Executive Summary
Electricity Supply
Business Plan
PT PLN (Persero) 2013 - 2022
PURPOSE AND SCOPE RUPTL
1
BUSINESS GROWTH AND CURRENT CONDITIONS OF ELECTRICITY SUPPLY
1
SHORT-TERM RESPONSE EFFORTS
2
AVAILABILITY OF PRIMARY ENERGY
2
POWER SYSTEM PLANNING POLICY AND DESIGN CRITERIA
2
POWER DEMAND FORECAST
3
PLANS FOR ADDITIONAL POWER GENERATION
4
CO2 EMISSION PROJECTION
6
CARBON FINANCE PROJECT
7
DEVELOPMENT PLAN FOR TRANSMISSION AND SUBSTATION
7
INVESTMENT NEEDS
9
JAVA-BALI SYSTEM DEVELOPMENT PLAN
9
SUMATERA SYSTEM DEVELOPMENT PLAN
15
WEST KALIMANTAN SYSTEM DEVELOPMENT PLAN
19
SOUTH, CENTRAL AND EAST KALIMANTAN SYSTEM DEVELOPMENT PLAN
22
NORTH SULAWESI SYSTEM DEVELOPMENT PLAN
26
SOUTH SULAWESI SYSTEM DEVELOPMENT PLAN
27
DEVELOPMENT PLAN FOR NEW AND RENEWABLE ENERGY
31
DEVELOPMENT PLAN FOR ISOLATED POWER SYSTEMS
32
RISK ANALYSIS
32
CONCLUSION
33
Executive Summary Electricity Supply Business Plan 2013 - 2022
2013 - 2022
CONTENTS
iii
PURPOSE AND SCOPE RUPTL
e Electricity Supply Business Plan (RUPTL) by PT PLN (Persero) for the period 2013 - 2022 has been issued
to fulfill the mandate of the Government Regulation No.14/2012 on Power Supply Operations and to serve as
guidance for the development of power infrastructure to meet electricity demand within PLN business areas
in an efficient and well-planned manner, in order to prevent inefficiencies from starting at the planning stage.
RUPTL covers electricity demand load forecasts, generation capacity expansion plans and the development
plans related to transmission, substations and distribution. Projected electricity demand has been prepared
for each province and electricity system, including the electricity systems in remote islands across the region.
Development plans for generating capacity, transmission and substation are also for their respective projects.
Electricity demand forecasts are prepared to project the electricity needed to support economic growth targeted by the government and to take into consideration population growth.
e development of generation capacity has been planned to meet the growing demand for electricity, reserve
margin and to the extent possible, based on the principle of lowest cost. Utilization of local energy sources is
also prioritized, especially renewable energy such as geothermal and hydropower. Several projects have been
confirmed as undertaken as a PLN project or independent power producer (IPP) project, whilst some projects
have not been designated as either a PLN or IPP project. is is intended for PLN to decide a later stage, with
the approval of the Government, whether a project is implemented as a PLN or IPP project.
e development of the transmission system is planned to strike a balance between generation capacity and
power requirements efficiently to meet certain reliability and quality criteria. In electricity systems as large as
Sumatera and Java, an extra high voltage transmission line has been planned for the transmission system, to
form the backbone of the electrical system.
BUSINESS GROWTH AND CURRENT CONDITIONS OFELECTRICITY SUPPLY
e electricity landscape by September 2013 can be described as follows: As of September 2013 the installed
capacity of PLN power plants and IPPs in Indonesia was 40,533 MW, consisting of 31,815 MW in Java-Bali
and 8,718 MW in Sumatera and East Indonesia, excluding 2,933 MW of rental generating units. Generating
capacity in Sumatera and East Indonesia is barely sufficient to meet the electricity needs of the community,
but there can be a shortfall when there is disruption to the power supply or a plant needs to undergo routine
maintenance. For example, the electricity system of North Sumatera operates for almost the whole year
without backup operation and often faces shortfalls in electricity supply, resulting in the operation of many
liquid fuel generating plants. e South Sumatera system also experiences a similar issue, suffering from
shortfalls in electricity supply for most of the year. is situation also occurs in several other areas, such as
East Kalimantan, South Kalimantan, Southeast Sulawesi, Minahasa-Gorontalo, Palu, Lombok, Ambon, Ternate
and Jayapura. Smaller deficits are also observed in other smaller electricity systems. In Java and Bali, there is
enough generating capacity to meet the power requirements. However, certain operational issues were faced
in 2012, such as insufficient gas supply for PLN’s power plants, over-loading of many transformers, as well as
the increasing transfer of power from Central Java/East Java to West Java, which resulted in voltage in the
system transmission during peak-load periods.
Executive Summary Electricity Supply Business Plan 2013 - 2022
2013 - 2022
In the last five years, between 2008 and 2012, PLN’s business has continued to grow. Electricity sales increased from 128 TWh in 2008 to 172 TWh in 2012, the number of customers increased from 39 million in
2008 to 50 million in 2012 and the electrification ratio increased from 62.3% in 2008 to 75.9% in 2012.
1
SHORT-TERM RESPONSE EFFORTS
e problems in electricity supply that need to be addressed are an urgent need to meet electricity demand in
areas that lack electricity supply, replacing oil-fired plants with a non-petroleum fuels and to electrify regions
where there is no supply of electricity.
Certain actions that have been taken in West and East Indonesia, including rental of generation capacity,
purchase of electricity from small-scale IPPs, partnership/co-operation with local governments, purchase of
excess power, acceleration of the development of coal-fired power plants as stipulated in PR71/2006, building of transmission lines, securing continuity of primary energy supply and installation of solar power plants.
Short-term measures in the Java - Bali system include acceleration of the procurement of 150/20 kV transformer and 500/150 kV interbus, adding generating capacity in Bali, accelerating the commissioning of submarine cables in Java-Bali 150 kV circuits 3 and 4 and installing shunt capacitors in the Jakarta system to improve
voltage levels.
AVAILABILITY OF PRIMARY ENERGY
Coal resources of 120 billion tonnes and reserves of 28 billion tonnes in Indonesia are the basis for the planning of the development of coal power plants, both coastal power plants using coal at market prices, as well
as mine-mouth power plants using low-rank coal at cost price plus a margin.
For natural gas, although Indonesia has large reserves amounting to 165 TSCF, in reality there is insufficient
gas available for power generation. In fact, the supply of gas to the existing power plants has been and will
be declining such that a deficit in gas supply is expected if there is no new gas supply. In the year 2012, the
LNG FSRU plant in Jakarta commenced supply of LNG to power plants in Jakarta during peak load periods. e
price of gas in LNG form is relatively high and is only economically viable if used for generation at peak load.
Faced with such a gas supply situation, the RUPTL only plans for 2 units of 800 MW Combined cycle gas-fired
power plant classes, with the expectation that one unit will received gas supply from the Cepu block, while the
gas supply for the other unit is to be determined. LNG for power generation will also be developed in Arun,
which will supply peaking power plants in Arun and Pangkalan Brandan and existing power plants in Belawan.
Continuing on the topic of gas, the RUPTL plans a smaller number of peaking power plants that will utilize
LNG or CNG in East Indonesia. e base load requirements will be met by the planned development of coal
fired power plants, while gas supplies will be used for peaking power plants wherever possible, to avoid the
use of oil.
A large number of plants utilizing renewable energy on large scale, such geothermal and hydro powers, have
also been planned in the RUPTL.
POWER SYSTEM PLANNING POLICY AND DESIGN CRITERIA
RUPTL
Interconnection System
2
Power system planning is optimized from an economic perspective, with the objective of achieving a configuration of the development of plants which provide the lowest total NPV of the electricity supply cost, while
still meeting certain reliability criteria. e cheapest configuration is obtained through an optimization process
or objective function that includes capital costs, fuel costs, operation and maintenance costs and the cost of
energy not served. Simulation and optimization is done by using a model called WASP (Wien Automatic System Planning).
e reliability criteria used in the planning process is a Loss of Load Probability (LOLP) which is less than 1
day per year. is means the probability of peak loads exceeding available generating capacity is less than
Executive Summary Electricity Supply Business Plan 2013 - 2022
0.274%. Calculation of generation capacity based on the LOLP produces a reserve margin, which depends on
the generation unit size, availability factor of each unit, number of units and type of units.
In the Java-Bali system, the LOLP of < 0.274% is equivalent to a reserve margin of ≥ 25 - 30% of net generation capacity. When expressed in terms of installed capacity, the reserve margin required is approximately
35%.
For East Indonesia and West Indonesia, the reserve margin is set at about 40%, in view of a smaller number
of generating units, a larger unit size relative to peak load, a higher level of de-rating and a higher growth rate
compared to Java Bali.
As part of the optimization process, renewable energy generation capacity, particularly geothermal and hydropower, is treated as a ‘fixed system’ (permitted to enter the grid with no economic optimization required) at
the time the project is put into commercial operation.
Small Non-Interconnected/Isolated Systems
Power generation planning for isolated small systems do not apply probabilistic methods and the economic
optimization process, but use the deterministic method. In this method, the planning was based on a N-2 criteria, i.e. the minimum reserve must be greater than the two largest generation units. e reserve is defined
as the difference between the total generation capacity of existing power plants and peak load.
Transmission Planning Criteria
e transmission planning is carried out using both a static and dynamic reliability criteria N-1. e static N-1
criteria requires that when there is an outage in a transmission circuit due to a disruption or maintenance, then
the remaining transmission circuits must be able to distribute the overall load, so the continuity of electrical
power supply is maintained. e dynamic N-1 criteria requires that in the event of a three-phase short-circuit,
followed by the loss of a transmission circuit, then there should not be a loss of synchronization between that
group of generators and other groups of generators.
Generally, the criteria applied in the RUPTL is that there is a need for additional transformer capacity when the
loading of the transformer reaches 70% - 80%.
Between 2013 and 2022, electricity consumption in Indonesia is expected to increase from 189 TWh to 386
TWh, with an average growth of 8.4% per year, as shown in Figure-1. e number of costumers is projected
to increase from 54 million to 77 million by 2022, an increase of 2.7 million per annum. e additional customers will increase the electrification ratio from 79.6% to 97.7%. Regionally, the electricity demand in Java-Bali
is expected to increase from 144 TWh to 275 TWh, growing at a rate of 7.6% per annum. Demand in East
Indonesia is expected to grow more rapidly, increasing from 18 TWh to 46 TWh, a growth rate of 11.2% per
annum, while demand in Sumatera is expected to grow from 26 TWh to 66 TWh, a growth rate of 10.6% per
annum.
Figure-2 shows that in the Java-Bali system, industrial customers account for the largest portion of total consumption, an average of 38.5% of total sales. In East Indonesia and Sumatera, the proportion of consumption
by industrial customers is relatively smaller, at 11% and 15.8% respectively. By 2022, residential customers
would dominate sales, accounting for 62% of sales in East Indonesia and 55 % in Sumatera.
Executive Summary Electricity Supply Business Plan 2013 - 2022
2013 - 2022
POWER DEMAND FORECAST
3
Figure-1. Map of Power Demand Growth in Indonesia through Year 2022
300,000
450,000
Indonesia
Jawa-Bali
400,000
250,000
350,000
200,000
300,000
Industrial
250,000
Industrial
150,000
200,000
Public
150,000
Public
100,000
Business
Business
100,000
50,000
Residenal
50,000
Residenal
-
2013
2014
2015
2016
2017
2018
2019
2020
2021
2022
2013
2014
2015
2016
2017
2018
2019
2020
2021
2022
2019
2020
2021
2022
Indonesia
50,000
70,000
Sumatera
Eastern Indonesia
45,000
60,000
40,000
50,000
35,000
30,000
40,000
Industrial
Public
Business
30,000
Industrial
Public
Business
25,000
20,000
15,000
20,000
Residenal
Residenal
10,000
10,000
5,000
-
2013
2014
2015
2016
2017
2018
2019
2020
2021
2022
2013
2014
2015
2016
2017
2018
RUPTL
Figure-2. Power Demand Growth Composition by Customer Group in Indonesia Regions (GWh)
4
PLANS FOR ADDITIONAL POWER GENERATION
To meet the growing power demand, an additional generating capacity of 59.5 GW for the whole of Indonesia
is required, an average growth rate of 6 GW per annum, as shown in Figure-3. e RUPTL plans for PLN and
IPPs to develop 16.9 GW and 25.5 GW of capacity respectively, with the remaining 17.1 GW currently unallocated, i.e. projects where developers and funding sources have not been established.
