Increase efficiency and reliability in power generation
− Avoid risk on fuel price
− Respond to the need of clean energy
34
6.1.1 Supply Increasing Power Demand
Thailand is a developing country with increasing population, improving social
living standard and growing economic, although there are still impacts from the present global
economic recession. These situations cause the national power demand increase every year.
According to the power demand forecast during 2008 – 2021, the annual power demand
growth will be approximate 4.9 % or 1,589 MW so that the power demand of the next 13
years, in 2021, will increase twice that in 2008. Therefore, EGAT is necessary to provide
sufficient power supply in which the nuclear power plant is an appropriate alternative in
responding the future power demand of the country.
6.1.2 Strengthen Stability of National Power and Energy System
As the fossil fuel has limited reserve, especially the natural gas in the Gulf of
Thailand will run out in the near future. The present power generation in Thailand mostly
depends on the natural gas with 79 % of total fuel consumption. However, the power
generation, in actual, should not rely on sole fuel but it should be diversified to various fuel to
avoid the risk of fuel security as well as to strengthen the stability of the national power
system. The base load power plant which is required for the stability of power system should
be an effective, stable and sufficiently durable plant with less possibility to trip from the
system. Since the nuclear power plant is considered to be effective, stable, durable and
capable for continuously long term operation, it is appropriate as the base load power plant to
enhance the security the power system.
6.1.3 Increase Efficiency and Reliability in Power Generation
The nuclear power plant utilizes very small fuel consumption. It is therefore an
effective power plant as its power generation per fuel consumption is only 1 kg of Uranium to
produce the energy of 50,000 kWh while 1 kg of coal and natural gas can produce the energy
of only 3 and 4 kWh respectively. Moreover, the nuclear power plant is a large scale power
plant and capable for continuously long term operation with more than 80 % capacity factor
allowing base load operation and higher reliability than smaller power plants.
6.1.4 Avoid Risk on Fuel Price
According to the global fuel crisis situation which tends to be shortage, the
uncertainty of fossil fuel price leads to risk on the consumers. In order to mitigate the risk,
35
other fuel should be taken into account. Uranium is a low cost and insensitive pricing fuel
which price does not depend on oil therefore it is an applicable alternative fuel to avoid risk
on fuel price.
6.1.5 Respond to Need of Clean Energy
The nuclear power plant uses Uranium as fuel therefore it will not emit the
polluted Green House Gases such as NOx, SO2 and CO2, which have impacts to environment,
like the power generation from fossil fuel. At present, all over the world is facing the global
warming problem and Thailand also concerns this problem. The nuclear power plant is then
an alternative of power generation in Thailand to help the global warming situation.
6.2 Nuclear Power Plant in PDP 2007 Revision 2
As the Cooperation Committee for Nuclear Power Infrastructure Establishment
informed that the nuclear power project can be proceeded as planned but the capacity was
reduced to 1,000 MW per year that is 1,000 MW in 2020 and another 1,000 MW in 2021. The
PDP 2007 Revision 2 indicates the nuclear power plants of 1,000 MW per year as base load
plant in the system since 2020.
In order to govern the preparation of the nuclear power plant implementation to
keep on plan, the Government has approved the final plan of Infrastructure Implementation
for Nuclear Power Generation by establishing the Office of Nuclear Power Project
Development under the Ministry of Energy to coordinate and activate the mentioned
infrastructure implementation plan.
The first 3 years, 2008 – 2010, is the preparation phase before the decision making
by the government and public to proceed the nuclear power project in early 2011. The
preparation phase comprises 6 following activities.
1. Legal, regulation and binding among countries
2. Safety and environmental protection
3. Industrial and commercial infrastructure
4. Human resources development and technology transfer
5. Public relation and stakeholder involvement
6. Nuclear power project implementation planning
36
Currently, EGAT has engaged with Burns and Roe Asia Co., Ltd., the consultant
on the preparation of nuclear power plant development in the budget of 174 Million Baht for
study period of 20 months from October 1, 2008 and such consultant was designated by the
coordination subcommittee of nuclear power project implementation planning to perform the
feasibility study of the project including selection of technology and project site, initial
environmental examination, economic and financial study, as well as human resource
development planning which will be concluded within 2010 and proposed to the Government
for further decision making.
The nuclear power plant will support the security in providing fuel for power
generation in the future and maintain the stability of energy price while support the policy to
diversify various energy resources. Furthermore, the nuclear power plant is also the clean
power plant without the emission of Carbon Dioxide to help the global warming problem.
37
7. Power Purchasing from Private Power Companies and Neighboring
Countries
7.1 Independent Power Producers (IPPs)
Independent Power Producers (IPPs) are the large scale private power
producers participating in the electricity supply industry by selling the generated power to
EGAT. The fuel used in the IPPs could be natural gas, coal or heavy oil. At present,
EGAT has the Power Purchase Agreement (PPA) with 7 IPPs from the first round of IPP
solicitation with the total capacity of 6,677.5 MW. The capacities of these IPPs range from
350 MW to 1,400 MW in which the 7 IPPs have commercially generated power to the
system including Tri Energy Co., Ltd., Independent Power Producer (Thailand) Co., Ltd.,
Glow IPP CO., Ltd., Eastern Power & Electric CO., Ltd., BLCP Power Co., Ltd., Gulf
Power Generation Co., Ltd. and Ratchaburi Power Co., Ltd. In addition, EGAT subsidiary
companies, Electricity Generating Public Co., Ltd. (EGCO) and Ratchaburi Holding Public
Co., Ltd. (RATCH) have also commercially generated power to the system.
Later, on 27th June 2007, the Ministry of Energy (by Energy Policy and
Planning Office, EPPO) and the IPP Power Purchase Proposal Evaluation and Selection
Subcommittee announced the second solicitation for proposals from independent power
producers for the supply of power to EGAT during 2011 to 2014 with the total capacity of
3,200 MW which Commercial Operation Date (COD) is 2012 for 800 MW, 2013 for 800
MW and 2014 for 1,600 MW.
After the deadline of bidding proposal on 19th October 2007, there are 20
qualified bid proposals with the total capacity of 17,407 MW in which 14 proposals of
13,807 MW are gas-fired power plants and another 6 proposals of 3,600 MW are coal-fired
power plants.
According to the evaluation of the lowest levelized unit price of each bidder by
the Subcommittee, 4 successful bidders were selected and, in the PDP 2007 Revision 2,
they have been negotiated to postpone their COD in order to maintain reserve margin at an
appropriate level corresponding to the present situation. Resulting from the negotiation, 2
38
IPPs agreed to postpone their COD for one year with no impact on previously proposed
tariff. The 4 IPPs comprise:
Project
Companies
Fuel Types Proposed Capacity
(MW)
Scheduled Commercial Operation Date (SCOD)
1 GHECO-One Coal 660 November 2011
3 Siam Energy Natural Gas 1,600 March - September 2013
2 National Power Supply (NPS)
Coal 540 November 2013 – March 2014
4 Power Generation Supply Natural Gas 1,600 June – December 2014
Total 4,400
7.2 Small Power Producers (SPPs)
Small Power Producers (SPPs) are the private power producers selling the
generated power to EGAT with the capacity between 10 MW and 90 MW. The generation
technology of the SPPs are cogeneration which fuel is mainly natural gas and coal, and
renewable energy, such as biomass, waste, biogas, solar and wind, which could enhance
the efficiency in the energy utilization of the country. As of December 2008, there are 90
SPPs of 4,203 MW in which 64 SPPs of 3,839.6 MW have firm contract while another 26
SPPs of 363.4 MW have non-firm contract. 60 SPPs of 2,285.5 MW have generated power
in the system in which 41 SPPs of 2,079.1 MW have firm contract while another 19 SPPs
of 206.4 MW have non-firm contract. Besides, another 30 SPPs of 1,917.5 MW have not
yet generated power in the system in which 23 SPPs of 1,760.5 MW have firm contract
while another 7 SPPs of 157 MW have non-firm contract.
7.3 Very Small Power Producers (VSPPs)
Very Small Power Producers (VSPPs) are the private power producers selling
the generated power to EGAT with the capacity lower than 10 MW. The generation
technology of the VSPPs are cogeneration which fuel is mainly natural gas and coal, and
renewable energy, such as biomass, waste, biogas, solar and wind. At the end of 2008, it
was expected to supply 235 MW to the peak load and further expected that the VSPPs
proposed to MEA and PEA could supply power of 499 MW and 700 MW to the peak load
in 2015 and 2021 respectively.
39
7.4 Power Purchase from Lao PDR
The Government of Thailand and Lao PDR have entered into several
Memorandums of Understanding (MOU) to promote the cooperation in developing power
generation projects in Lao PDR as follows:
− 4 June 1993 purchase power up to 1,500 MW
− 19 June 1996 extending power purchase to 3,000 MW
− 18 December 2006 extending power purchase to 5,000 MW
− 22 December 2007 extending power purchase to 7,000 MW
At present, the 214 MW Theun Hinboun and 126 MW Houay Ho projects have
signed the Power Purchase Agreement (PPA) and are in operation. The projects with PPA
and under construction are the 920 MW Nam Theun 2, 597 MW Nam Ngum 2 and 220
MW Theun Hinboun – Expansion. Moreover, there are many projects which had early
signed tariff MOU but some MOU have expired while some projects have terminated
MOU due to increasing project cost so that the projects could not proceed. These projects
require further cooperation and negotiation with the Lao Government and project
developers as follows:
1. Nam Theun 1 523 MW
2. Nam Ngum 3 440 MW
3. Nam Ngiep 261 MW
4. Nam Ou 1,043 MW
5. Hong Sa 1,470 MW
7.5 Power Purchase from the Union of Myanmar
The governments of Thailand and the Union of Myanmar have entered into the
Memorandum of Understanding (MOU) on the power purchase from the Union of
Myanmar on 4th July 1997. According to the MOU, Thailand will cooperate with the
Union of Myanmar to encourage the purchase of power up to 1,500 MW. Later on 30 May
2005, the Ministry of Energy of Thailand and the Ministry of Electric Power (1) of the
Union of Myanmar signed additional MOU on the Cooperation in the Development of
Hydropower Projects on the Thanlwin and Tanintharyi River in which 2 projects on the
Thanlwin River were proposed to sell power to Thailand as following.