Executive Summary Electricity Supply Business Plan 2013 - 2022
12.000
Unallocated
10.000
IPP
2.555
PLN
8.000
2.689
6.000
3.435
1.026
6.838
2.084
4.000
314
2.518
6.410
96
729
2.000
1.391
1.506
3.948
2.013
2014
1.535
2.919
2.908
2.003
1.869
1.244
1.234
2013
3.274
1.954
2.003
878
2015
2016
2017
2018
55
90
2019
2020
2021
2022
Figure-3. Additional Generation Capacity Requirement (MW)
Figure-4 shows the additional generation capacity required, by plant type. New coal-fired power plants will
dominate the additional generation capacity to be developed, accounting for 37.9 GW, or 63.8% of the planned
additional capacity. Planned combined cycle gas-fired power plants amount to 5 GW of capacity, or 8.4 %. For
renewable energy, the largest planned additional capacity relates to hydropower at 6.5 GW, or 11.0% of the
total additional capacity, followed by geothermal at 6.0 GW, or 10.2%. Of this planned additional capacity,
around 16.6 GW will be in West Indonesia and around 11.5 GW in East Indonesia. In West Indonesia, there is a
510 MW hydroelectric project Batang Toru to be developed by the private sector, and in East Indonesia there
is also a 450 MW hydropower project Karama which will be developed by the private sector. For the Java - Bali
system, additional power is about 31.5 GW, or an average of 3.2 GW per year, including 353 MW of mini-hydro
and 50 MW of wind turbine power plants.
12,000
10,627
10,000
9,154
8,000
6,053
5,948
6,000
5,449
5,348
3,786
4,000
2,838
2,831
2,000
2013
2014
CFPP
2015
HEPP
2016
GeoPP
2017
2018
CCPP
GT/GEPP
2019
2020
2021
2022
Others
Figure-4. Additional Generation Capacity by Plant Type (MW)
e energy mix for power generation in 2022 for Indonesia is projected to be 65.6% coal, 16.6% natural gas
(including LNG), 11.0% geothermal, 5.1% hydroelectric and 1.7% oil and other fuels as shown in Figure-5.
Executive Summary Electricity Supply Business Plan 2013 - 2022
2013 - 2022
7,473
5
500,000
450,000
400,000
350,000
GWh
300,000
250,000
200,000
150,000
100,000
50,000
2013
Import
2014
Biomass
2015
2016
Solar/Wind/Hybrid
2017
HSD
MFO
2018
LNG
2019
Gas
2020
Coal
2021
Geothermal
2022
Hydro
Figure-5. Projected Electricity Production by Fuel Type for Indonesia
Table-1 shows the energy mix for Indonesia from 2013 to 2022.
Table-1. Projected Primary Energy Requirement
No,
Fuel Type
2013
2014
2015
2016
2017
2018
2019
2020
2021
2022
1
HSD ( x 10^3 kl )
6,679
6,007
4,711
3,414
2,651
1,740
1,812
1,757
1,862
2,019
2
MFO ( x 10^3 kl )
1,267
1,238
1,599
1,544
1,185
183
191
190
194
212
3
Gas (bcf)
387
396
412
447
448
400
366
357
354
375
4
LNG (bcf)
92
87
119
147
174
242
244
245
258
269
5
Batubara (10^6 ton)
59
71
83
94
106
114
120
131
143
151
6
Biomass (10^3 ton)
1
80
286
474
693
738
745
752
761
770
CO2 EMISSION PROJECTION
RUPTL
System planning process in RUPTL 2013 - 2022 doesn‘t take into account the CO2 emissions cost as one of
variable costs. However, this doesn’t mean that RUPTL ignoring the CO2 emissions reduction. It can be seen
from the number of geothermal and hydropower power plants candidate set into the electrical system even
though they are not the lowest cost solution. e use of supercritical boiler technology and ultra supercritical
in Java also prove that PLN concerned with the efforts to reduce CO2 emissions from power generation.
6
e amount of emissions is calculated from the amount of fuel used and converted into CO2 emissions (in
tonnes of CO2 ) by using a multiplier factor (emission factor) issued by the IPCC (Intergovernmental Panel on
Climate Change ).
Figure 6 shows the CO2 emissions that would be generated with electricity production and fuel mix as shown
in Figure 5. From Figure 6 it can be seen that CO2 emissions in Indonesia will increase from 165 million tons
in 2013 to 339 million tonnes by 2022. Of the 339 million tons of emissions, 294 million tons (87%) comes
from burning coal.
Executive Summary Electricity Supply Business Plan 2013 - 2022
Million tCO2
350
300
250
200
150
100
50
0
2013
2014
2015
Biomass
2016
HSD
2017
MFO
2018
LNG
2019
2020
Gas
2021
2022
Coal
Figure-6. CO2 Emission per Fuel Type (Indonesia)
Average grid emission factor for Indonesia in 2013 was 0.766 kgCO2/kWh, will increase to 0.846 kgCO2/kWh
in 2017 and will further decline due to the operation of geothermal and hydro projects so that the average grid
emission factor in 2022 became 0.773 kgCO2/kWh.
CARBON FINANCE PROJECT
PLN will utilize carbon finance opportunities through the UNFCCC or outside the UNFCCC framework. Carbon
finance project implementation will be applied to all activities within the PLN, which has the potential to obtain
carbon finance.
Since the expiration of the first commitment of the Kyoto Protocol by the end of 2012, the use of carbon
finance will be adjusted to the new carbon financing mechanisms, both within and outside the UNFCCC framework of the UNFCCC.
DEVELOPMENT PLAN FOR TRANSMISSION AND SUBSTATION
e planned development of the transmission system for the period 2013 - 2022 includes the development
of the transmission system with a voltage of 500 kV and 150 kV in the Java-Bali system, and systems with
voltage of 500 kV, 275 kV, 150 kV and 70 kV in East Indonesia and West Indonesia. Generally, the construction of the transmission system looks to achieve compatibility between the upstream generation capacity and
the downstream portion of the power demand in an efficient manner. In addition, it also looks to overcome
bottlenecks and improve service voltage.
e development of 500 kV transmission lines in Java is generally intended to transmit power from new and
expansion plants and to maintain the N-1 reliability criterion, whether static or dynamic. On the other hand,
the development of 150 kV transmission lines is intended to maintain the N-1 reliability criterion and the associated transmission, in relation to the new 150 kV substations.
Executive Summary Electricity Supply Business Plan 2013 - 2022
2013 - 2022
Since the year 2002 PLN is aware of funding opportunities of carbon through the Clean Development Mechanism (CDM) and do some assessment of potential CDM projects, and results to date PLN has signed several
ERPA (Emission Reduction Purchase Agreements). In addition PLN also develop projects through the VCM
(Voluntary Carbon Mechanism).
7
14.000
12.000
10.000
8.000
6.000
4.000
2.000
2013
2014
70 kV
2015
150 kV
2016
2017
250 kV DC
2018
275 kV
2019
500 kV DC
2020
2021
2022
500 kV AC
Figure-7. Requirement for Development of Transmission Lines by Voltage (kms)
25.000
20.000
15.000
10.000
5.000
2013
2014
70/20 kV
275/150 kV
2015
2016
2017
150/20 kV
500 kV DC
2018
2019
150/70 kV
500/150 kV
2020
2021
2022
250 kV DC
500/275 kV
RUPTL
Figure-8. Requirement for Development of Substations and Transformers by Voltage (MVA)
8
e development of 500 kV transmission line in Sumatera is intended to form the backbone of the transmission system, bringing together the interconnections in the eastern corridor of Sumatera. Large-scale power
plants and load centers in Sumatera will be connected to this 500 kV transmission system. is transmission
system also will transmit power from regions with rich and inexpensive primary energy sources (e.g. Sumbagseland Riau) to regions which lack an affordable primary energy source (e.g. Sumbagut). In addition, a 500 kV
transmission line will also be developed in South Sumatera as a feeder electricity supply from the mine mouth
power plants to the converter station for the HVDC transmission line, which will connect Sumatera and Java.
Executive Summary Electricity Supply Business Plan 2013 - 2022
e development plan for the transmission system in Indonesia by 2022 involves a projected 57,132 kms and
134,435 MVA of substation and transformer as shown in Figure-7 and Figure-8.
INVESTMENT NEEDS
e development of generation, transmission and distribution infrastructure requires an investment of
US$71.1billion for PLN projects alone and a total of US$125.2 billion when combined with the power projects
expected to be implemented by the private sector/IPPs, with annual disbursements as shown in the Figure-9.
20.0
PLN power plant :
IPP power plant :
Transmission
:
Distribution
:
18.0
16.0
14.0
Total PLN
Total PLN+IPP
12.0
US$
US$
US$
US$
37,2 billion
54,1 billion
19,4 billion
14,5 billion
: US$ 71,1 billion
: US$125,2 billion
10.0
8.0
6.0
4.0
2.0
2013
2014
2015
2016
2017
2018
2019
2020
2021
Total Investment PLN
Total Investment PLN+IPP
Power Plant PLN+IPP
Transmission
Distribuon
Power Plant PLN
2022
To date, many PLN projects have been financed through loans obtained from overseas (two-step loan). However, since 2006 the role of this kind of financing has begun to decline and financing by issuing bonds (both
local and global) has been increasing. e 10,000 MW Fast Track project was fully financed by loans to PLN,
backed by a guarantee from the Government. Lately, PLN has once again tried to obtain loans from multilateral
and bilateral financial institutions to fund power projects, such as the Upper Cisokan pumped storage and the
Sumatera-Java HVDC transmission line.
JAVA - BALI SYSTEM DEVELOPMENT PLAN
e additional generation capacity to be developed over the period of 2013 - 2022 for the Java - Bali system is
31.5 GW, or an average increase in capacity of 3.2 GW per year, including small-scale mini-hydro power plants
of 353 MW and wind power plants of 50 MW. e capacity of PLN will increase by as many as 8.3 GW, or 26%
of the total planned additional capacity. Private sector participation represents a large proportion of the total
planned additional capacity, i.e. 15.6 GW, or 50%, while unallocated projects amount to 7.5 GW, or 24%. Of the
types of power generation, coal-fired power plants will represent the majority of additional capacity to be developed, at 22.6 GW, or 71.8%, followed by combined cycle gas-fired power plants with a total capacity of 3.2
GW, or 10.0% and gas-fired plants with total capacity of 0.2 GW, or 0.7 %. As for renewable energy, additional
capacity consists of geothermal at 2.8 GW, or 8.9%, hydro electric at 2.6 GW, or 8.4%, and other plants of 0.05
GW, or 0.2%. e breakdown of power generation development in the Java-Bali system is shown in Table-2.
Executive Summary Electricity Supply Business Plan 2013 - 2022
2013 - 2022
Figure-9. Investment requirement for the development of electricity
9
Table-2. Power Generation Development Plan in the Java - Bali System
PROJECTS
Energy Sales
Growth
Energy Production
Load Factor
GWh
%
GWh
2014
2015
157,183
170,232
2016
183,486
2017
2018
197,293
211,527
2019
2020
226,314
2021
241,805
2022
257,968
274,850
8.8
9.1
8.3
7.8
7.5
7.2
7.0
6.8
6.7
6.5
163,501
178,009
192,714
207,605
223,336
239,235
255,816
273,475
292,238
312,111
78.4
78.5
78.6
78.7
78.8
78.9
79.0
79.1
79.2
79.3
MW
23,801
25,880
27,982
30,106
32,346
34,605
36,957
39,458
42,112
44,919
Net Capacity
MW
29,053
29,028
29,028
29,028
29,028
29,028
27,997
27,997
27,997
27,997
Installed Capacity
MW
30,285
30,261
30,261
30,261
30,261
30,261
29,229
29,229
29,229
29,229
PLN
MW
24,625
24,601
24,601
24,601
24,601
24,601
23,569
23,569
23,569
23,569
-200
-25
0
0
0
0
-1031
0
0
0
MW
5,660
5,660
5,660
5,660
5,660
5,660
5,660
5,660
5,660
5,660
350
Gross Peak Load
%
2013
144,010
GENERATION
CAPACITY
Retired/Mothballed
IPP
PLN On-going and
Committed
Pelabuhan Ratu
CFPP
700
Pacitan
CFPP
630
Tj. Awar-awar
CFPP
350
Adipala
CFPP
Indramayu #4 (FTP2)
CFPP
Upper Cisokan PS
(FTP2)
HEPP
Sub Total PLN Ongoing & Committed
MW
350
660
1,000
1,040
1,680
1,360
-
130
250
-
1,040
-
-
-
-
1,000
IPP On-going and
Committed
Celukan Bawang
CFPP
Banten
CFPP
Sumsel-8 MT
CFPP
1,200
Sumsel-9 MT (PPP)
CFPP
600
Sumsel-10 MT (PPP)
CFPP
600
Cilacap exp
CFPP
Madura 2x200 MW
(FTP2)
CFPP
Jawa Tengah (PPP)
CFPP
Rajamandala (FTP2)
HEPP
Patuha (FTP2)
GeoPP
Kamojang-5 (FTP2)
GeoPP
600
614
400
950
950
47
55
110
30
Karaha Bodas (FTP2)
GeoPP
Tangkuban Perahu 1
(FTP2)
GeoPP
Ijen (FTP2)
GeoPP
Iyang Argopuro (FTP2)
GeoPP
Wilis/Ngebel (FTP2)
GeoPP
110
Cibuni (FTP2)
GeoPP
10
Tangkuban Perahu 2
(FTP2)
GeoPP
Cisolok - Cisukarame
(FTP2)
GeoPP
Ungaran (FTP2)
30
110
110
110
55
50
GeoPP
55
GeoPP
220
Dieng (FTP2)
GeoPP
Tampomas (FTP2)
GeoPP
45
Baturaden (FTP2)
GeoPP
220
Guci (FTP2)
GeoPP
55
Rawa Dano (FTP2)
GeoPP
110
RUPTL
55
60
Wayang Windu (FTP2)
115
Umbul Telomoyo (FTP2)
GeoPP
55
Gn. Ciremai (FTP2)
GeoPP
110
Gn. Endut (FTP2)
GeoPP
55
Sub Total IPP On-going
& Committed
10
625
MW
-
185
280
Executive Summary Electricity Supply Business Plan 2013 - 2022
1,269
272
3,350
2,815
110
220
400
Table-2. Power Generation Development Plan in the Java - Bali System
continued
PROYEK
2013
2014
2015
2016
2017
2018
2019
2020
2021
2022
PLANNED ADDITIONAL CAPACITY
Jawa-1 (Load Follower)
CCPP
Jawa-2 (Load Follower)
CCPP
Muara Tawar Add-on
Blok 2,3,4
CCPP
Muara Karang Peaker
CCPP
Grati Peaker
CCPP
800
800
650
450
300
50
150
Pesanggaran Peaker
GEPP
Karangkates #4-5
HEPP
150
100
Kesamben
HEPP
37
Kalikonto-2
HEPP
Jatigede (FTP2)
HEPP
Matenggeng PS
HEPP
Indramayu #5
CFPP
Lontar Exp #4
CFPP
Jawa-1 (FTP2)
CFPP
Jawa-3 (FTP2)
CFPP
660
660
Jawa-4 (FTP2)
CFPP
1,000
1,000
Jawa-5 (FTP2)
CFPP
1,000
1,000
Jawa-6 (FTP2)
CFPP
Jawa-7
CFPP
1,000
1,000
62
110
450
450
1,000
315
1,000
2,000
Iyang Argopuro
GeoPP
220
Cisolok - Cisukarame
GeoPP
110
Ungaran
GeoPP
140
Dieng
GeoPP
110
Bedugul
GeoPP
Gn. Lawu
GeoPP
10
165
Arjuno Welirang
GeoPP
110
MW
-
50
450
600
1,225
2,450
3,869
4,110
2,450
1,855
Total Additional
Capacity
MW
1,680
1,595
730
1,869
2,537
5,800
6,684
4,220
2,670
3,255
TOTAL INSTALLED
CAPACITY
MW
31,965
33,536
34,266
36,135
38,672
44,472
50,124
54,344
57,014
60,269
TOTAL NET CAPACITY
MW
30,733
32,303
33,033
34,902
37,439
43,239
48,892
53,112
55,782
59,037
e breakdown of the planned development for Java - Bali power system above indicates that the net reserve
margin varies between 16 - 36%, with the lowest reserve margin occurring in 2015 (18%), 2016 (16%) and
2017 (16%), due to delays some IPP projects such as Sumsel 8 coal-fired power plant (2x600MW), Central Java
coal-fired power plant (2x950 MW), Madura coal-fired power plant (2x200 MW), Java-1 coal-fired power plant
(1x1,000 MW), Java-3 coal-fired power plant (2x660 MW) as well as some geothermal power plants amounting
to 400 MW. In anticipation of lower reserve margins in 2015 to 2017, steps have been taken to address the
issue.
e Muara Karang combined cycle gas-fired power plant (450 MW), Grati combined cycle gas-fired power plant
(450 MW), Pesanggaran gas engine power plant (200 MW) and Java-1combined cycle gas-fired power plant
(800 MW) and coal-fired IPPs such as Celukan Bawang power plant (380 MW), Banten power plant (625 MW)
and Cilacap expansion (600 MW) should be operational over the period 2014 - 2017, to ensure that the reserve margin is maintained and does not decline.
Plants that undergo changes are as follows: (i) Changes in plant type and unit size: Muara Karang open
cycle gas-fired power plant (400 MW) to Muara Karang combined cycle gas-fired power plant (450 MW) and
the Grati open cycle gas-fired power plant (300 MW) to Grati combined cycle gas-fired power plant (450 MW),
as combined cycle gas-fired power plants are more efficient and are able to operate on a daily start-stop basis
as a peaker plant, (ii) Capacity of Java-1 and Java-2 combined cycle gas-fired power plants to increase from
750 MW to 800 MW, to keep abreast of the latest technology that is more efficient, (iii) Changes in location:
Executive Summary Electricity Supply Business Plan 2013 - 2022
2013 - 2022
Sub Total Planned
Additional Capacity
11
Location of Java-6 coal-fired power plant from Bojonegara to Karawang, (iv) Addition of new planned generating capacity: Java-7 coal-fired power plant (2x1,000 MW), (v) plants removed from the RUPTL: Semarang open
cycle gas-fired power plant (150 MW) as the period of validity of the loan had expired and was not renewed,
and Kamojang 6 geothermal plant (60 MW) in view of the results of the study of the PGE reservoir show that
it is not possible to develop the Kamojang 6 geothermal power plant, but only to develop the Kamojang 5
geothermal power plant (30 MW).
e locations of coal-fired power plants and combined cycle gas-fired power plants are subject to change in
accordance with developments in project preparation, including the availability of gas supply.
BANTEN
SRLYA
~ ~~ PLTU
MTWAR
PLTU 4x1.000 MW
2x1.000 MW
CLGON
PRIOK
MKRNG
DKSBI
BKASI
KMBNG
BRAJA
CWANG
TMBUN
GNDUL
XBOGOR
CBTUBRU
IDRMYU
CBATU
PLTU 2x1.000 MW
TJATI B
CIBNG
DEPOK
PLTU 1x1.000 MW
CRATA
CSKAN PS
SGLNG
BDSLN
MDCAN
PLTU 2x660 MW
JATENG IPP
GRSIK
UNGAR
UJBRG
NGBNG
PMLNG
CGRLNG
TANDES
SBBRT
TASIK
RWALO
CLCAP IPP ADIPALA
PEDAN
SBSLN
GRATI
SOLO
PITON
KDIRI
BANGIL
NEW ANTOSARI
Legend:
~
Existing Power Plant in 500 kV
Planned Power Plant in 500 kV
Existing 500 kV S/S
Planned 500 kV S/S
Existing 500 kV EHV
Planned 500 kV EHV
Figure-10. Plans for Strengthening 500 kV Transmission in Java – Bali
e development of the 500 kV transmission in Java is generally intended to evacuate power from new and
expansion power plants, to maintain both the static and dynamic N-1 security criterion,while the development
of the 150 kV transmission is intended to maintain the N-1 security criterion and the transmission associated
with the new 150 kV substation.
RUPTL
e plans for development of the 500 kV transmissions in Java-Bali are shown in Figure-10. Considering the
development of EHV transmission lines and HV transmission lines are often delayed due to licensing, ROW
and social issues, as well as the urgent need for additional power, there is a need for PLN to take steps to
increase transmission capacity soon. e development of EHV transmission line using the new route would
take a long time, while the reconductoring of several sections of the 500 kV and 150 kV transmissions would
take a shorter time.
12
Construction of the 500 kV transmission is intended to evacuate power from large-scale coal-fired power
plants such as Adipala, Indramayu 4 and 5, Central Java, Java-1, Java-3, Java-4, Java-5, Java-6, Java-7, JavaBali Crossing to transfer from Paiton to the load center in Bali, pumped storage hydropower Upper Cisokan
and Matenggeng, as well as several other new plants.
e 500 kV EHV transmission lines to undergo reconductoring are New Suralaya-Bojonegara-Balaraja (2018)
and Old Suralaya-Balaraja-Gandul (2019).
e new 500 kV transmission development plan for EHV transmission lines includes Tanjung Jati B-PemalangIndramayu - Cibatu, Balaraja - Kembangan - Duri Kosambi and Duri Kosambi - Muara Karang - Muara Tawar forming looping EHV transmission lines in North Jakarta, to strengthen and improve the reliability and flexibility of
the system operation in Jakarta. A 500 kV HVDC transmission interconnection between Sumatera-Java will also
be built, to distribute power from the mine mouth power plants in South Sumatera to the load centers in Java.
Executive Summary Electricity Supply Business Plan 2013 - 2022
PLTU LONTAR
3 x 300 MW
TELUK
TNAGA
MKRNG
KAPUK
TNAGA II
JAKARTA
PRIOK
SPTAN
SPTAN II
ANCOL
MKRNG III
TGBRU II
SOETA
PSKMS
TGRNG III
GNSRI
MGBSR II
ANGKE
TGBRU
BNTEN
KBJRK
NewOld
NSYAN II
DNYSA II
DNYSA
PCRAN2
Old
PDKLP
TMRSD
CIKRNG
MRT
LKONG II
BNTRO II
CSW III/
Psmede
KMANG
PDNDH
BKSPWR
TMBUN II
TMBUN
CWANGBR
PDNDH II
LKONG
JTWRG
CWANG
DRTGA
PTKNG
CSENG
FAJAR
PNCOL II
PNCOL
MPANG
CSW CSW II
LEGOKLKONG
KSBRU
PGDGSTEEL
AGP
SNYAN
NSYAN
PWRSTEL
TGRSA
BKASI II
SKTNI
BKASI
KESA
AGP IISMBRT
KMBNG
CITRA
STBDI
PGLNG
PGDNG
PLMAS
MGRAICIPNG II
CIPNG
KARET
CBTUBR
BKASIUTRA
PGSAN
DKTAS
GBLMA-2
DKTASII
CLDK
PGLNG II
PKRNG
GPOLA
BDKMY
SMBRT II
TGRSA II
KDSPI
GMBRU
GRGOL II
LIPP
O
LIPP ALMSTRA
O II
LAUTS
MRNDA
JGC
KLPGD
TTNGI
GBLMA
KBSRH
Old
MLNIUM
HVDC
KMYRN II
DRKSB
JTAKE
TGRNG
SPINML
MGBSR
KTPNG
New
BLRJA
PLPNG
HRPDH
GRGOL
CKRNG
MAXIM
CKNDE
KDSPI II
KMYRN
DMGOT
RWBUAYA
CKUPA
PLTU 4x1.000 MW
MTWAR
PLNDOB
PLNDOA
MKRNG
SPTAN III
JBEKA
TMBUN
RJPKSI
MNTUR
GDMKR
CBATU
LKONG III/BSD
RGNAN
BNTRO
SRPNG
JTNGN
BNTRO III
GDRIA
GNDUL
DPBRU
JTNGNII/
CBBUR
CBATU
LEGEND :
EXISTING 500 KV S/S
NEW 500 KV S/S
EXISTING 150 KV S/S
NEW 150 KV EXISTING
NEW 150 KV S/S FOR HV CUSTOMER
EXISTING 70 KV S/S
DEPOK III
CLGSI II/
JONGGOL
CMGIS II
ASPEK
CMGIS
CIBNG
CLGSI
BGORX
CIBNG II
CLGON
SNTUL
TSMYA
SCBNG
SGLNG
ITP
BGBRU
KDBDK
Figure-11. Plans for Strengthening of 500 kV Transmission in Jakarta
Figure-12. Projected composition of Electricity Production by fuel type in Java - Bali
Executive Summary Electricity Supply Business Plan 2013 - 2022
2013 - 2022
To strengthen the system supply in Jakarta, construction has been planned for a EHV transmission line for the
Duri Kosambi - Muara Karang - Priok - Muara Tawar section (looping EHV transmission line for north Jakarta
route) as shown in Figure-11. e new EHV transmission line will also improve the reliability and flexibility of
operation of the power systems in Jakarta and Bekasi.