40
1. Hutgyi Hydropower Project 1,190 MW expected to connect to Thailand at
Tha Song Yang district, Tak province
2. Tasang Hydropower Project 7,000 MW expected to connect to Thailand at
Mae Eye district, Chieng Mai province
7.6 Power Purchase from the People Republic of China
The Government of Thailand entered into a Memorandum of Understanding
(MOU) with the Government of People’s Republic of China (PRC) on 12 November 1998
as the intention that the Government of Thailand agreed to purchase power of 3,000 MW
within 2017. PRC will propose feasible projects to Thailand and both parties agreed to
cooperate in planning and construction of transmission system between the two countries
as well as the negotiation with Lao PDR on the issues relating to the right-of-way of the
transmission line passing through the territory of Lao PDR.
7.7 Power Purchase from Cambodia
The Governments of Thailand and Cambodia has no Memorandum of
Understanding (MOU) on power cooperation. However, private agencies have developed
project in Cambodia and proposed to sell power to Thailand such as Koh Kong power
project which is a proposed 3,600 MW coal fired power plant separated into two phases
each of 1,800 MW.
41
Appendices
42
43
Appendix 1
Comparison of Thailand Power Development Plans
44
COMPARISION BETWEEN THAILAND PDP 2007 : Revision 1 AND PDP 2007: Revision 2
( 2009 - 2021 )
PDP 2007 : Revision 1 PDP 2007 : Revision 2
Power Plants MW Power Plants MW2009 VSPP (Jan.) 6
SPPs (Jan.) 88 SPP (Renew) (Jan.) 16.5
CHP of South Bangkok CC # 2 (Jan.) 74 SPP (Renew) (Mar.) 10
South Bangkok CC # 3 (Mar.) 715 South Bangkok CC # 3 (Mar.) 710
Bang Pakong CC # 5 (Mar.) 715 Bang Pakong CC # 5 (Jul.) 710
Power purchased from Lao PDR (Nam Theun 2) (Nov.) 920 Power purchased from Lao PDR (Nam Theun 2) (Nov.) 920
Small hydro Power (RPS) (Mar., Aug., Sep., Dec.) 45.7 Chao Phraya Dam # 1 (Dec.) 6
Wind energy and Solar energy (Dec.) (3)
2010 VSPP (Jan.) 10
SPPs (Jan.) 225 Chao Phraya Dam # 2 (Mar.) 6
CHP of Wang Noi CC # 1-3 (Jan.) 243 North Bangkok CC # 1 (May.) 670
Small hydro Power (RPS) (Jan., Apr.) 33 Mae Klong Dam # 1-2 (Aug.,Dec.) 2x6
North Bangkok CC # 1 (Mar.) 685 Pasak Jolasid Dam (Oct.) 6.7
Khun Dan Prakarnchon Dam (Nov.) 10
SPP (Co-Gen) (Nov.) 90
2011 VSPP (Jan.) 48
Power purchased from Loa PDR (Nam Ngum 2) (Jan.) 596.6 Power purchased from Lao PDR (Nam Ngum 2) (Jan.) 596.6
SPPs (Mar.) 25 Kwae Noi Dam # 1-2 (Jan., Apr.) 2x15
Gheco-one Co.,Ltd (Nov.) 660 Naresuan Dam (Feb.) 8
SPP (Renew) (Aug.) 250
Gheco-one Co.,Ltd (Nov.) 660
2012 VSPP (Jan.) 50
Wang Noi CC # 4 (Jan.) 700 SPP (Renew) (Jan.) 65
Power purchased from Loa PDR (Theun Hinboun – Expanded) (Mar.) 220 Power purchased from Lao PDR (Theun Hinbun-expanded) (Jul.) 220
Siam Energy Co., Ltd # 1-2 (Mar., Sep.) 2x800 SPP (Co-Gen) (Jun.) 924
National Power Supply Co., Ltd # 1-2 (Nov.) 2x135
SPPs (Mar.) 245
2013 VSPP (Jan.) 50
Bang Pakong CC # 6 (Jan.) 700 Siam Energy Co., Ltd # 1-2 (Mar.,Sep.) 2x800
Power purchased from Loa PDR (Nam Ngum 3) (Jan.) 440 SPP (Co-Gen) (Jun.) 540
National Power Supply Co., Ltd # 3-4 (Mar.) 2x135 National Power Supply Co., Ltd # 1-2 (Nov.) 2x135
Power purchased from Loa PDR (Hong Sa 1) (Mar.) 490
SPPs (Mar.) 200
Year
SPPs (Mar.) 200
2014 VSPP (Jan.) 50
Power purchased from Loa PDR (Hong Sa 2-3) (Jan.) 2x490 National Power Supply Co., Ltd # 3-4 (Mar.) 2x135
Power purchased from Loa PDR (Nam Theun 1) (Jan.) 523 Wang Noi CC # 4 (Jun.) 800
Power purchased from Loa PDR (Nam Ngiep) (Jan.) 261 SPP (Co-Gen) (Jun.) 90
Power Generation Supply Co., Ltd # 1-2 (Jun., Dec.) 2x800 Power Generation Supply Co., Ltd # 1-2 (Jun., Dec.) 2x800
Power purchased from Loa PDR (Nam Ou 1) (Mar.) 200 Chana CC # 2 (Jul.) 800
SPPs (Mar.) 200
2015 VSPP (Jan.) 50
Power purchased from Loa PDR (Nam Ou 2) (Jan.) 843 Power purchased from neighboring countries (Jun.) 450
Thermal power plant (Coal) _EGAT # 1 (Mar.) 700
SPPs (Mar.) 210
2016 VSPP (Jan.) 50
Thermal power plant (Coal) _EGAT # 2-3 (Jan.) 2x700 Thermal power plant (Coal)_EGAT # 1-2 (Jan.) 2x700
SPPs (Mar.) 200 Power purchased from neighboring countries (Mar.) 450
New power plant_South (Jul.) 800
2017 VSPP (Jan.) 50
New IPP power plant (Gasl/Coal) (Jan.) 700 Thermal power plant (Coal)_EGAT # 3-4 (Jan.) 2x700
South Bangkok CC #4-5 (Jan.) 2x700 New power plant (Jan.) 800
Power purchased from neighboring countries (Jan.) 510 Power purchased from neighboring countries (Jan.) 450
Thermal power plant (Coal) – EGAT #4 (Mar.) 700
SPPs (Mar.) 200
2018 VSPP (Jan.) 50
New IPP power plant (Gasl/Coal) (Jan.) 700 South Bangkok CC # 4-5 (Jan.) 2x800
Southern region CC - EGAT (Jan.) 700 Bang Pakong CC # 6 (Jan.) 800
Power purchased from neighboring countries (Jan.) 1780 Power purchased from neighboring countries (Jan.) 450
SPPs (Mar.) 175
2019 VSPP (Jan.) 50
North Bangkok CC #2 (Jan.) 700 North Bangkok CC # 2 (Jan.) 800
Power purchased from neighboring countries (Jan.) 2600 New power plant (Jan.) 2x800
Power purchased from neighboring countries (Jan.) 500
2020 VSPP (Jan.) 50
Thermal power plant (Nuclear) – EGAT #1-2 (Jan.) 2x1000 Thermal power plant (Nuclear)_EGAT # 1 (Jan.) 1000
Power purchased from neighboring countries (Jan.) 2600 New power plant _IPP (Jan.) 2x800
Power purchased from neighboring countries (Jan.) 500
2021 VSPP (Jan.) 50
Thermal power plant (Nuclear) – EGAT #3-4 (Jan.) 2x1000 Thermal power plant (Nuclear)_EGAT # 2 (Jan.) 1000
Power purchased from neighboring countries (Jan.) 1200 New power plant (Jan.) 2x800
Power purchased from neighboring countries (Jan.) 500p g g ( )
45
46
47
Appendix 2
Thailand Power System Map
48
50
51
Appendix 3
Installed Capacity of Thailand Power System
52
Hydroelectric PlantBhumibol - 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 - 1.275Mae Ngat - 9.0 Huai Kum - 1.06Rajjaprabha - 240.0 Pak Mun - 136.0 Lam Takhong PS. - 500.0 Small Hydro Power Plant - 0.445
3,424.180 11.75%Power Plant
South Bangkok Unit 3 Gas/Heavy oil 265.0 Unit 4 Gas/Heavy oil 294.0
South Bangkok Block 1 Gas 316.0 Block 2 Gas 562.0
1,437.0 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
2,832.0 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 10,034.0 34.43%
Gas Turbine Power Plant Lan Krabu Gas 220.1 Nong Chok Diesel 351.0 Surat Thani Diesel 234.0
805.1 2.76%Diesel
Mae Hong Son Diesel 4.4 4.4 0.02%
Renewable Energy SourceSubTotal 1.034 0.00%
14,268.7 48.97%Total Capacity of EGAT
Subtotal
Subtotal
Subtotal
Subtotal
Plant Type
CAPACITY OF THAILAND POWER SYSTEM(as of December 2008)
Subtotal
Subtotal
Subtotal
Subtotal
Subtotal
Subtotal
Capacity(MW)
Fuel Type
Subtotal
File : 01-Table_PDP2007Rev2_28Feb09_Eg
Purchased Power
Hydroelectric Plant
Theun Hinboun - 214.0
Houay Ho - 126.0
340.0 1.17%
Power Plant
Khanom PPB Unit 1 Gas/Heavy oil 69.9
Unit 2 Gas/Heavy oil 70.2
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 370.0
Heavy oil 9.0
Gas 1,293.0
1,672.0
13,823.6 47.44%
Renewable Energy Source
SPP Biomass 287.1 0.99%
Gas Turbine Power Plant
SPP Gas 120.0 0.41%
Others
EGAT-TNB Stag 2 - 300.0 1.03%
14,870.7 51.03%
29,139.4
Subtotal
Fuel Type
CAPACITY OF THAILAND POWER SYSTEM (Con.)(as of December 2008)
CapacityPlant Type
(MW)
Grand Total Capacity
Subtotal
Subtotal
Subtotal
Subtotal
Subtotal
Subtotal
Subtotal
Subtotal
Total Capacity of the Purchased
Subtotal
Subtotal
Subtotal
Subtotal
File : 01-Table_PDP2007Rev2_28Feb09_Eg
55
Appendix 4
Existing Transmission System
56
EXISTING TRANSMISSION LINES AND SUBSTATIONS OF EGAT POWER SYSTEM(as of December 2008)
Voltage Levels Substations Transmission LinesNumber Transformer Capacity
(kV) (MVA) (Circuit-kilometers)Metropolitan Area
500 2 4,050.0 411.1230 13 14,400.0 805.0115 - 25.0 -
Subtotal 15 18,475.0 1,216.2Central Region
500 5 6,000.0 1,881.6230 25 14,193.3 4,146.9115 42 5,242.3 2,618.669 - - 18.8
Subtotal 72 25,435.6 8,665.9Northeastern Region
500 1 2,000.0 -230 11 4,300.0 2,050.7115 37 3,938.0 5,286.0
Subtotal 49 10,238.0 7,336.7Southern Region
230 13 4,366.7 3,045.82/ 3/
1/
132 - 133.4 8.7115 18 2,379.0 2,769.2
300 (HVDC) - 388.0 23.0Subtotal 31 7,267.1 5,846.7
Northern Region500 2 3,800.0 1,139.7230 6 3,900.0 3,228.8115 34 2,959.5 2,784.8
Subtotal 40 10,659.5 7,153.3All Regions
500 10 15,850.0 3,432.4230 68 41,160.0 13,277.3132 - 133.4 8.7115 131 14,543.8 13,458.669 - - 18.8
300 (HVDC) - 388.0 23.0
Total 209 72,075.2 30,218.8Remark: 1/ Excluding generator transformers and station service transformers 2/ Sa Dao and Klong Ngea Substations are already included in the 115 kV and 230 kV Substations. 3/ The length of transmission lines from substation to Thailand - Malaysia border
Source: System Control and Operation Division
2/
2/
3/
3/
1/
58
59
Appendix 5
Power Demand Statistic and Load Forecast
60
TOTAL EGAT GENERATION REQUIREMENT December 2008 : Base Case
Peak Energy Load
Year Increase Increase FactorMW % GWh % %
Actual : Gross Generation2000 (2543) 14,918.30 1,205.90 8.79 98,536.85 7,105.23 7.77 75.19
2001 (2544) 16,126.40 1,208.10 8.10 103,868.65 5,331.80 5.41 73.53
2002 (2545) 16,681.10 554.70 3.44 111,299.74 7,431.09 7.15 76.17
2003 (2546) 18,121.40 1,440.30 8.63 118,378.22 7,078.48 6.36 74.57
2004 (2547) 19,325.80 1,204.40 6.65 127,457.04 9,078.82 7.67 75.08
2005 (2548) 20,537.50 1,211.70 6.27 134,826.98 7,369.94 5.78 74.94
2006 (2549) 21,064.00 526.50 2.56 142,004.67 7,177.69 5.32 76.96
2007 (2550) 22,586.10 1,522.10 7.23 146,925.50 4,920.83 3.47 74.26
Average Growth2000-2007 - 1,109.21 6.44 - 6,936.74 6.11 -
Forecast : NET Generation2008 (2551) 22,017 -19 -0.08 147,229 3,487 2.43 76.34
2009 (2552) 22,886 869 3.95 150,458 3,229 2.19 75.05
2010 (2553) 23,936 1,050 4.59 155,645 5,187 3.45 74.23
2011 (2554) 25,085 1,149 4.80 162,884 7,239 4.65 74.12
MW GWh
2012 (2555) 26,572 1,487 5.93 172,593 9,709 5.96 74.15
2013 (2556) 28,188 1,616 6.08 183,218 10,625 6.16 74.20
2014 (2557) 29,871 1,683 5.97 194,326 11,108 6.06 74.26
2015 (2558) 31,734 1,863 6.24 206,604 12,278 6.32 74.32
2016 (2559) 33,673 1,939 6.11 219,339 12,735 6.16 74.36
2017 (2560) 35,668 1,995 5.92 232,413 13,074 5.96 74.38
2018 (2561) 37,725 2,057 5.77 245,950 13,537 5.82 74.42
2019 (2562) 39,828 2,103 5.57 259,740 13,790 5.61 74.45
2020 (2563) 42,024 2,196 5.51 274,144 14,404 5.55 74.47
2021 (2564) 44,281 2,257 5.37 288,920 14,776 5.39 74.48
Average Growth1992-1996 - 1,053.18 10.60 - 7,413.68 11.60 -1997-2001 - 563.10 3.91 - 3,217.36 3.42 -2002-2007 - 1,076.62 5.78 - 7,176.14 5.95 -2008-2011 - 762.35 3.29 - 4,785.52 3.17 -2012-2016 - 1,717.60 6.07 - 11,291.00 6.13 -2017-2021 - 2,121.60 5.63 - 13,916.20 5.67 -2008-2021 - 1,588.96 4.93 - 10,369.86 4.95 -
Note 8 January 2009
- The growth rate in 2008 is calculated by the 2007 actual Net Generation.- From 2008 onward, EGAT generation requirement presented is the Net Generation (Station Services are exclude
File : 01-Table_PDP2007Rev2_28Feb09_Eg ; Sheet : Appendix 5-1
COMPARISON OF TOTAL EGAT GENERATION REQUIREMENT
Case: September 2007 Case: December 2008 DifferenceYear (1) (2) (2)-(1)
MW GWh MW GWh MW % GWh %2008 23,490 152,124 22,017 147,229 -1,473 -6.27 -4,895 -3.222009 24,784 160,798 22,886 150,458 -1,898 -7.66 -10,340 -6.432010 26,206 170,037 23,936 155,645 -2,270 -8.66 -14,392 -8.462011 27,540 178,824 25,085 162,884 -2,455 -8.91 -15,940 -8.912012 29,172 189,483 26,572 172,593 -2,600 -8.91 -16,890 -8.912013 30,946 201,148 28,188 183,218 -2,758 -8.91 -17,930 -8.912014 32,794 213,343 29,871 194,326 -2,923 -8.91 -19,017 -8.912015 34,840 226,823 31,734 206,604 -3,106 -8.92 -20,219 -8.912016 36,968 240,803 33,673 219,339 -3,295 -8.91 -21,464 -8.912017 39,158 255,156 35,668 232,413 -3,490 -8.91 -22,743 -8.912018 41,417 270,019 37,725 245,950 -3,692 -8.91 -24,069 -8.912019 43,726 285,158 39,828 259,740 -3,898 -8.91 -25,418 -8.912020 46,137 300,971 42,024 274,144 -4,113 -8.91 -26,827 -8.912021 48,614 317,193 44,281 288,920 -4,333 -8.91 -28,273 -8.91
8 January 2009
ESTIMATED DEPENDABLE CAPACITY OF VSPP FOR PDP 2007: REVISION 2 Unit: MW
2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021
Cogeneration 7 18 25 43 79 97 161 177 193 210 225 236 247 247 Biogas 16 27 48 48 48 48 48 48 48 48 48 48 48 48 Waste to Energy 2 2 2 46 91 91 91 91 91 91 91 91 91 91 Biomass 211 228 268 525 778 778 778 778 778 778 778 778 778 778 Wind Energy - - - 0 26 53 79 105 132 158 184 211 237 263 Solar Energy 1 137 272 420 567 715 862 862 910 955 1,003 1,053 1,105 1,161Small hydropower 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Others 0 0 1 1 1 1 1 1 1 1 1 1 1 1 Total 236 411 615 1,084 1,591 1,783 2,020 2,062 2,153 2,241 2,330 2,418 2,507 2,589
1. Estimated capacity of VSPP to be successfully developed and linked to EGAT system 2/
Cogeneration 6 4 9 18 27 59 67 75 83 91 96 102 102 Biogas 5 11 - - 0 0 0 0 0 0 0 0 0 Waste to Energy - - 22 22 22 22 22 22 22 22 22 22 22 Biomass 9 20 129 126 126 126 126 126 126 126 126 126 126 Wind Energy - - 0 13 26 39 52 66 79 92 105 118 131 Solar Energy 68 68 74 74 148 221 221 245 268 292 317 343 371 Small hydropower 0 0 - - - - - - - - - - - Others - 0 0 - 0- 0- 0- 0- 0- 0- 0- 0- 0-
88 102 234 254 350 468 489 535 579 623 667 712 753
2.Estimation of VSPP potential to serve peak demand of the EGAT system 3/
Cogeneration - 2 1 3 5 8 18 20 22 25 27 29 31 31 Biogas - 2 3 - - 0 0 0 0 0 0 0 0 0 Waste to Energy - - - 7 7 7 7 7 7 7 7 7 7 7 Biomass - 3 6 39 38 38 38 38 38 38 38 38 38 38 Wind Energy - - - - - - - - - - - - - - Solar Energy - - - - - - - - - - - - - - Small hydropower - 0 0 - - - - - - - - - - - Others - - 0 0 - 0- 0- 0- 0- 0- 0- 0- 0- 0-