13
Figure-12 shows that coal will be the main primary energy used, representing 70% of all production in 2022,
followed by natural gas (including LNG) 17%, geothermal 9%, hydro 3% and fuel oil in very small proportions
(1%). e proportion of fuel oil utilized in 2013 was about 3.5% but will decrease to very low levels by 2022.
is decrease can be achieved if alternative fuels are available at levels as planned and fullest efforts are made
to reduce electricity production costs. Contribution of natural gas will decline from 21% in 2013 to 10% in
2022 due to no certain additional gas supply expected to materialize. e contribution of LNG is relatively stable at around 6-7% until the year 2022, to operate peaking power plants and ‘must run’ plants. Contribution
by geothermal energy was only 5% in 2013 and will rise to 9% by 2022.
Table-3 shows the gas supply based on current contracts. From Table-3 it shows that the supply of gas for the
next 10 years is likely to decline, especially for Priok, Muara Karang, Muara Tawar, Gresik and Grati. Tambak
Lorok and Pesanggaran (Bali) have been using fuel oil to-date and they are expected to obtain gas supplies
from new sources. Demand for gas for power generation in Java-Bali is shown in Table-4. In the coming years,
there will be additional planned gas-fired generating capacity as follows: Pesanggaran gas engine power plant
200 MW (2015), Grati combined cycle gas-fired peaker plant 450 MW (2015/16), Muara Karang combined
cycle gas-fired peaker plant 450 MW (2016), Java-1 combined cycle gas-fired power plant (in Gresik) 800 MW
(2017), which is expected to receive gas supply from the Cepu block; as well as Java-2 combined cycle gasfired power plant (alternative in Grati) 800 MW (2018), which has yet to establish its gas supply.
Table-3. Gas Supply Situation for Java - Bali Power Generation
bbtud
No
Power Plant
1
Muara Karang and
Priok
2
Muara Tawar
Supplier
PHE ONWJ (GSA)
PGN - Priok (GSA-IP)
2013
100
2014
2015
110
110
30
30
30
-
-
-
-
136
136
136
229
229
197
197
Total
276
276
166
229
229
197
197
41
41
41
322
347
316
PERTAMINA - P Tengah (GSA)
25
25
25
PGN (GSA)
79
41
41
MEDCO Ex-Keramasan/SCS Field
20
17
35
25
25
26
RUPTL
25
26
30
30
30
30
30
30
5
3
179
182
134
92
92
96
56
30
30
CNOOC (GSA)
80
80
80
80
80
80
80
80
80
80
PGN (GSA)
30
30
30
30
30
30
30
30
30
30
40
110
110
110
110
110
110
110
110
110
110
PCML
-
-
48
116
116
116
116
89
70
70
SPP (GSA-IP)
-
50
50
50
50
50
50
50
50
50
Total
-
50
98
166
166
166
166
139
120
120
123
98
104
83
64
49
89
87
78
75
72
70
70
69
69
69
130
130
60
60
60
60
53
50
43
43
PHE WMO ex-Kodeco
Media Karya Sentosa
11
Wali Nusa Energi
17
12
12
12
4
4
12
43
51
19
9
-
-
-
-
-
25
25
17
10
-
-
-
-
100
100
100
100
100
100
370
339
322
306
336
302
223
219
212
212
Santos Oyong (GSA-IP)
40
40
40
Santos Wortel (GSA-IP)
30
30
30
20
14
1
Sampang Mandiri Perkasa (GSA-IP)
17
17
17
17
17
17
Petronas-Bukit Tua (Potential)
14
21
30
35
Kangean Energy Indonesia
7
21
30
30
Hess (GSA)
Santos Peluang Field (Contract Process)
Exxon/Pertamina Cepu Block (Potential)
Total
Grati
Pasuruan Migas (GSA-IP)
Total
Pesanggaran
2022
30
Total
6
2021
176
Total
Gresik
2020
30
Swap Premier (Potential)
5
2019
207
Swap Program FSRU West Java (Potential)
Tambaklorok
2018
110
30
Additional from PHE (Potential)
4
2017
192
SWAP JOB Jambi Merang
Cilegon
110
FSRU PT NR (GSA)
MEDCO Lematang/Singa Field
3
2016
3
3
3
3
3
3
90
90
90
40
34
21
-
-
-
-
30
30
20
20
-
-
-
-
Sengkang LNG (Potential)
Total
Total Gas Supply for Power Plants in Jawa - Bali
Executive Summary Electricity Supply Business Plan 2013 - 2022
-
-
30
30
20
20
-
-
-
-
1,071
1,118
1,101
1,019
1,034
881
783
727
668
668
From Table-4, there could be a shortage of gas supply to some power plants due to the decline in the supply
of gas for the next 10 years. To prevent this, there must be a follow-up to extend existing gas contracts and
to seek new sources of gas.
Table-4. Gas Balance for Power Plants in Java - Bali
bbtud
No.
1
Power Plant
2013
2014
2016
2017
164
150
140
127
124
Gas Demand
168
Gas Supply
140
197
176
169
163
140
140
140
110
LNG Supply
192
207
176
136
0
0
0
Gas Demand
179
182
Gas Supply
179
182
0
Gas Demand
Gas Supply
Muara Karang 1)
MW
Tanjung Priok
Muara Tawar 2)
Gresik 3)
2020
2021
2022
122
123
122
124
122
159
157
156
181
205
136
136
229
229
197
197
-20
-42
-145
-51
-49
-109
-131
179
201
201
202
160
162
164
159
134
92
92
96
56
30
30
30
0
-45
-110
-109
-106
-104
-132
-134
-129
301
290
284
269
242
236
236
237
240
245
301
290
284
269
208
174
103
100
93
93
0
-34
-63
-134
-137
-147
-152
2,662
Surplus-Deficit
4
2019
1,923
Surplus-Deficit
3
2,979
Surplus-Deficit
5
Tambak Lorok
1,234
Gas Demand
50
98
166
166
166
166
139
120
120
Gas Supply
50
98
166
166
166
166
139
120
120
0
0
0
0
0
0
0
0
0
161
161
164
174
-161
-161
-164
-174
Surplus-Deficit
6
4
Grati )
2,014
Gas Demand
90
90
90
96
89
160
Gas Supply
90
90
90
40
34
21
-56
-55
-139
Surplus-Deficit
7
2018
2,077
Gas Demand
2
2015
Cilegon
0
740
Gas Demand
110
110
110
110
110
110
110
110
110
110
Gas Supply
110
110
110
110
110
110
110
110
110
110
20
20
20
20
-20
-20
-20
-20
1,133
1,107
1,123
1,156
Surplus-Deficit
Pesanggaran
250
Gas Demand
30
30
20
20
Gas Supply
30
30
20
20
Surplus-Deficit
9
Total Jawa-Bali
Gas Demand
1,012
1,069
1,108
Gas Supply
- 1,012
1,069
1,063
982
876
723
663
608
549
549
Surplus/Deficit
-
0
-45
-186
-240
-453
-470
-499
-574
-607
0
1,168
1,116
1,176
Note:
1) Includes Muara Karang combined cycle gas-fired power plant 450 MW
2) Includes Muara Tawar Add-on Blocks 2,3,4 combined cycle gas-fired power plant 650 MW
3) Includes Java-1 combined cycle gas-fired power plant 800 MW
4) Includes Java-2 combined cycle gas-fired power plant 800 MW
SUMATERA SYSTEM DEVELOPMENT PLAN
Table-5 shows the power supply and demand balance of the Sumatera power system. e power system in
Sumatera is planned to achieve a reserve margin of 65% by 2022, which is lower than the reserve margin in
the RUPTL 2012 - 2021, which had planned to achieve a reserve margin of 70% in 2018. Potential burden on
Sumatera could be higher than planned. With reserve margins that are high enough, it is possible to accommodate such potential high loads. However, if the reserve margin is lower than 40 %, it would be necessary
to control the load.
Executive Summary Electricity Supply Business Plan 2013 - 2022
2013 - 2022
8
15
e new power plant development plan on Sumatera system includes the following: Sumut-1 coal-fired power plant
300 MW (COD 2017); Sumut-2 coal-fired power plant 2x300 MW (2020/2021); Sumbagsel-1mine mouth coalfired power plant 2x150 MW (2018/2019); Bengkulu coal-fired power plant 2x100 MW (2019); Sumbagut-2 gas
turbine/engine power plant 250 MW peaker (2018) Sumbagut-3 gas turbine/engine power plant 250 MW (2018);
Sumbagut-4 gas turbine/engine power plant 250 MW (2018); and Meurebo-2 hydropower 59 MW (2020).