6 10 48 50 53 62 65 67 70 72 74 75 75
1/MEA and PEA plan for power purchase from VSPP, as the meeting of Thailand Load Forecast Subcommittee (2008 data are estimated2/To be 50 percent of the additional power purchase from VSPP estimated3/To be 30 percent of the estimated capacity of VSPP to be successfully developed and linked to EGAT system (Wind and solar energy are excluded4/In 2009-2012, it is the VSPP potential estimated to serve peak demand. In 2013-2021, the dependable capacity of VSPP is estimated to increase by 50 MW each yea5/Wind and solar energy are excluded due to their properties of non-firm power plant
749 799 dependable capacity 5/
Note :
449 499 549 599 649 699
50 50 of VSPP for PDP 2007: Rev. 24/
Accumulative estimated235 241 251 299 349 399
50 50 50 50 50 50
MEA and PEA plan for power purchase from VSPP 1/
Total
TotalEstimated dependable capacity
6 10 48 50 50
64
65
Appendix 6
EGAT RPS Power Plant Projects
66
Scheduled Capacity (MW)Commissioning Date 2009 2010 2011 Total
1. Small Hydropower Plants
1.1 Chao Phraya Dam Unit 1 December 2009 6.0 6.0
Unit 2 March 2010 6.0 6.0
1.2 Mae Klong Dam Unit 1 November 2010 6.0 6.0
Unit 2 February 2011 6.0 6.0
1.3 Pasak Jolasid Dam October 2010 6.7 6.7
1.4 Khun Dan Prakarnchon Dam November 2010 10.0 10.0
1.5 Kwae Noi Dam Unit 1 March 2011 15.0 15.0
Unit 2 June 2011 15.0 15.0
1.6 Naresuan Dam February 2011 8.0 8.0
Subtotal 6.0 28.7 44.0 78.7
2. Solar Energy Power Plant December 2009 1.0 1.0
3. Wind Energy Power Plant December 2009 2.0 2.0
Total 9.0 28.7 44.0 81.7
Power Plants
EGAT RPS Power Plant Projects
68
69
Appendix 7
Summary of Power Purchase from SPPs
70
Installed Capacity Proposed Contracted Capacity(MW) (MW)
Firm Contractsa) Existing Projects
Natural Gas 2,260.8 1,413.0 Coal 703.0 370.0 Fuel Oil 10.4 9.0 Black Liquor 32.9 25.0 Rice husk and Wood residue 214.9 169.3 Bagasse 137.7 84.0 Palm cluster, Palm fiber, Palm shell 9.9 8.8 Subtotal 3,369.6 2,079.1
b) Commtted Projects 2,447.7 1,760.5
c) On Listing Projects 250.0 225.0
Total Firm Contracts 6,067.3 4,064.6
Non-Firm Contractsa) Existing Projects
Natural Gas 58.3 52.2 Coal 57.2 14.0 Fuel Oil, Gas, Coal 108.0 45.0 Rice husk and Wood residue 9.0 5.0 Bagasse 261.6 81.5 By-product gas from crude oil refine 2.0 1.7 Municipal Solid Waste 2.5 1.0 Waste Gas 19.0 6.0 Subtotal 517.6 206.4
b) Commtted Projects 398.0 157.0
Total Non-Firm Contracts 915.6 363.4
Grand Total 6,982.9 4,428.0
Descriptions
Summary of Power Purchase from SPPs(as of December 2008)
Projects MW
Renewable
Phu Khieo BIO-Energy CO.,LTD. 10.0
Dan Chang BIO-Energy CO.,LTD. 10.0
Deja Bio Green Co.,Ltd. 6.5
Advance Agro Public Co., Ltd. 25.0
Thai Power Generating Co.,Ltd. Project 1 70.0
National Power Supply Co., LTD. 65.0
Bio Mass Power 90.0
Thai Power Supply Co., LTD. 65.0
รวม 341.5
Co-Generation
Siam Power Generation Plc. 60.0
Siam Power Generation Co.,Ltd. Phase 1 30.0
Amata Steam Supply Co.,Ltd. 90.0
Siam Power Generation Co.,Ltd. Phase 2 90.0
Glow SPP Public Company Limited Project 3 74.0
Rojana Power Co., LTD. 90.0
Navanakorn Electric Co., Ltd. 90.0
Sara Buri B Co-generation Co.,Ltd. 90.0
Industrial Co-Gen Co.,Ltd. 90.0
Bangpain Land Development Co.,Ltd. 90.0
B-Grim BIP Power Co.,Ltd. 90.0
RIL Co-Generation Co.,Ltd. 90.0
Sara Buri B Co-Generation Co.,Ltd. 90.0
Combine Heat and Power Co.,Ltd. 90.0
Chachuengsao Co-generation Co.,Ltd. 90.0
Pathum Co-generation Co.,Ltd. 90.0
Amata Power Co., LTD. (Amata Nakorn) 90.0
Amata Power Co., LTD. (Plauk Daeng) 90.0
Thai National Power Co., LTD. Project 2 90.0
TRC Construction Public Company Limited 40.0
Subtotal 1,644.0 1,985.5
List of Small Power Producers Project (Firm Contract)
During Consideration of Purchasing in 2009 - 2014
(As of 31 December 2008)
Grand Total
73
Appendix 8 Summary of Existing Non-Firm Contract SPP
Classified by Fuel Typess
74
Fuel Types Capacity Contracted
Capacity(MW) (MW)
Commercial Fuels Natural gas 58.300 52.200 Fuel oil 108.000 45.000 Coal 57.200 14.000 Subtotal 223.500 111.200 Renewable Energy Bagasse 261.600 81.500 Rice husk and wood residue 9.000 5.000 Waste Gas 19.000 6.000 Municipal solid waste 2.500 1.000 By-product gas from crude oil refinery 1.950 1.723 Subtotal 294.050 95.223
Total 517.550 206.423
Summary of Existing Non-Firm Contract SPP
(As of 31 December 2008)Classified by Fuel Types
Declare for Cancelling Contract with EGAT
No. Company Retirement Date MW
1 New Kuang Sun Lee Sugar Co.,Ltd. 31 March 2007 2.0
2 Bua Yai Bio Power Co.,Ltd. 31 August 2007 7.0
3 Uthong Biomass Co.,Ltd. 30 September 2007 6.5
4 Salaf Energy Co.,Ltd. 30 November 2007 8.5
5 Saharuang Co.,Ltd. 30 November 2007 7.0
6 Khonburi Sugar Co.,Ltd. 30 November 2007 6.0
7 Korach Industry Co., Ltd. (1) 31 December 2007 8.0
8 TN Sugar Industry Co., Ltd. 31 December 2007 8.0
9 Advance Bio Power Co.,Ltd. 31 December 2007 6.5
10 E-Saan Sugar Industry Co.,Ltd. 31 December 2007 2.5
11 Karnchanaburi Sugar Industry Co., Ltd. 31 December 2007 4.0
12 Bua Sommai Co., Ltd. 31 January 2008 3.0
13 Eastern Sugar Co., Ltd. 31 January 2008 6.0
14 Rayong Sugar Co., Ltd. 31 January 2008 6.0
15 Mitrkasetr Industry Co.,Ltd. 31 January 2008 3.0
List of Small Power Producers Project (Non-Firm Contract)
(As of 31 December 2008)
16 Rermudom Sugar Factory Co.,Ltd. 29 February 2008 7.0
17 Buri Ram Sugar Co., Ltd. 29 February 2008 8.0
18 Banpong Sugar Co., Ltd. 29 February 2008 3.0
19 Phitsanulok Sugar Co., Ltd. 29 February 2008 4.0
20 New Krung Thai Sugar Factory Co.,Ltd. 31 March 2008 2.0
21 Tha Maka Sugar Co., Ltd. 31 March 2008 2.0
22 Korach Industry Co., Ltd. (2) 31 March 2008 8.0
23 Surin Electric Co., Ltd. 31 March 2008 8.0
24 Pran Buri Sugar Industry Co., Ltd. 31 March 2008 3.0
25 Rajburi Sugar Co., Ltd. 31 March 2008 6.8
26 Sing Buri Sugar Co.,Ltd. 31 May 2008 4.0
27 Thai Identity Sugar Factory Co.,Ltd. 19 January 2009 3.0
28 Kaset Thai Sugar Co., Ltd. 24 January 2009 8.0
29 Thai Permpun Industry Co.,Ltd. 28 February 2009 4.0
30 Ruampol Nakhonsawan Industry Co., Ltd. 31 May 2009 2.5
157.3
Note : 1/ These SPPs are still selling power to EGAT and will be terminated when contract is over
Total
1/
1/
1/
1/
File : 01-Table_PDP2007Rev2_28Feb09_Eg
77
Appendix 9 Projection of Energy Generating Capacity
Classified by Power Plant Types
78
PRO
JEC
TIO
N O
F G
EN
ER
AT
ING
CA
PAC
ITY
CL
ASS
IFIE
D B
Y P
OW
ER
PL
AN
T T
YPE
S (P
DP
2007
: Rev
isio
n 1)
2009
2010
2011
2012
2013
2014
2015
2016
2017
2018
2019
2020
2021
- E
GA
TM
W3,
424
3,42
4 3,
424
3,42
4 3,
424
3,42
4 3,
424
3,42
4 3,
424
3,42
4 3,
424
3,42
4 3,
424
%11
.4
11.1
10
.5
10.2
9.
5 8.
8 9.
0 8.
6 8.
1 7.
7 7.
3 7.
0 6.
6 -
Lao
PD
RM
W1,
260
1,26
0 1,
857
2,07
7 2,
077
2,07
7 2,
077
2,07
7 2,
077
2,07
7 2,
077
2,07
7 2,
077
%4.
2 4.
1 5.
7 6.
2 5.
7 5.
4 5.
5 5.
2 4.
9 4.
7 4.
4 4.
3 4.
0 -
Fore
ign
Purc
hase
MW
-
-
-
-
-
-
450
900
1,35
0 1,
800
2,30
0 2,
800
3,30
0 %
-
-
-
-
-
-
1.2
2.3
3.2
4.1
4.9
5.7
6.4
Subt
otal
MW
4,68
4 4,
684
5,28
1 5,
501
5,50
1 5,
501
5,95
1 6,
401
6,85
1 7,
301
7,80
1 8,
301
8,80
1 %
15.5
15
.1
16.3
16
.3
15.2
14
.2
15.6
16
.0
16.2
16
.4
16.5
17
.0
17.0
O
il-
EG
AT
MW
315
315
315
315
315
315
315
315
315
315
315
315
315
%1.
0 1.
0 1.
0 0.
9 0.
9 0.
8 0.
8 0.
8 0.
8 0.
7 0.
7 0.
6 0.
6 -
SPP
MW
9 9
9 9
9 9
9 9
9 9
-
-
-
%0.
0 0.
0 0.
0 0.
0 0.
0 0.
0 0.
0 0.
0 0.
0 0.
0 -
-
-
O
il / G
as-
EG
AT
MW
2,20
4 2,
204
2,20
4 2,
204
2,20
4 1,
152
1,15
2 1,
152
1,15
2 1,
152
1,15
2 1,
152
1,15
2 %
7.3
7.1
6.8
6.5
6.1
3.0
3.0
2.9
2.7
2.6
2.4
2.4
2.2
- IP
PM
W1,
580
1,58
0 1,
510
1,51
0 1,
510
1,51
0 1,
510
1,44
0 1,
440
1,44
0 1,
440
1,44
0 1,
440
%5.
2 5.
1 4.
7 4.
5 4.
2 3.
9 4.
0 3.
6 3.
4 3.
2 3.
1 3.
0 2.
8 L
igni
te-
EG
AT
MW
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 %
7.2
7.0
6.7
6.5
6.0
5.6
5.7
5.5
5.2
4.9
4.6
4.5
4.2
Coa
l-
EG
AT
MW
-
-
-
-
-
-
-
1,40
0 2,
800
2,80
0 2,
800
2,80
0 2,
800
%-
-
-
-
-
-
-
3.
5 6.
6 6.
3 5.
9 5.
7 5.
4 -
IPP
MW
1,34
7 1,
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
%4.
5 4.
4 6.
2 6.
0 6.
3 6.
6 6.
7 6.
4 6.
0 5.
7 5.
4 5.
2 4.
9 -
SPP
MW
370
370
370
370
370
370
370
370
370
360
360
360
360
%1.
2 1.
2 1.
1 1.
1 1.
0 1.
0 1.
0 0.
9 0.
9 0.
8 0.
8 0.
7 0.
7 Su
btot
alM
W8,
005
8,00
5 8,
595
8,59
5 8,
865
8,08
3 8,
083
9,41
3 10
,813
10
,803
10
,794
10
,794
10
,794
%
26.6
25
.9
26.5
25
.5
24.5
20
.8
21.2
23
.5
25.6
24
.3
22.9
22
.1
20.9
-
EG
AT
MW
6,19
6 6,
866
6,86
6 6,
866
6,86
6 8,
466
8,46
6 8,
466
8,15
2 9,
913
10,7
13
10,0
72
10,0
72
%20
.6
22.2
21
.1
20.4
19
.0
21.8
22
.2
21.2
19
.3
22.3
22
.7
20.6
19
.5
- IP
PM
W9,
225
9,22
5 9,
225
9,22
5 10
,825
12
,425
11
,250
10
,572
10
,572
10
,572
10
,572
11
,472
11
,472
%
30.6
29
.8
28.4
27
.3
29.9
32
.1
29.5
26
.4
25.0
23
.8
22.4
23
.5
22.2
-
SPP
MW
1,29
3 1,
293
1,29
3 1,
293
1,29
3 1,
293
1,29
3 1,
293
1,11
3 1,
081
901
721
521
%4.
3 4.
2 4.
0 3.
8 3.
6 3.
3 3.
4 3.
2 2.
6 2.
4 1.
9 1.
5 1.
0 -
New
pow
er p
lant
MW
-
-
-
-
-
-
-
800
1,60
0 1,
600
3,20
0 3,
200
4,80
0 %
-
-
-
-
-
-
-
2.0
3.8
3.6
6.8
6.6
9.3
Subt
otal
MW
16,7
14
17,3
84
17,3
84
17,3
84
18,9
84
22,1
84
21,0
09
21,1
31
21,4
37
23,1
66
25,3
86
25,4
65
26,8
65
%55
.4
56.2
53
.5
51.5
52
.4
57.2
55
.2
52.8
50
.8
52.1
53
.8
52.1
51
.9
- E
GA
TM
W4
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 -
SPP
MW
120
120
120
120
120
120
120
120
120
120
120
120
120
%0.
4 0.
4 0.
4 0.
4 0.
3 0.
3 0.
3 0.
3 0.
3 0.
3 0.
3 0.
3 0.
2 Su
btot
alM
W12
4 12
4 12
4 12
4 12
4 12
4 12
4 12
4 12
4 12
4 12
4 12
4 12
4 %
0.4
0.4
0.4
0.4
0.3
0.3
0.3
0.3
0.3
0.3
0.3
0.3
0.2
- E
GA
TM
W7
42
80
80
80
80
80
80
80
80
80
80
80
%0.
0 0.
1 0.
3 0.
2 0.
2 0.
2 0.
2 0.
2 0.
2 0.
2 0.
2 0.
2 0.
2 -
SPP
MW
287
287
287
287
287
287
287
287
287
287
287
279
279
%1.
0 0.
9 0.
9 0.
9 0.
8 0.
7 0.
8 0.
7 0.
7 0.
7 0.
6 0.
6 0.
5 Su
btot
alM
W29
4 32
9 36
7 36
7 36
7 36
7 36
7 36
7 36
7 36
7 36
7 35
9 35
9 %
1.0
1.1
1.1
1.1
1.0
1.0
1.0
0.9
0.9
0.8
0.8
0.7
0.7
- R
enew
able
MW
27
27
277
342
342
342
342
342
342
342
342
342
342
%0.
1 0.
1 0.
9 1.
0 0.
9 0.
9 0.
9 0.
9 0.
8 0.
8 0.
7 0.
7 0.
7 -
Cog
ener
atio
nM
W-
90
90
1,
014
1,55
4 1,
644
1,64
4 1,
644
1,64
4 1,
644
1,64
4 1,
644
1,64
4 %
-
0.3
0.3
3.0
4.3
4.2
4.3
4.1
3.9
3.7
3.5
3.4
3.2
Subt
otal
MW
27
117
367
1,35
6 1,
896
1,98
6 1,
986
1,98
6 1,
986
1,98
6 1,
986
1,98
6 1,
986
%0.
1 0.
4 1.
1 4.
0 5.
2 5.
1 5.
2 5.
0 4.
7 4.
5 4.
2 4.
1 3.
8 M
W6
16
64
114
164
214
264
314
364
414
464
514
564
%0.
0 0.
1 0.
2 0.
3 0.
5 0.
6 0.
7 0.
8 0.
9 0.
9 1.
0 1.
1 1.
1
MW
300
300
300
300
300
300
300
300
300
300
300
300
300
%1.
0 1.
0 0.
9 0.
9 0.
8 0.
8 0.
8 0.
8 0.
7 0.
7 0.
6 0.
6 0.
6 -
EG
AT
MW
-
-
-
-
-
-
-
-
-
-
-
1,00
0 2,
000
%-
-
-
-
-
-
-
-
-
-
-
2.
1 3.