Table-5. Power Generation Development Plan in Sumatera
Projects
Unit
2013
2014
2015
2016
2017
2018
2019
2020
2021
2022
GWh
28,935
31,603
34,918
70
69
69
38,562
42,599
47,047
52,981
57,456
63,539
70,312
69
70
70
71
72
72
MW
4,742
5,227
5,770
73
6,316
6,912
7,561
8,288
9,288
9,916
10,961
Installed Capacity
MW
5,722
5,607
5,492
4,832
4,542
4,384
4,384
4,384
4,384
4,384
Net Capacity
MW
4,711
4,672
4,542
4,019
3,849
3,742
3,742
3,742
3,742
3,742
PLN
MW
3,126
3,093
3,093
2,960
2,795
2,773
2,773
2,773
2,773
2,773
Rental
MW
728
728
688
298
293
208
208
208
208
208
IPP
MW
857
851
761
761
761
761
761
761
761
761
Retired & Mothballed (PLN)
MW
90
33
-
133
166
22
-
-
-
-
200
200
55
55
Demand
Energy Production
Load Factor
Gross Peak Load
%
Supply
Additional Capacity
PLN ON-GOING & COMMITTED
Tarahan (FTP1)
CFPP
Meulaboh (Nagan Raya) #1,2 (FTP1)
CFPP
110
110
Teluk Sirih #1,2 (FTP1)
CFPP
112
112
Pangkalan Susu #1,2 (FTP1)
CFPP
Riau (FTP1 Amandment)
CFPP
Pangkalan Susu #3,4 (FTP2)
CFPP
Sungai Gelam (CNG/Peaker)
GEPP
92
GEPP
112
Duri
Arun (Peaker)
200
220
220
GT/GEPP
Batanghari
CCPP
Keramasan
CCPP
Hululais (FTP2)
GeoPP
Sungai Penuh (FTP2)
GeoPP
Peusangan 1-2
HEPP
Asahan III (FTP2)
HEPP
Masang-2 (FTP2)
HEPP
220
200
30
80
88
174
55
RENTAL
Dumai
CFPP
240
Lampung (Sribawono + Sutami)
GT/GEPP
200
Payo Selincah
GT/GEPP
50
Tanjung Jabung Timur
GT/GEPP
-200
-50
100
-100
ADDITIONAL RENTAL
(Diesel/GT/GEPP)
Sumbagut
MW
165
265
-175
Sumbagselteng
MW
50
80
-130
-255
IPP ON-GOING & COMMITTED
CFPP
230
Keban Agung
CFPP
225
Sumsel - 5
CFPP
RUPTL
Banjarsari
16
Sumsel - 7
CFPP
Riau Kemitraan (PLN-TNB-PTBA)
CFPP
Jambi
CFPP
Gunung Megang, ST Cycle
CCPP
150
150
150
150
1,200
400
400
30
110
GeoPP
GeoPP
Sarulla I (FTP2)
GeoPP
110
220
Muara Laboh (FTP2)
GeoPP
110
110
Rantau Dadap (FTP2)
GeoPP
Sorik Marapi (FTP2)
GeoPP
Seulawah Agam (FTP2)
GeoPP
55
55
Rajabasa (FTP2)
GeoPP
110
110
Suoh Sekincau (FTP2)
GeoPP
110
110
Sipoholon Ria-Ria (FTP2)
GeoPP
Executive Summary Electricity Supply Business Plan 2013 - 2022
55
55
Lumut Balai (FTP2)
Ulubelu #3,4 (FTP2)
55
55
110
110
80
160
55
Table-5. Power Generation Development Plan in Sumatera
continued
Projects
Unit
2013
2014
2015
2016
2017
2018
2019
2020
2021
2022
Wai Ratai (FTP2)
GeoPP
55
Sarulla II (FTP2)
GeoPP
110
Simbolon Samosir (FTP2)
GeoPP
110
Danau Ranau (FTP2)
GeoPP
110
Bonjol (FTP2)
GeoPP
Scattered Sumut MHPP
MHPP
Wampu (FTP2)
HEPP
Semangka (FTP2)
HEPP
Hasang (FTP2)
HEPP
Merangin
HEPP
Peusangan-4 (FTP2)
HEPP
Batang Toru (Tapsel)
HEPP
165
25
25
46
45
56
40
350
83
510
PLANNED ADDITIONAL CAPACITY
Meulaboh (Nagan Raya) #3,4
CFPP
Sumut-1
CFPP
Sumut-2
CFPP
300
300
Sumsel-1 MT
CFPP
300
300
Sumsel-6 MT
CFPP
CFPP
Bengkulu
CFPP
Banyuasin
CFPP
Aceh
GTPP
Riau
300
150
300
150
200
230
25
CCPP
Lampung Peaker
200
50
GT/GEPP
200
Jambi Peaker
GT/GEPP
100
Riau Peaker
GT/GEPP
200
Sumbagut-1 Peaker
CCPP/MGU
250
Sumbagut-2 Peaker (Arun)
CCPP/MGU
250
Sumbagut-3 Peaker (Medan)
CCPP/MGU
250
Sumbagut-4 Peaker (Medan)
CCPP/MGU
250
G, Talang
GeoPP
Kepahiyang
GeoPP
Simonggo-2
HEPP
Meureubo-2
HEPP
Ketahun-3
HEPP
Kumbih-3
HEPP
42
Sibundong-4
HEPP
32
Total Additional Capacity
Total Installed Capacity
Total Net Capacity
HEPP
MW
MW
MW
20
220
90
59
61
667
1,801
990
666
819
2,699
1,275
1,887
1,330
1,840
6,389
8,075
8,950
9,956
10,485
12,471
13,701
15,588
16,918
18,758
5,378
7,140
8,000
9,143
9,732
11,829
13,059
14,946
16,276
18,116
e development of transmission lines in Sumatera will form the transmission backbone 500 kV interconnection system that unites the corridors of Sumatera in the east. e centers of large-scale generation and load
centers in Sumatera will be connected to this 500 kV transmission system. is transmission also will transfer
electricity from power plants in the areas with adequate cheap primary energy source (Sumbagsel and Riau) to
areas which lack a primary energy source (Sumbagut). e addition of 500 kV transmission is also developed
in South Sumatera as a feeder supplier of electricity from the mine mouth coal fired power plant to the HVDC
transmission converter station which will connect the islands of Sumatera and Java.
e development plan in RUPTL 2013 - 2022 for the transmission system will see significant change to the
network topology with the establishment of the 275 kV and 500 kV interconnection system in Sumatera. e
development is also done to meet the growing demand in the form of additional transformer capacity. Development to improve the reliability and debottlenecking which is also planned in some systems, such as the
plan to build a second circuit and reconductoring several sections in the Sumbagsel and Sumbagut transmission systems.e plan for a 275 kV interconnection in Sumatera is programmed to be implemented entirely in
2017. In addition some substations and 150 kV transmission are being constructed to take over the load of
diesel generators to interconnected systems.
Executive Summary Electricity Supply Business Plan 2013 - 2022
2013 - 2022
Sumbagsel-1 MT
200
300
17
e development plan of the power system in Sumatera is shown in Figure-13.
22
21
2017
20
2017
24
1
2
No
1
2
3
4
5
6
7
8
9
10
11
12
13
14
16
17
18
19
20
21
22
23
26
27
28
25
2017
GI 275 kV
Sigli
Meulaboh
Lhokseumawe
Sarulla
Payakumbuh
Kiliranjao
Muara Bungo
Bangko
Lubuk Linggau
Lahat
Gumawang
Muara Enim
Betung
New Aur Duri
New G. Sak2015
P. Sidempuan
Simangkok
Galang
Binjai
Pangkalan Susu
Ulee Kareeng
Rantau Prapat
Lumut Balai
Sungai Lilin
Lampung
18
3
23
COD
2016
2016
2016
2015
2015
2015
2015
2015
2015
2015
2014
2016
2015
2015
19
17
2018
2014
16
2018 2020
15
4
2015
2016
2016
14
2018
2015
2016
27
5
13
2018
6
2015
7
2017
8
2017
2014
2013
2013
2013
2016
2018
2014
2015
2018
12
2016
11
2014
No
12
14
15
16
23
24
25
GI 500 kV
Muara Enim
New Aur Duri
Rengat
New G. Sak2016
Rantau Prapat
Medan (S.Rotan)
Kuala Tanjung
2014
COD
2016
2016
2016
9
10
2018
28
26
2018
2018
2018
Figure-13. Development Plan of Transmission System in Sumatera
e projected fuel mix for electricity production in Sumatera in 2022 would be 49% coal, 17% natural gas,
11% hydro, 1% oil and 22% geothermal as shown in Figure-14.
80,000
70,000
60,000
GWh
50,000
40,000
RUPTL
30,000
18
20,000
10,000
2013
2014
Import
2015
Biomass
2016
HSD
2017
MFO
2018
LNG
Gas
2019
Coal
2020
Geothermal
2021
2022
Hydro
Figure-14. Projected Composition of Electricity Production by Fuel Type in Sumatera
Executive Summary Electricity Supply Business Plan 2013 - 2022
Fuel requirements in Sumatera from 2013 to 2022 are presented in Table-6, and plans for the supply to gas
power plant in Sumatera are presented in Table-7.
Table-6. Fuel Requirement in Sumatera
No.
Fuel Type
2013
2014
2015
2016
2017
2018
2019
2020
2021
2022
1
HSD ( x 10^3 kl )
2,846.8
2,444.0
1,454.6
843.9
765.4
185.7
180.5
174.3
174.9
170.3
2
MFO ( x 10^3 kl )
393.0
294.6
328.1
190.8
105.9
9.5
10.0
10.5
-
-
3
Gas (bcf)
67.1
74.8
79.5
93.2
95.4
93.6
77.9
78.9
80.9
82.3
4
LNG (bcf)
1.0
1.5
17.1
35.8
29.0
46.5
54.3
54.2
53.5
55.1
5
Coal (10^6 ton)
4.6
6.8
9.8
11.6
12.7
13.9
15.7
18.3
20.3
20.9
6
Biomass (10^3 ton)
0.7
79.9
285.8
474.1
693.1
738.3
744.8
752.2
760.7
770.2
Table-7. Gas Supply for Power Plants in Sumatera
No
1
Power Plant
Supplier
Aceh Timur
Medco Blok A
Belawan, P. Pasir,
Kambuna
2
Sumbagut-1 dan
FSRU LNG Tangguh
Arun
PEP Benggala
3
Teluk Lembu
Kalila Bentu
4
PLTMG Rawa Minyak Bengkalis
Petroselat Rawa Minyak
(Potensi)*
5
PLTG sewa Jabung
Petro China (Potensi)
Sungai Gelam
PEP - TAC (Own Operation)
Payo Selincah,
PEP - TAC Sungai Gelam
Simpang Tuan
Perusda Jambi
6
7
8
9
2013
2014
2015
2016
2017
2018
2019
2020
2021
2022
-
-
-
-
5.0
5.0
5.0
5.0
5.0
5.0
-
-
-
-
-
-
-
-
5.0
-
-
-
47.5
92.1
92.1
92.1
92.1
92.1
92.1
92.1
2.0
2.0
2.0
2.0
-
-
-
-
-
-
30.0
30.0
30.0
30.0
30.0
30.0
30.0
30.0
30.0
30.0
-
2.0
5.0
5.0
5.0
5.0
5.0
-
5.0
5.0
5.0
5.0
5.0
5.0
2.0
2.0
2.0
2.0
2.0
-
-
-
-
-
2.5
2.5
2.5
2.5
2.5
-
-
-
-
-
2.5
2.5
2.5
2.5
2.5
-
Payo Selincah,
Energasindo
14.0
14.0
14.0
14.0
14.0
14.0
-
-
-
Batanghari
Jambi Merang
20.0
20.0
18.0
16.0
14.0
14.0
14.0
-
-
-
Jakabaring (CNG)
PDPDE Sumsel
3.0
3.0
3.0
3.0
3.0
3.0
3.0
3.0
-
-
21.0
10.0
17.0
-
-
-
-
-
-
-
8.0
8.0
8.0
8.0
8.0
8.0
8.0
-
-
-
Indralaya
Medco E&P Indonesia
Talang Duku
PGN
12
Borang
Medco E&P Indonesia
18.0
18.0
-
-
-
-
-
-
-
-
13
Keramasan
Medco E&P Indonesia
15.0
-
-
-
-
-
-
-
-
-
Pertamina EP
15.0
15.0
15.0
-
-
-
-
-
-
-
Medco E & P Indonesia
15.0
15.0
15.0
15.0
15.0
15.0
-
-
-
-
Borang
Pertamina EP (Asri Gita)
31.0
31.0
31.0
31.0
31.0
-
-
-
-
-
PLTMG Duri, Duri
Relokasi, Riau
Peaker
Jambi Merang
25.0
26.0
30.0
30.0
30.0
27.0
27.0
-
-
-
14
15
Gunung Megang
16
PLTGU Duri
Jambi Merang
-
-
16.0
16.0
16.0
16.0
16.0
-
-
17
Rengat
Jambi Merang
3.0
3.0
3.0
3.0
3.0
3.0
3.0
-
-
18
Lampung Peaker
FSRU Lampung (Potensi)
-
-
12.5
12.5
12.5
12.5
12.5
12.5
19
Lampung Sewa
PGN (Potensi)
Total
-
38.0
38.0
38.0
38.0
38.0
-
-
-
232.0
247.0
304.5
327.6
328.6
287.6
220.6
142.6
139.6
2013 - 2022
10
11
-
-
12.5
-
139.6
WEST KALIMANTAN SYSTEM DEVELOPMENT PLAN
e current installed capacity in West Kalimantan is 335 MW (including rental capacity) which all plants are
using fuel oil, so operating costs are very high. Additional generation capacity in West Kalimantan is still in the
planning stage, with the exception of Fast Track Phase 1 – Parit Baru (2x50 MW) and Kura-kura (2x25 MW)
coal-fired power plants are under construction and expected to be operational by 2015.