9
MW
30,1
54
30,9
59
32,4
81
33,7
40
36,2
00
38,7
58
38,0
83
40,0
35
42,2
41
44,4
60
47,2
21
48,8
42
51,7
92
%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
VSP
P
EG
AT
-TN
B H
VD
C
Nuc
lear
Tot
al
The
rmal
Com
bine
d C
ycle
Gas
Gas
Tur
bine
and
Die
sel
Ren
ewab
le E
nerg
y
SPP
(Add
ition
al P
urch
ase)
Pow
er P
lant
Typ
esU
nits
Yea
r
Hyd
ro/
Fore
ign
Purc
hase
80
81
Appendix 10 Projection of Energy Generation
Classified by Fuel Types and Energy Purchase
82
PRO
JEC
TT
ION
OF
EN
ER
GY
GE
NE
RA
TIO
N C
LA
SSIF
IED
BY
FU
EL
TY
PES
AN
D E
NE
RG
Y P
UR
CH
ASE
(PD
P 20
07: R
evis
ion
2)Y
ear
2009
2010
2011
2012
2013
2014
2015
2016
2017
2018
2019
2020
2021
- E
GA
TG
wh
5,79
8 6,
046
5,82
7 5,
795
5,79
8 5,
815
5,81
5 5,
815
5,81
5 5,
815
5,81
5 5,
815
5,81
5 %
3.9
3.9
3.6
3.4
3.2
3.0
2.8
2.7
2.5
2.4
2.2
2.1
2.0
- L
ao P
DR
Gw
h2,
930
8,13
6 10
,193
10
,588
10
,658
11
,270
11
,220
11
,170
11
,120
11
,120
11
,120
11
,120
11
,120
%
2.0
5.2
6.3
6.1
5.8
5.8
5.4
5.1
4.8
4.5
4.3
4.1
3.9
- For
eign
Pur
chas
eG
wh
-
-
-
-
-
-
1,45
5 4,
275
6,92
9 9,
239
11,8
05
14,3
72
16,9
38
%-
-
-
-
-
-
0.
7 2.
0 3.
0 3.
8 4.
6 5.
2 5.
9 Su
btot
alG
wh
8,72
8 14
,182
16
,020
16
,384
16
,457
17
,084
18
,490
21
,260
23
,864
26
,173
28
,740
31
,306
33
,872
%
5.8
9.1
9.8
9.5
9.0
8.8
8.9
9.7
10.3
10
.6
11.1
11
.4
11.7
-
EG
AT
Gw
h44
,326
42
,146
43
,445
45
,059
42
,623
40
,570
44
,752
43
,176
40
,544
56
,005
61
,558
59
,185
58
,340
%
29.5
27
.1
26.7
26
.1
23.3
20
.9
21.7
19
.7
17.4
22
.8
23.7
21
.6
20.2
M
MC
FD95
5 88
0 89
2 93
3 87
6 79
1 86
4 82
9 77
6 1,
052
1,15
3 1,
096
1,08
3 -
IPP
Gw
h56
,297
57
,946
58
,182
57
,217
64
,412
69
,899
75
,825
73
,508
67
,034
63
,565
57
,297
65
,407
59
,973
%
37.4
37
.2
35.7
33
.2
35.2
36
.0
36.7
33
.5
28.8
25
.8
22.1
23
.9
20.8
M
MC
FD1,
109
1,14
5 1,
148
1,13
1 1,
261
1,34
5 1,
452
1,40
2 1,
281
1,21
3 1,
092
1,23
4 1,
132
- SP
PG
wh
9,10
7 9,
361
9,29
8 9,
303
9,10
4 9,
902
9,90
2 9,
902
9,27
2 8,
473
8,04
9 6,
367
5,28
6 %
6.1
6.0
5.7
5.4
5.0
5.1
4.8
4.5
4.0
3.4
3.1
2.3
1.8
- N
ew p
ower
pla
ntG
wh
-
-
-
-
-
-
-
2,87
5 12
,384
12
,344
24
,603
24
,477
36
,478
%
-
-
-
-
-
-
-
1.3
5.3
5.0
9.5
8.9
12.6
M
MC
FD-
-
-
-
-
-
-
53
23
0 22
9 45
6 45
3 67
6 Su
btot
alG
wh
109,
730
109,
453
110,
924
111,
579
116,
139
120,
371
130,
480
129,
461
129,
234
140,
386
151,
508
155,
437
160,
078
%72
.9
70.3
68
.1
64.7
63
.4
62.0
63
.2
59.0
55
.6
57.1
58
.3
56.7
55
.4
MM
CFD
2,06
4 2,
025
2,04
0 2,
064
2,13
6 2,
136
2,31
6 2,
284
2,28
7 2,
494
2,70
1 2,
783
2,89
1 -
EG
AT
Gw
h16
6 11
5 -
-
-
0
0 1
1 1
1 1
1 %
0.1
0.1
-
-
-
-
-
-
-
-
-
-
-
ML
iters
41
29
-
-
-
0 0
0 0
0 0
0 0
- IP
PG
wh
153
-
-
0 0
-
-
-
-
-
-
-
-
%0.
1 -
-
-
-
-
-
-
-
-
-
-
-
M
Lite
rs37
-
-
0
0 -
-
-
-
-
-
-
-
-
SPP
Gw
h33
29
30
29
30
63
63
63
63
63
32
-
-
%
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
-
-
Subt
otal
Gw
h35
2 14
4 30
29
30
63
63
64
64
64
32
1
1 %
0.2
0.1
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
-
-
ML
iters
78
29
-
0 0
0 0
0 0
0 0
0 0
- E
GA
TG
wh
53
28
28
28
35
26
26
27
26
24
24
21
21
%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 M
Lite
rs13
8
8 8
11
7 7
7 7
6 6
6 6
- E
GA
TG
wh
16,5
97
16,5
23
17,1
55
16,7
69
17,1
55
17,1
53
17,1
53
17,2
02
17,1
53
17,1
53
17,1
53
17,2
02
17,1
53
%11
.0
10.6
10
.5
9.7
9.4
8.8
8.3
7.8
7.4
7.0
6.6
6.3
5.9
MT
ons
16.3
5 16
.27
16.6
0 16
.21
16.6
0 15
.82
15.6
8 15
.14
15.1
2 15
.15
14.5
1 14
.54
13.6
3 -
EG
AT
Gw
h-
-
-
-
-
-
-
10
,732
21
,401
21
,401
21
,401
21
,464
21
,401
%
-
-
-
-
-
-
-
4.9
9.2
8.7
8.2
7.8
7.4
M
Ton
s-
-
-
-
-
-
-
3.
78
7.53
7.
53
7.53
7.
55
7.53
-
IPP
Gw
h10
,021
10
,082
11
,974
15
,004
15
,436
19
,103
19
,464
19
,522
19
,464
19
,464
19
,464
19
,522
19
,464
%
6.7
6.5
7.4
8.7
8.4
9.8
9.4
8.9
8.4
7.9
7.5
7.1
6.7
MT
ons
3.67
3.
68
4.38
5.
49
5.65
6.
86
6.99
7.
01
6.99
6.
99
6.99
7.
01
6.99
-
SPP
Gw
h2,
268
2,35
9 2,
413
2,36
9 2,
623
2,59
3 2,
593
2,59
3 2,
593
2,52
9 2,
523
2,52
3 2,
523
%1.
5 1.
5 1.
5 1.
4 1.
4 1.
3 1.
3 1.
2 1.
1 1.
0 1.
0 0.
9 0.
9 Su
btot
alG
wh
12,2
89
12,4
41
14,3
87
17,3
73
18,0
59
21,6
96
22,0
57
32,8
47
43,4
58
43,3
94
43,3
88
43,5
09
43,3
88
%8.
2 8.
0 8.
8 10
.1
9.9
11.2
10
.7
15.0
18
.7
17.6
16
.7
15.9
15
.0
MT
ons
3.67
3.
68
4.38
5.
49
5.65
6.
86
6.99
10
.79
14.5
2 14
.52
14.5
2 14
.56
14.5
2 -
EG
AT
Gw
h3
77
262
277
277
365
365
365
365
365
365
365
365
%-
0.
1 0.
2 0.
2 0.
2 0.
2 0.
2 0.
2 0.
2 0.
2 0.
1 0.
1 0.
1 -
SPP
Firm
Gw
h1,
770
1,74
4 1,
715
1,58
6 1,
601
2,01
2 2,
012
2,01
2 2,
012
2,01
2 2,
012
1,97
5 1,
956
%1.
2 1.
1 1.
1 0.
9 0.
9 1.
0 1.
0 0.
9 0.
9 0.
8 0.
8 0.
7 0.
7 -
SPP
Non
Fir
mG
wh
601
601
515
515
515
365
365
365
365
365
365
365
365
%0.
4 0.
4 0.
3 0.
3 0.
3 0.
2 0.
2 0.
2 0.
2 0.
2 0.
1 0.
1 0.
1 Su
ntot
alG
wh
2,37
4 2,
421
2,49
2 2,
379
2,39
3 2,
743
2,74
3 2,
743
2,74
3 2,
743
2,74
3 2,
705
2,68
7 %
1.6
1.6
1.5
1.4
1.3
1.4
1.3
1.3
1.2
1.1
1.1
1.0
0.9
- R
enew
able
Gw
h17
4 18
6 91
6 2,
393
2,39
3 2,
393
2,39
3 2,
393
2,39
3 2,
393
2,39
3 2,
393
2,39
3 %
0.1
0.1
0.6
1.4
1.3
1.2
1.2
1.1
1.0
1.0
0.9
0.9
0.8
Gw
h-
10
5 63
1 4,
408
9,31
4 11
,258
11
,521
11
,521
11
,521
11
,521
11
,521
11
,521
11
,521
%
-
0.1
0.4
2.6
5.1
5.8
5.6
5.3
5.0
4.7
4.4
4.2
4.0
Subt
otal
Gw
h17
4 29
1 1,
546
6,80
1 11
,707
13
,652
13
,914
13
,914
13
,914
13
,914
13
,914
13
,914
13
,914
%
0.1
0.2
1.0
3.9
6.4
7.0
6.7
6.3
6.0
5.7
5.4
5.1
4.8
Gw
h17
45
17
9 32
0 46
0 60
0 74
0 88
0 1,
020
1,16
1 1,
301
1,44
1 1,
581
%0.