PLN and Sarawak Electricity Company (SESCO) have signed a Power Exchange agreement (PEA) which sets
out plans for PLN to purchase electricity to supply West Kalimantan from Sarawak for 50 MW flat (as baseload) and at peak load PLN can purchase up to 230 MW, starting from early 2015 until 2019. In the long term
Executive Summary Electricity Supply Business Plan 2013 - 2022
19
it is possible that such purchase of electricity from Sarawak will only be during peak loads. is will enable PLN
to defer the need for peaking plants which run on expensive fuel. However, to avoid excessive dependence
on electricity supply from Sarawak, the construction of a gas turbine/engine power plant of 100 MW in 2017
has been planned.
e power supply and demand balance of the West Kalimantan system (Table-8) indicates that the reserve
margin will reach 51% by 2020. is situation is still acceptable considering that coal-fired power plant projects in West Kalimantan are at a risk of delays for various reasons andthere is no take-or-pay clause at peak
periods in the Sarawak interconnection.
Table-8. Power Generation Development Plan in West Kalimantan
Projects
2013
2014
2015
2016
2017
2018
2019
2020
2021
2022
1,371
1,632
1,855
2,373
2,907
3,302
3,675
4,088
4,544
5,040
67
67
66
66
66
66
66
66
67
67
MW
234
280
319
413
506
575
636
703
776
856
Installed Capacity
MW
335
434
136
79
131
139
139
139
139
139
Net Capacity
MW
270
360
123
71
119
126
126
126
126
126
PLN
MW
105
105
30
30
30
30
30
30
30
30
GTPP-HSD PLN (Siantan)
MW
30
30
30
30
30
30
30
30
30
30
Diesel-MFO PLN (Sei Raya
& Siantan)
MW
61
61
-
-
-
-
-
-
-
-
Diesel-MFO PLN (Sei Wie
& Sudirman)
MW
14
14
-
-
-
-
-
-
-
-
MW
-
-
-
41
89
96
96
96
96
96
Rental
MW
164
254
93
-
-
-
-
-
-
-
Retired & Mothballed (PLN)
MW
-
-
75
-
-
-
-
-
-
-
100
100
200
200
Demand
Energy Production
Load Factor
Peak Load
GWh
%
Supply
Interconnected isolated
system
Additional Capacity
PLN ON-GOING AND
COMMITTED
Pantai Kura-Kura (FTP1)
CFPP
55
Parit Baru (FTP1)
CFPP
100
Parit Baru (FTP2)
CFPP
100
IPP ON-GOING AND
COMMITTED
PLANNED ADDITIONAL
CAPACITY
Kalbar - 1
CFPP
Kalbar - 2 (new proposal)
CFPP
Peaker
GT/GEPP
Nanga Pinoh*)
HEPP
Pade Kembayung
HEPP
Power Purchase dgn SESCo
100
98
30
275 KV
180
275 KV
50
(Peaking)
RUPTL
Power Purchase dgn SESCo
20
-50
(Baseload)
Total Additional Capacity
MW
0
0
385
100
200
100
0
150
200
128
Total Installed Capacity
MW
335
434
471
514
766
874
874
1,074
1,274
1,402
Total Net Capacity
MW
270
360
508
556
804
911
911
1,061
1,261
1,389
Interconnection with Sesco can be extended, but only for peaking, after Kalbar-2 coal fired power plant in operation
Executive Summary Electricity Supply Business Plan 2013 - 2022
Development plans for the transmission network in West Kalimantan up to the year 2022 amount to 2,812
km, which include: construction of a new 150 kV transmission line associated with the Fast Track coal-fired
plants, coal-fired IPP and hydro projects. Development of the existing 150 kV transmission line to scattered
locations in West Kalimantan systems is also planned in order to meet the reliability criteria (N-1) and to
overcome bottlenecks in delivery, improve voltage and operational flexibility. Construction of 275 kV West
Kalimantan - Sarawak transmission interconnection will reap economic benefits of the energy exchange when
there is a marginal cost difference between the two systems. e development of the interconnection is also
useful as a contingency in the event that the construction of new plants is delayed. West Kalimantan system
development plan is shown in Figure-15.
SARAWAK
(MALAYSIA)
ARUK
BIAWAK
SERIKIN
SAMBAS
2013
KUCHING
Ke GITET
Matang
JAGOI
BABANG
PLTU P. Baru (FTP2)
2x50 MW – 2016
BATU KAYA
U
SINGKAWANG
PLTU P. Kura-Kura (FTP1)
2x27,5 MW – 2015
PLTG/MG Peaker
100 MW – 2017
PUTUSSIBAU
2020
BADAU
ENTIKONG
BENGKAYANG
2014
PLTA Pade Kembayung
3x10 MW – 2022
U
PARIT BARU
U
G
KOTA BARU
2015
SEI RAYA
SANGGAU
2016
TAYAN
2013
SIANTAN
PLTU Sintang
3x7 MW – 2015
A
NGABANG
2014
55 km
MEMPAWAH
PLTU P. Baru (FTP1)
2x50 MW – 2015
KALIMANTAN
TIMUR
TEBEDU
U
U
SINTANG
2016
U
GB
A
PLTU Sanggau
2x7 MW – 2013 /14
NANGA PINOH
2018
PLTU Kalbar -1
2x100 MW – 2018/19
KALIMANTAN
TENGAH
GI. K0TA BARU
2019
PLTU Kalbar -2
2x200 MW – 2020/21
PLTGB Sewa Tayan
6 MW – 2013
PLTA Nanga Pinoh
2x49 MW – 2022
SEKADAU
2016
SUKADANA
2017
SANDAI
2017
ke
Kalteng
PERENCANAAN SISTEM
PLTU Ketapang
2x10 MW – 2016
PT PLN (Persero )
KETAPANG
2017
96 km
PLTU IPP Ketapang
2x6 MW – 2016
U
KENDAWANGAN
2020
PETA JARINGAN
PROPINSI KALIMANTAN BARAT
/
/
/
/
/
/
/
/
GI
GI
GI
GI
500 kV Existing
275 kV Existing
150 kV Existing
70 kV Existing /
GI
GI
GI
GI
500/275 kV Existing / Rencana
500/275 /150 kV Existing / Rencana
275/150 kV Existing / Rencana
150/70 kV Existing / Rencana
/
/
/
/
T/L
T/L
T/L
T/L
70
150
275
500
/ Rencana
/ Rencana
/ Rencana
Rencana
kV Existing
kV Existing
kV Existing
kV Existing
/
/
/
/
Rencana
Rencana
Rencana
Rencana
U
G
P
A
/
/
/
/
U
G
P
A
GU / GU
MG /MG
M /M
D / D
PLTU Existing
PLTG Existing
PLTP Existing
PLTA Existing
/ Rencana
/ Rencana
/ Rencana
/ Rencana
PLT GU Existing / Rencana
PLTMG Existing / Rencana
PLT M Existing / Rencana
PLT D Existing / Rencana
Kit Existing
Kit Rencana
Edit Desember 201 3
KALIMANTAN
SELATAN
e fuel mix for electricity production in West Kalimantan is presented in Figure-16. e role of each primary
energy can be explained as follows: (i) in 2013, because of the lack of new power generation capacity besides
fuel oil, electricity production using fuel oil reached 1,498 GWh. In line with the operation of coal-fired power
plant and imports of electricity from Sarawak, the use of fuel oil as the primary fuel in the West Kalimantan
power system can be further reduced; (ii) Hydro power resources are found in the Nanga Pinoh area, so a 98
MW Nanga Pinoh hydropower plant has been planned, to be operational by 2022; (iii) ere are also plans
to ship LNG from Batam to West Kalimantan, which will be used to supply peaker plants 100 MW with gas
demands of 5 bbtud.
Executive Summary Electricity Supply Business Plan 2013 - 2022
2013 - 2022
Figure-15. Transmission System Development Plan in West Kalimantan
21
6.000
5.000
GWh
4.000
3.000
2.000
1.000
2013
2014
Import
2015
HSD
2016
MFO
2017
LNG
2018
Gas
2019
Coal
2020
Geothermal
2021
2022
Hydro
Figure-16. Projected composition of Power Generationby Fuel Type in West Kalimantan
SOUTH, CENTRAL, NORTH AND EAST KALIMANTAN SYSTEM DEVELOPMENT
PLAN
e South-Central Kalimantan (Kalselteng) system and North - East Kalimantan (Kaltimra) system have suffered
power supply shortages for many years. To improve the power shortage situation, PLN has introduced both
short-term and long-term solutions. Short-term solutions involve rental of diesel engine generating units, while
long-term solutions involve the planning and development of a number of coal fired power plants, gas fired
power plants and hydroelectric power plants. In reality, however, many of these power generating projects have
faced problems and as such, project completions have been delayed from the initial schedule. As a result, the
additional power generated from the short-term solution (rental of diesel engine units) has not been able to sufficiently improve the power shortage situation, due to the rapid growth of demand for power. In addition, maintenance of existing power plant machinery could not be carried out as planned because these plants have to be
operated continuously. Also, some potential customers with high power demand could not be served.
RUPTL
Currently, the power generation capacity of PLN and IPP power plants, including rental diesel engine units and
excess power, in the South, Central, North and East regions of Kalimantan (Kalseltengtimra) is 815 MW, with
peak load at 847 MW, excluding the Asam-asam coal fired power plant units 3 and 4, which are expected to be
operational in 2013. In addition, the portion of power generation plants operating on oil fuel in Kalseltengtimra
is still high, hence the power generation cost remains high.
22
A large number of additional power plants have been planned in anticipation of project delays. is is reflected
in the power balance of the Kalseltengtimra system, where the annual reserve margin is 33% to 53%, other
than in 2015, when the reserve margin is only 22% of the net available capacity. Reserve margins are estimated to be highest in 2019 if all projects are completed on time. However, based on PLN’s experience to
date, the success rate of power generation projects is relatively low, particularly in Kalimantan. e steam
turbine IPP project, which had been planned to be operational by 2012 - 2014, has been delayed by one year.
PLN Muara Jawa/Teluk Balikpapan coal fired power plant (FTP1) is estimated to be delayed by one year, while
Pulang Pisau coal fired power plant is estimated to be delayed by two years.
From the above, it can be seen that the reserve margin is relatively high (up to 53%). is is intended to provide
greater certainty to the people South Kalimantan, Central Kalimantan, East Kalimantan and North Kalimantan
that the electricity supply in these regions will be adequate.
Executive Summary Electricity Supply Business Plan 2013 - 2022
During the period 2013 - 2022, additional 2,957 MW of new generation capacity from both PLN and IPP has
been planned, including those already in the procurement process and under construction. e additional new
generation capacity comprises of coal fired power plants (1,925 MW), gas turbine/engine peaker plants (795
MW), hydroelectric plants (120 MW) and combined cycle gas turbine power plants (117 MW). Power generation
development plan in Kalseltengtimra is shown in Table-9.