0 0.
0 0.
1 0.
2 0.
3 0.
3 0.
4 0.
4 0.
4 0.
5 0.
5 0.
5 0.
6 G
wh
143
117
122
931
783
939
939
941
939
939
939
941
939
%0.
1 0.
1 0.
1 0.
5 0.
4 0.
5 0.
5 0.
4 0.
4 0.
4 0.
4 0.
3 0.
3 -
EG
AT
Gw
h-
-
-
-
-
-
-
-
-
-
-
7,
666
15,2
86
%-
-
-
-
-
-
-
-
-
-
-
2.
8 5.
3 T
ons
-
-
-
-
-
-
-
-
-
-
-
22.9
3 45
.72
Tot
alG
wh
150,
458
155,
645
162,
884
172,
593
183,
218
194,
326
206,
604
219,
339
232,
413
245,
950
259,
740
274,
144
288,
920
%10
0 10
0 10
0 10
0 10
0 10
0 10
0 10
0 10
0 10
0 10
0 10
0 10
0
EG
AT
-TN
B H
VD
C
Nuc
lear
SPP
(Add
ition
al
Purc
hase
)-
Cog
ener
atio
n
VSP
P
Fuel
oil
Die
sel
Lig
nite
Impo
rted
coa
l
Ren
ewab
le E
nerg
yFuel
Typ
esU
nits
Hyd
ro/
Fore
ign
Purc
hase
Nat
ural
gas
/ L
NG
84
85
Appendix 11 Transmission System Expansion Projects
86
DETA
ILS O
F TR
ANSM
ISSI
ON SY
STEM
EXP
ANSI
ON P
ROGR
AM(P
DP 20
07: R
evisi
on 2)
Items
Name
of Tr
ansmi
ssion
Lines
Lengt
hNu
mber
Voltag
eCo
nducto
rCo
mmiss
ioning
and(km
)of
(kV)
Size
Date
Subst
ations
Circui
t(M
CM)
(Year
)A.
TRAN
SMIS
SION
EXP
ANSI
ON P
ROJE
CTS A
SSOC
IATE
D W
ITH
GENE
RATI
ON P
ROJE
CTS
1. ON
GOIN
G PR
OJEC
TS
COM
BIND
CYC
LE P
OWER
PLA
NT P
ROJE
CTS
1.1
Nort
h Bang
kok Co
mbine
d Cycl
e Pow
er Pla
nt Blo
ck #1
(1x670
MW)
1.1.1
Nort
h Bang
kok Su
bstatio
n Expa
nsion
--
230-
2009
Subto
tal
-B.
TRAN
SMIS
SION
SYST
EM E
XPAN
SION
PRO
JECT
S
1. ON
GOIN
G PR
OJEC
TS
1.1 T
rans
missi
on Sy
stem
Expa
nsion
Pro
ject N
o. 10
1.1.1
Tran
sform
er Ad
dition
at Ex
isting
Subst
ations
--
--
2009
1.1.2
Shun
t Capa
citor In
stallat
ion-
--
-200
9
1
.1.3 M
iscella
neous
Syste
m Ex
pansio
n-
--
-200
9-2010
Subto
tal
-
DETA
ILS
OF T
RANS
MIS
SION
SYS
TEM
EXP
ANSI
ON P
ROGR
AM (C
ontin
ued)
(PDP
2007
: Rev
ision
2)
Items
Name
of Tr
ansmi
ssion
Lines
Lengt
hNu
mber
Voltag
eCo
nducto
rCo
mmiss
ioning
and(km
)of
(kV)
Size
Date
Subst
ations
Circui
t(M
CM)
(Year
)
1.2
500 k
V Tr
ansm
ission
Syste
m Pr
oject
for P
ower
Pur
chas
e fro
m Na
m Th
eun 2
Hyd
ro P
ower
Plan
t
1
.2.1 T
hai/La
o Bord
er (M
ukdaha
n Prov
ince)
- Roi
Et 2
1662
5004x1
272200
9
1
.2.2 R
oi Et
2 - Ro
i Et 1
202
2304x1
27 2200
9
Subt
otal
186
.0 km
(or 37
2.0 cir
cuit-k
ilome
ters)
1.3
Bulk
Pow
er Su
pply
for th
e Gre
ater B
angk
ok A
rea P
hase
2 Pro
ject
1.3.1
Sai N
oi and
Bangk
ok No
i Subs
tations
Expan
sion
--
230-
2009
1.3.2
Shun
t Capa
citor In
stallat
ion-
--
-200
9-2010
1.3.3
Misc
ellaneo
us Sy
stem
Expan
sion
--
--
2009-2
010
1
.3.4 N
ong Ch
ok - O
n Nuch
(18.0)
2500
4x1272
2010
1.3.5
Sect
ionaliz
ing of
230 k
V Bang
Pakon
g - Ba
ng Ph
li Line
at Kh
long D
an Su
bstatio
n
and B
ang Pa
kong -
Khlon
g Dan
- Bang
Phli
442
2302x1
272201
0-2011
1.3.6
Tran
sform
er Ad
dition
at Ex
isting
Subst
ations
--
--
2010-2
011
Su
btotal
44 k
m (or
88.0 c
ircuit
-kilom
eters)
and 1
new s
ubstati
onNo
tes :
1/ On
the e
xistin
g righ
t-of-w
ay2/
New S
ubstati
on3/
Line c
onvers
ion fro
m 230
kV to
500 k
V
1/ 1/
3/2/
DETA
ILS
OF T
RANS
MIS
SION
SYS
TEM
EXP
ANSI
ON P
ROGR
AM (C
ontin
ued)
(PDP
2007
: Rev
ision
2)
Items
Name
of Tr
ansmi
ssion
Lines
Lengt
hNu
mber
Voltag
eCo
nducto
rCo
mmiss
ioning
an d(km
)of
(kV)
Size
Date
Subst
ations
Circui
t(M
CM)
(Year
)
1.4
500 k
V Tr
ansm
ission
Syste
m Pr
oject
for IP
Ps P
ower
Plan
ts
1.4.1
Plua
k Daen
g - No
ng Ch
ok Jun
ction #
3, 4
1592
5004x1
272201
1
Subt
otal
159.
0 km
(or 31
8.0 cir
cuit-k
ilome
ters)
1.
5 50
0 kV
Tran
smiss
ion Sy
stem
Proje
ct for
Pow
er P
urch
ase f
rom
Nam
Nugm
2 Hy
dro P
ower
Plan
t
1
.5.1 T
hai/La
o Bord
er (N
ong Kh
ai Prov
ince)
- Udon
Thani
380
2500
4x1272
2010
S
ubtota
l
80.0 k
m (or
160.0
circui
t-kilo
meter
s) and
1 new
subst
ation
1.6
Tra
nsmi
ssion
Syste
m Ex
pans
ion P
rojec
t No.1
1
Cen
tral R
egion
1.6.1
Rayon
g 3 - R
ayong
115.
42
1152x7
95201
0
1.
6.2 K
anchan
aburi 1
- Kanc
hanabu
ri 214
2115
2x795
2010
1.6.3
Sectio
nalizin
g Wang
Noi -
Sarabu
ri 2
t
o Sara
buri 5
Subst
ation
54
2302x1
272201
1
1.6
.4 Th
a Wung
- Lop
Buri 1
132
1152x7
95201
1
a
nd Th
a Tako
- Chai
Badan
902
115795
2011
1.6.5
Ratch
aburi 3
- Sam
ut Sak
hon 4 -
S
amut
Sakhon
3 - Sa
m Ph
ran 1
40/25.
5/15.5
2/4/4
230/23
04x1
272/2x
1272
2011
(Invar
)
a
nd Sam
ut Sak
hon 1 -
Samu
t Sakh
on 3 -
Sam
Phran
1(7.
1)/(15
.5)-
115/11
52x7
95201
1
Notes
: 1/
New S
ubstati
on2/
Initial
ly ene
rgize
at 230
kV3/
On th
e exis
ting r
ight-o
f-way
4/ Qu
adrupl
e-circ
uit ste
el tow
ers
1/2/
3/1 /
3/3/
3 /
3/3/
4/4/4/
DETA
ILS
OF T
RANS
MIS
SION
SYS
TEM
EXP
ANSI
ON P
ROGR
AM (C
ontin
ued)
(PDP
2007
: Rev
ision
2)
Items
Name
of Tr
ansmi
ssion
Lines
Lengt
hNu
mber
Voltag
eCo
nducto
rCo
mmiss
ioning
and(km
)of
(kV)
Size
Date
Subst
ations
Circui
t(M
CM)
(Year
)
Nor
thea
stern
Reg
ion
1
.6.6 U
don Th
ani 2 -
Nong
Bua L
am Ph
u(55
.2)1
115795
2010
an
d Nong
Bua L
am Ph
u - Lo
ei80
2115
795201
1
1
.6.7 N
am Ph
ong 2 -
Udon
Thani
385
2500
4x1272
2011
1.6.8
Sect
ionaliz
ing La
m Ta
khong
- Nakh
on Ra
tchasi
ma 2
to
Sikhi
u Subs
tation
54
2302x1
272 (G
AP)
2011
S
ikhiu
- Nakh
on Ra
tchasi
ma 3
452
2302x1
272201
1i
(i
)i
/
1/
4/ 3/2/
5 /
1.6.9
Suri
n 2 - (
Surin
1) - B
uri Ra
m2/4
62
230127
2201
1
1
.6.10 R
oi Et
1- Ma
hasara
kham
382
1152x7
95201
1
Sout
hern
Reg
ion
1
.6.11 K
rabi -
Phang
nga 2-
Phukh
et 398/
(76.9)
2/2230
/230
2x1272
/1272
2011
Notes
: 1/
New S
ubstati
on2/
On th
e exis
ting r
ight-o
f-way
3/ In
itially
energ
ized a
t 115
kV4 /
Initia
lly en
ergize
d at 2
30 kV
5/ Li
ne stri
nging
on the
existi
ng ste
el tow
ers6/
Line
conver
sion f
rom 11
5 kV t
o 230
kV
1/
4/ 3/2/ 2 /
1/1/
2/2/
5/
6/
DETA
ILS
OF T
RANS
MIS
SION
SYS
TEM
EXP
ANSI
ON P
ROGR
AM (C
ontin
ued)
(PDP
2007
: Rev
ision
2)
Items
Name
of Tr
ansmi
ssion
Lines
Lengt
hNu
mber
Voltag
eCo
nducto
rCo
mmiss
ioning
and(km
)of
(kV)
Size
Date
Subst
ations
Circui
t(M
CM)
(Year
)
Noth
ern R
egion
1.6.1
2 Tr
ansfor
mer A
dditio
n at E
xistin
g Subs
tations
--
--
2010-2
011
1
.6.13
Shunt
Capac
itor In
stallat
ion-
--
-201
0-2011
1.6.1
4 M
iscella
neous
Syste
m Ex
pansio
n(78
.8)1
1152x7
95201
0-2011
1.6.1
5 M
ae Mo
h 3 - M
ae Mo
h 4 - L
amphu
n 21/1
042/4
230/23
04x1
272/2x
1272
2011
a
nd Ma
e Moh
3 - La
mpang
1
and
Lamp
hun 1 -
Lamp
hun 2
(35.3)
/(7.5)
-115
2x795/
795201
116
16Sec
tional
izingM
aeMo
h3-C
hiang
Rai
2/
1/
5/2/
2/3/
1 /4/
1.6.1
6 Se
ctional
izing M
ae Mo
h 3 - C
hiang
Rai
t
o Phay
ao Su
bstatio
n1
4230
1272
2011
1.6.1
7 Se
ctional
izing P
hitsan
ulok 2
- Nakh
on Saw
an
to P
hichit
Subst
ation
232
230127
2201
1
Su
btotal
746.4
km (o
r 1,77
8.8 cir
cuit-k
ilome
ters) a
nd 6 n
ew su
bstatio
ns
Notes
: 1/
New S
ubstati
on2/
On th
e exis
ting r
ight-o
f-way
3/ Qu
adrupl
e-circ
uit ste
el tow
ers4/
Line
stringi
ng on
the ex
isting
steel t
owers
5/ On
the e
xistin
g righ
t-of-w
ay (M
ae Mo
h 3 - L
ampan
g 1 - L
amphu
n 1 -
6/ Qu
adrupl
e-circ
uit ste
el tow
ers, in
itally
double
-circu
it line
string
ing
Lamp
hun 2)
7/ Li
ne con
versio
n from
230 k
V to 5
00 kV
2/
1/
5/2/
2/3/
1 /4/ 3/ 6/
DETA
ILS
OF T
RANS
MIS
SION
SYS
TEM
EXP
ANSI
ON P
ROGR
AM (C
ontin
ued)
(PDP
2007
: Rev
ision
2)
Items
Name
of Tr
ansmi
ssion
Lines
Lengt
hNu
mber
Voltag
eCo
nducto
rCo
mmiss
ioning
and(km
)of
(kV)
Size
Date
Subst
ations
Circui
t(M
CM)
(Year
)2.
FUTU
RE P
ROJE
CTS
2.
1 T
rans
missi
on Sy
stem
Deve
lopme
nt fo
r Pow
er P
urch
ase f
rom
Theu
n Hinb
oun E
xpan
sion H
ydro
powe
r Pro
ject
2.1.1
Thai
/Lao B
order
(Nakh
on Ph
anom
Provin
ce) - N
akhon
Phano
m 2
(7.5)
2230
1272 (
Invar)
2012
2.1.2
Nakh
on Ph
anom
2 - Na
khon P
hanom
Junct
ion2
2230
1272
2012
2.1.3
Phan
g Khon
- Sako
n Nakh
on 1
522
115477
2012
Subto
tal
54.0
km (o
r 108.
0 circ
uit-ki
lomete
rs) an
d 1 ne
w subs
tation
2.2.2
นาน
- แมเมาะ 3
1652
5004x1
272255
5
2.2
Tra
nsmi
ssion
Syste
m Pr
oject
for IP
Ps P
ower
Plan
ts
A
) GHE
CO-O
ne Co
., Ltd.
(Coal
), Niko
m Ma
p Ta P
hut
2.2
.1 N
ikom
Map T
a Phut
Subst
ation E
xpansi
on-
-230
-201
1
2.2
.2 N
ikom
Map T
a Phut
- Rayo
ng 2
(11)
2230
2x450m
m2 (ZTA
CIR)
2011
2.2.3
Klae
ng - C
hantha
buri
561
115795
2012
B) S
iam En
ergy C
o., Ltd
. (Gas)
, Bang
Khla
2.2.4
Sect
ionaliz
ing of
Pluak
Daeng
- Nong
Chok
Doubl
e-circ
uit
t
o Bang
Khla S
ubstati
on 0.1
4500
4x1272
2012
to b
e Plua
k Daen
g - Ba
ng Kh
la - No
ng Ch
ok(2
Route
s)
2.2
.5 C
onstru
cting f
rom Ba
ng Kh
la - Po
wer P
lant
0.32
5004x7
95201
2(2
Route
s)
C
) Natio
nal Po
wer S
upply
Co., L
td. (C
oal), P
hanom
Sarak
ham
2.2
.6 S
ection
alizing
of Pl
uak Da
eng - W
ang No
i (1 cir
cuit)
to P
hanom
Sarak
ham Su
bstatio
n0.1
2500
4x1272
2013
to b
e Plua
k Daen
g - Ph
anom
Sarakh
am - W
ang No
i
2.2.7
Cons
tructin
g from
Phano
m Sar
akham
- Pow
er Pla
nt12
250 0
4x795
2013
Notes
: 1/
New S
ubstati
on2/
Recon
ductor
ing to
high
capaci
ty typ
e (Inv
ar3/
On th
e exis
ting r
ight-o
f-way
4/ Co
nstruc
ting t
he sin
gle-ci
rcuit t
ransm
ission
line o
n the
double
-circu
it stee
l towe
1/2/
3/ 3/ 3/3/
4 /
1/
1 /
DETA
ILS
OF T
RANS
MIS
SION
SYS
TEM
EXP
ANSI
ON P
ROGR
AM (C
ontin
ued)
(PDP
2007
: Rev
ision
2)
Items
Name
of Tr
ansmi
ssion
Lines
Lengt
hNu
mber
Voltag
eCo
nducto
rCo
mmiss
ioning
an d(km
)of
(kV)
Size
Date
Subst
ations
Circui
t(M
CM)
(Year
)
D
) Pow
er Ge
neratio
n Supp
ly Co
., Ltd.
(Gas)
, Non
Saeng
2.2.8
Sect
ionaliz
ing of
Tha T
ako - W
ang No
i Doub
le-cir
cuit
0.14
5004x7
95201
3
t
o Pha
Chi 2
Subst
ation
(2 Ro
utes)
to b
e Tha
Tako
- Pha
Chi 2
- Wang
Noi
2.2.9
Cons
tructin
g from
Pha C
hi 2 -
Powe
r Plan
t1
2500
4x795
2013
2.2.10
Sect
ionaliz
ing of
Tha T
ako - N
ong Ch
ok Sin
gle-ci
rcuit
51
5004x7
95201
3
t
o Pha
Chi 2
Subst
ation
to b
e Tha
Tako
- Pha
Chi 2
Singl
e-circ
uit
2.2
.11 Co
nstruc
tion o
f Pha
Chi 2
- (Ph
a Chi
2 Junc
tion)
-21
2500
4x1272
2013
Wang
Noi Ju
nction
Doubl
e-circ
uit
Subto
tal
95.6
km (o
r 130.
6 circ
uit-ki
lomete
rs) an
d 3 ne
w subs
tations
2.
3 50
0 kV
Tran
smiss
ion Sy
stem
Proje
ct for
Upp
er N
orth
ern A
rea
2.3.1
Mae
Moh 5
- Chia
ng Ma
i 4145
2500
4x1272
2018
Subto
tal
145.
0 km
(or 29
0.0 cir
cuit-k
ilome
ters) a
nd 2 n
ew su
bstatio
ns
To
tal
1,510.
0 km
(or 3,2
45.4 c
ircuit
-kilom
eters)
and 1
4 new
subst
ations
Notes
: 1/
New S
ubstati
on
1/1/
1 /