Table-9. Power Generation Development Plan in Kalseltengtimra
PROJECTS
2013
2014
2015
2016
2017
2018
2019
2020
2021
2022
Kalselteng - Kaltim Interconnection 2016
Kalselteng-Kaltim-Kaltara Interconnection (2018)
Demand
Energy Production
5,154
6,304
7,744
8,495
9,376
10,545
11,390
12,277
13,178
%
69.5
69.5
69.8
69.7
70.8
71.2
71.5
71.6
71.8
71.9
MW
847
1,036
1,266
1,391
1,511
1,690
1,819
1,956
2,095
2,252
Installed Capacity
MW
970
969
862
682
335
390
390
390
390
390
Net Capacity
MW
815
814
708
527
299
354
354
354
354
354
PLN
388
394
400
400
238
272
272
272
272
272
IPP
428
420
308
128
61
82
82
82
82
82
21
-
-
-
143
-
-
-
-
-
Load Factor
Peak Load
GWh
14,190
Supply
Retired & Mothballed
Additional Capacity
PLN On Going & Committed
Pulang Pisau (FTP1)
CFPP
-
-
120
-
-
-
-
-
-
-
Asam Asam (FTP1)
CFPP
130
-
-
-
-
-
-
-
-
-
Bangkanai (FTP2)
Kaltim Peaking (APBN)
GT/GE/CCPP
GTPP
-
-
155
70
70
-
-
-
-
-
100
-
-
-
-
-
-
-
-
-
Muara Jawa/Teluk Balikpapan (FTP1)
CFPP
-
220
-
-
-
-
-
-
-
-
Sampit
CFPP
-
-
-
50
-
-
-
-
-
-
IPP On Going & Committed
Senipah
GTPP
82
-
-
-
-
-
-
Embalut (Expansion)
CFPP
-
50
-
-
-
-
-
-
-
-
Senipah (ST)
CCPP
-
-
-
-
35
-
-
-
-
-
Kalsel Peaker 1
GT/GE/CCPP
-
-
-
200
-
-
-
-
-
-
Kalsel Peaker 2
GT/GE/CCPP
-
-
-
-
-
-
-
-
50
-
Kaltim Peaker 2
GT/GE/CCPP
-
-
-
100
-
-
-
-
-
-
Kaltim Peaker 3
GT/GE/CCPP
-
-
-
-
-
-
-
-
50
-
Kelai
HEPP
-
-
-
-
-
-
-
-
-
55
Kusan
HEPP
-
-
-
-
-
-
-
-
-
65
Kalsel (FTP2)
CFPP
-
-
-
-
100
100
-
-
-
-
Kalselteng 1
CFPP
-
-
-
-
-
100
100
-
-
-
Kalselteng 2
CFPP
-
-
-
-
200
-
-
-
Kalselteng 3
CFPP
-
-
-
-
50
50
-
-
-
-
Kaltim (FTP2)
CFPP
-
-
-
-
100
100
-
-
-
-
Kaltim (Mine Mouth)
CFPP
-
-
-
-
-
55
-
-
-
-
Kaltim 3
CFPP
-
-
-
-
-
-
-
150
150
-
Kaltim 4
CFPP
-
-
-
-
-
100
-
-
-
-
Total Additional Capacity
MW
312
270
275
420
555
505
100
150
250
120
TOTAL INSTALLED CAPACITY
MW
1,282
1,551
1,719
1,959
2,167
2,727
2,827
2,977
3,227
3,347
TOTAL NET CAPACITY
MW
1,127
1,396
1,565
1,804
2,131
2,691
2,791
2,941
3,191
3,311
e development plan of the Kalseltengtimra 150 kV and 70 kV transmission system is intended to meet electricity demand growth and to connect isolated systems to the grid. e transmission system is also intended
to support regional development to ensure availability of power supply, given the establishment of the North
Kalimantan province, which will result in increasing electricity demand.
Executive Summary Electricity Supply Business Plan 2013 - 2022
2013 - 2022
Planned Additional Capacity
23
e transmission development plan in Kalseltengtimra in Figure-17 and Figure-18 include: Construction of a
new 150 kV transmission line related to accelerated coal fired power plants under the Fast Track 1 projects,
as well as accelerated coal and gas fired power plants under the Fast Track 2 projects, coal-fired and open
cycle gas-fired IPP projects, gas turbine/engine peaker plants, and hydroelectric plants; Development of 150
kV transmission in dispersed locations to connect isolated electrical systems, to overcome bottlenecks in the
electrical power distribution to meet reliability criteria (N-1), improve service voltage and increase operational
flexibility; Construction of 150 kV transmission systems associated with development of industrial estates as
directed in the MP3EI (Master Plan for Development of Economy and Industry) in East Kalimantan, i.e. from
Sangatta to the Maloi industrial zone; 150 kV transmission projects which are required and expected to be operational in due course include: the section connecting Tanjung (South Kalimantan) – Kuaro – Petung – Karangjoang (Kaltim) in 2016, to connect the Kalselteng and Kaltim systems; and the section connecting Bangkanai
gas turbine/engine plants – MuaraTeweh – Buntok – Tanjung in 2014,to connect the Bangkanai gas turbine/
engine plants to the Kalselteng system.
With the establishment of the North Kalimantan province, it is expected that the electricity demand in the next
few years will grow higher, especially in big cities: Tanjung Selor (the province’s capital) and Tana Tidung and
Malinau (regency capital cities). e North Kalimantan Interconnection System in Kalseltengtim is a 150 kV
transmission network connecting Muara Wahau – Tanjung Redep – Tanjung Selor and is expected to be ready
in 2018.
SYSTEM PLANNING
PT PLN (Persero)
SOUTH AND CENTRAL KALIMANTAN SYSTEM
/
/
/
/
/
/
/
/
/
/
/
/
SS 500 kV Existing / Plan
SS 275 kV Existing / Plan
SS 150 kV Existing / Plan
SS 70 kV Existing / Plan
SS 500/275 kV Existing / Plan
SS 500/275/150 kV Existing / Plan
SS 275/150 kV Existing / Plan
SS 150/70 kV Existing / Plan
T/L 70 kV Existing / Plan
T/L 150 kV Existing / Plan
T/L 275 kV Existing / Plan
T/L 500 kV Existing / Plan
CF
GT
GEO
H
CC
GE
MH
D
/ CF
/ GT
/ GEO
/ H
/
/
/
/
CC
GE
MH
D
2013
2
013
CFPP Existing / Plan
GTPP Existing / Plan
GEOPP Existing / Plan
HEPP Existing / Plan
CCPP Existing / Plan
GEPP Existing / Plan
MHPP Existing / Plan
Diesel PP Existing / Plan
PP Existing
PP Plan
Bangkanai GEPP 140 MW – 2015
Bangkanai GT/GE PP 2x70 MW – 2016/17
2015
2015
to
Melak SS
(East
Kalimantan)
Puruk Cahu
Edit November 2013
D
ACSR 2x240 mm2
96 km - 2016
ACSR 2x240 mm2 GE
47 km - 2015
2013
2013
2xZebra
50 km - 2014
Muara Teweh
D
Kuala Kurun
D
ACSR 2x240 mm2
110 km - 2014
Buntok
CF
2011
20
011
Pangkalan
Banteng
ACSR 1x240 mm2
172 km - 2014
ACSR 2x240 mm2
80 km - 2013
Sampit
ACSR 2x240 mm2
130 km - 2014
D
ACSR 2x240 mm2
65 km - 2013
Kasongan
Palangkaraya
Parenggean
Nangabulik
2012
2012
ACSR 2x240 mm2
120 km - 2016
Kalselteng 1 CFPP
2x100 MW – 2018/19
ACSR 2x240 mm2
142 km - 2013
2
2010
2
010
Tanjung
CF
Amuntai
D
CF
D
2012
2012
D
Kalsel CFPP (FTP 2)
2x100 MW – 2017/18
New
Palangkaraya
D
to
Kuaro SS
(East
Kalimantan)
CF
Sukamara
Pangkalan Bun
CF
CF
Sampit CFPP
2x25 MW – 2016
Pulang Pisau CFPP
2x60 MW – 2015
Selat
Rantau
Kayutangi
CF
Seberang
Barito
Trisakti
Mantuil
Kotabaru
RUPTL
2011
2
011
Riam Kanan HEPP
3x10 MW
Cempaka
Satui
Bandara
ACSR 2x240 mm2
124 km - 2013
Asam-Asam CFPP (FTP 1)
2x65 MW – 2013
Kalselteng 2 CFPP
200 MW – 2017
Batu Licin
H
H
Ulin
Pelaihari
Kuala Pambuang CFPP
2x3 MW - 2016
24
Kusan HEPP
65 MW – 2022
ACSR 1x240 mm2
69 km - 2022
Pangkalan Bun CFPP
2x7 MW
Kalselteng 3 CFPP
2x50 MW – 2018
Barikin
ACSR 2x240 mm2
120 km - 2015
CF
ACCC 460 mm2
37 km - 2015
Asam-Asam 1,2 CFPP
2x65 MW
CF
Figure-17. Transmission System Development Plan in South and Central Kalimantan
Executive Summary Electricity Supply Business Plan 2013 - 2022
SABAH (MALAYSIA)
BRUNEI DARUSSALAM
ACSR 2x240 mm2
26 km - 2017
Tidang Pale
Malinau
ACSR 2x240 mm
102 km – 2017
2
Tanjung Selor CFPP
2x7 MW – 2014
CF
Tj. Selor
GE
Tanjung Selor GEPP
15 MW – 2015
ACSR 2x240 mm2
80 km - 2015
SARAWAK
(MALAYSIA)
Tj. Redep
Lati CFPP
3x7 MW – 2015
CF
CF
Kelai HEPP
55 MW – 2022
Tanjung Redep CFPP
2x7 MW – 2014
H
Talisayan
ACSR 2x240 mm2
120 km - 2017
Muara Wahau
Maloi
ACSR 2x240 mm2
80 km - 2017
Sepaso
Embalut (Expansion) CFPP
1x50 MW – 2014
Kaltim 4 CFPP
100 MW – 2018
Sangatta
WEST
KALIMANTAN
SYSTEM PLANNING
PT PLN (Persero)
NORTH AND EAST KALIMANTAN SYSTEM
/
/
/
/
/
/
/
/
/
/
/
/
SS 500 kV Existing / Plan
SS 275 kV Existing / Plan
SS 150 kV Existing / Plan
SS 70 kV Existing / Plan
SS 500/275 kV Existing / Plan
SS 500/275/150 kV Existing / Plan
SS 275/150 kV Existing / Plan
SS 150/70 kV Existing / Plan
T/L 70 kV Existing / Plan
T/L 150 kV Existing / Plan
T/L 275 kV Existing / Plan
T/L 500 kV Existing / Plan
CF
GT
GEO
H
CC
GE
MH
D
/ CF
/ GT
/ GEO
/ H
/
/
/
/
CC
GE
MH
D
Kaltim CFPP (FTP2)
2x100 MW – 2017/18
G
CENTRAL
KALIMANTAN
Bontang
Kota Bangun
Melak
to Bangkanai
GT/GE PP
(Central
ACSR 2x240 mm2
Kalimantan) 100 km - 2015
New Smd
CF
CF
GT
Kaltim Peaking GTPP
2x50 MW – 2014
Sambera
Kaltim (Mine Mouth) CFPP
2x27.5 MW – 2018
Sambutan
Kaltim 3 CFPP
2x150 MW – 2020/21
Karangjoang CF
Sepaku
GT
CC
Kariangau
G Manggarsari
ACSR 2x240 mm2 CF
New Balikpapan
155 km - 2015
Industri
CFPP Existing / Plan
GTPP Existing / Plan
GEOPP Existing / Plan
HEPP Existing / Plan
CCPP Existing / Plan
GEPP Existing / Plan
MHPP Existing / Plan
Diesel PP Existing / Plan
PP Existing
PP Plan
Petung
Longikis
ACSR 2x240 mm2
47 km - 2015
Kuaro
Komam
To Tanjung SS
(South Kalimantan)
Edit November 2013
Kaltim Peaker 3 GT/GE PP
50 MW – 2021
Grogot
Senipah GTPP
2x41 MW – 2014
CENTRAL
SULAWESI
Senipah (ST) CCPP
35 MW – 2017
Kaltim Peaker 2 GT/GE/CC PP
100 MW – 2016
Muara Jawa/Teluk Balikpapan CFPP (FTP1)
2x110 MW – 2014
SOUTH
SULAWESI
SOUTH
KALIMANTAN
Figure-18. Transmission System Development Plan in North and East Kalimantan
Demand for High Speed Diesel (HSD) and Marine Fuel Oil (MFO) in the Kalseltengtimra system is expected
to trend downwards, from 598,000 kiloliters in 2013 to 69,000 kiloliters in 2022, while the use of coal will
increase from 1.5 million tons in 2013 to 6.5 million tons in 2022. e volume of gas utilization in the form of
CNG and LNG will also increase from 3 bcf in 2013 to 22 bcf in 2022. Electricity production from hydro-power
will also increase from 106 GWh in 2013 to 580 GWh in 2022.
Projected composition of power generation by fuel type in Kalseltengtimra is shown in Figure-19.
16,000
12,000
GWh
10,000
8,000
6,000
4,000
2,000
2013
2014
Solar/Hybrid
2015
HSD
2016
MFO
2017
LNG
2018
Gas
2019
2020
Coal
Geot
2021
2022
Hydro
Figure-19. Projected Composition of Power Generation by Fuel Type in Kalseltengtimra
Executive Summary Electricity Supply Business Plan 2013 - 2022
2013 - 2022
14,000
25
NORTH SULAWESI SYSTEM DEVELOPMENT PLAN
e planned additional new generating capacity in North Sulawesi is relatively large, as can be seen from the
annual reserve margin, which lies between 34% and 58%. A high reserve margin of 58% has been planned
due to uncertainty of completion of the Kotamobagu I and II geothermal power plants. In 2013 and 2014, the
reserve margin is relatively low. is is mainly due to delays to several projects, namely the Sulut 1 coal-fired
power plant, Minahasa combined cycle gas turbine or gas turbine/engine peaker plant, Lahendong V and VI
geothermal plants, which are behind the original schedule. e power generation plan for North Sulawesi is
shown in Table-10.
New power generation capacity planned during the period 2013 - 2022 is 1,087 MW, consisting of coal fired
power plants (675 MW), geothermal power plant (120MW), gas fired turbine/engine peaker with gas storage
(250 MW) and hydro-electric plants (44 MW).
Table-10. Power Generation Development Plan in Northern Sulawesi
Projects
2013
2014
2015
2016
Demand
2017
2018
2019
2020
2021
2022
Sulut - Gorontalo - Tolitoli Interconnection
(2016)
Energy production
GWh
1,777
2,000
2,182
2,536
2,787
3,075
3,391
3,740
4,119
65
65
66
65
65
66
66
66
66
67
MW
311
349
379
445
487
535
587
645
708
777
Installed Capacity
MW
386
386
386
282
195
195
195
195
195
195
Net Capacity
MW
336
336
336
232
168
168
168
168
168
168
Load Factor
%
Peak Load
4,539
Supply
PLN
22.6
MW
227
227
227
227
164
164
164
164
164
164
IPP
5.3
MW
4
4
4
4
4
4
4
4
4
4
MW
104
104
104
-
-
-
-
-
-
-
-
-
-
-
63
-
-
-
-
-
50
50
100
100
Rental
Retired & Mothballed
Additional Capacity
Rental
Amurang (2x25) Rental CFPP
CFPP
50
PLN On Going & Committed
Gorontalo (FTP1)
CFPP
Sulut I (FTP1)
CFPP
50
25
25
15
30
IPP On Going & Committed
Molotabu
CFPP
Gorontalo (Terkendala)
CFPP
20
12*)
RUPTL
PLANNED ADDITIONAL CAPACITY
26
Tolitoli
CFPP
Sulut 3
CFPP
Sulbagut 1
CFPP
Sulbagut 2
CFPP
Sulbagut 3
CFPP
Poigar 2
HEPP
Sawangan
HEPP
Minahasa Peaker
GT/GE/CCPP
Gorontalo Peaker
GT/GE/CCPP
100
60
30
12
-
150
100
Kotamobagu 1, 2 (FTP2)
GeoPP
Kotamobagu 3, 4 (FTP2)
GeoPP
40
Lahendong 5 (FTP2)
GeoPP
Lahendong 6 (FTP2)
GeoPP
Total Additional Capacity
MW
20
0
50
240
175
180
92
50
100
180
TOTAL INSTALLED CAPACITY
MW
406
406
456
592
680
860
952
1,002
1,102
1,282
TOTAL NET CAPACITY
MW
356
356
406
542
653
833
925
975
1,075
1,255
40
-
20
-
Executive Summary Electricity Supply Business Plan 2013 - 2022
20
e projected composition of power generation by fuel type in North Sulawesi from 2013 to 2022 is shown
in Figure-20. e role of oil for power generation in North Sulawesi in 2013 is remain high, at around 732
GWh (41%). From 2015, the use of oil for power generation is expected to be reduced and replaced by natural
gas with the availability of combined cycle gas-fired/gas-fired turbine/engine peaker using LNG/CNG gas and
coal-fired power plants. Coal-fired power generation will increase from 278 GWh (16%) in 2013 to 2749 GWh
(62%) in 2022. From 2016, power generated from coal will be higher than geothermal plants after most of
the coal-fired power plant projects become operational. Power generated from geothermal plants will increase
from 552 GWh (31%) in 2013 to 791 GWh (18%) in 2022, when Lahendong IV-V and Kotamobagu geothermal
plants become operational. Oil consumption in North Sulawesi will continue to decline from 197,000 kiloliters
in 2013 to 9,000 kiloliters in 2022, after the non-oil power plants become fully operational.
e use of coal is expected to increase from 172,000 tons in 2012 to 1.73 million tons in 2022, or an increase
of 10 times. LNG will be used from 2016 at 3 bcf and will increase to 4 bcf in 2022. LNG will be used to operate peaking power plants. e use of geothermal energy will continue to increase from 552 GWh in 2013 to
797 GWh in 2022. e increase in hydropower is relatively small since the potential is low - from 215 GWh in
2013 to 369 GWh in 2022.
5.000
4.500
4.000
3.500
GWh
3.000
2.500
2.000
1.500
1.000
500
2014
HSD
2015
MFO
2016
LNG
2017
Gas
2018
2019
Coal
2020
Geothermal
2021
2022
Hydro
Figure-20. Projected composition of Power Generation by Fuel Type in Northern Sulawesi
SOUTH SULAWESI SYSTEM DEVELOPMENT PLAN
e integration of the Sulbagsel system which comprises Central Sulawesi (Sulteng), West Sulawesi (Sulbar),
South East Sulawesi (Sultra) and South Sulawesi (Sulsel), is planned to be completed in 2014. Presently, the
Central Sulawesi system relies on supply from Tawaeli 2x15 MW coal-fired IPP, PLN and rental diesel engine
plants. In 2014, additional supply will be obtained from Poso hydro power plant after the 150 kV transmission
line between Poso hydro power and New Palu is in operation. e Sulteng and Sulbar systems will be interconnected with the Sulsel system through the Poso – Palopo 275 kV transmission line and the Silae – Pasangkayu
150 kV transmission line. With this interconnection, the use of coal-fired power plants on a larger scale can be
implemented in Central Sulawesi.
e Sulsel system receives sufficient supply of power from the Jeneponto coal-fired IPP, Barru coal-fired plant
and Poso hydro power plant. In the Sultra system, the shortage of power has not been fully resolved due to
the lack of reliability of Kendari 2x10 MW coal-fired power plant (Fast Track 1 Project), which still requires im-
Executive Summary Electricity Supply Business Plan 2013 - 2022
2013 - 2022
2013
27
provement. To overcome these power shortages, short-term efforts are being made to improve the reliability
of the Kendari coal-fired power plant and to accelerate the Wotu – Malili – Lasusa – Kolaka – Unaaha – Kendari
150 kV transmission line project, which is currently under construction.
In order to meet long term electricity needs over the period of 2013 - 2022, non-oil power plant projects with
a total capacity of 3,639 MW in System Sulbagsel have been planned. ese projects consist of hydro power/
mini-hydro power plants (1,392 MW), coal-fired power plants (1,475 MW), combined cycle gas-fired turbine/
engine plants (600MW) and geothermal power plants (95 MW). Within the plan includes the Karama 450 MW
hydro power project in West Sulawesi. Karama is a hydro power project involving an unsolicited IPP procur
ement process which will be carried out by the PPP scheme. e power generation development plan for Sulbagsel is shown in Table-11.
Table-11. Power Generation Development Plan in South Sulawesi
Projects
2013
2014
2015
2016
2017
2018
2019
2020
2021
2022
16,191
Sulsel interconnection with Palu (2014) and Sultra (2016)
Demand
Energy Production
Load Factor
Gross Peak Load
GWh
%
MW
5,776
6,892
8,066
9,491
10,431
11,474
12,482
13,849
15,014
63
63
63
64
65
65
65
65
65
65
1,042
1,241
1,451
1,690
1,842
2,013
2,186
2,426
2,626
2,830
935
Supply
Installed Capacity
1,533
1,495
1,490
1,270
1,140
909
909
935
935
Net Capacity
MW
1,396
1,366
1,361
1,141
1,013
835
835
861
861
861
PLN
MW
370
379
379
379
380
202
202
228
228
228
IPP
MW
695
695
695
695
633
633
633
633
633
633
Rental
MW
331
293
288
68
-
-
-
-
-
-
25
-
-
-
-
178
-
-
-
-
Retired & Mothballed
Additional Capacity
PLN On Going & Comitted
Sulsel Barru #1 (FTP1)
CFPP
50
-
-
-
-
-
-
-
-
-
Nii Tanasa/Kendari #2 (FTP1)
CFPP
10
-
-
-
-
-
-
-
-
-
Nii Tanasa/Kendari (Expansion)
CFPP
-
10
-
-
-
-
-
-
-
-
Scattered MHPP
MHPP
-
-
4
6
-
-
-
-
-
-
Sengkang (GT 22)
GTPP
60
-
-
-
-
-
-
-
-
-
Sengkang (ST 28)
CCPP
60
-
-
-
-
-
-
-
-
-
Mamuju
CFPP
-
-
-
50
-
-
-
-
-
-
Tawaeli Expansion
CFPP
-
-
-
30
-
-
-
-
-
-
IPP On Going & Committed
RUPTL
PLANNED ADDITIONAL CAPACITY
28
Makassar Peaker
GT/GE/CCPP
-
-
-
300
150
150
-
-
-
Punagaya (FTP2)
CFPP
-
-
-
200
-
-
-
-
-
-
Jeneponto 2
CFPP
-
-
-
-
-
225
-
-
-
-
Kendari 3
CFPP
-
-
-
-
-
100
-
-
-
-
Sulsel Barru 2
CFPP
-
-
-
-
100
-
-
-
-
-
Sulsel 2
CFPP
-
-
-
-
-
200
200
-
-
-
Palu 3
CFPP
-
-
-
-
100
-
-
-
-
-
Sulsel 3/Takalar
CFPP
-
-
-
-
-
-
-
-
-
200
Wajo
GEPP
-
-
20
-
-
-
-
-
-
-
Poso 2
HEPP
-
-
-
-
-
-
-
-
66
66
Poko
HEPP
-
-
-
-
-
-
-
117
117
-
Konawe
HEPP
-
-
-
-
-
-
-
-
50
-
Watunohu
HEPP
-
-
-
-
-
-
-
-
15
-
Bakaru 2
HEPP
-
-
-
-
-
-
-
126
-
-
Karama Baseload (Unsolicited)
HEPP
-
-
-
-
-
-
-
100
-
-
Karama Peaking (Unsolicited)
HEPP
-
-
-
-
-
-
-
-
350
-
Bonto Batu (FTP2)
HEPP
-
-
-
-
-
-
110
-
-
-
Malea (FTP2)
HEPP
-
-
-
-
-
-
-
90
-
-
Bora Pulu (FTP2)
GeoPP
-
-
-
-
-
-
-
-
-
55
Marana/Masaingi (FTP2)
GeoPP
-
-
-
-
-
-
-
-
-
20
Lainea
GeoPP
-
-
-
-
-
-
-
-
-
20
Scattered MHPP
MHPP
Total Additional Capacity
MW
-
19
21
34
38
-
-
-
-
-
180
29
45
620
388
675
310
433
598
361
TOTAL INSTALLED CAPACITY
MW
1,713
1,703
1,744
2,143
2,401
2,846
3,156
3,615
4,213
4,574
TOTAL NET CAPACITY
MW
1,576
1,575
1,615
2,015
2,274
2,771
3,081
3,540
4,138
4,499
Executive Summary Electricity Supply Business Plan 2013 - 2022
Apart from power distribution from the power supply center to the demand center, the transmission system
also aims to build an interconnection among sub-systems, connect isolated electrical systems to the grid,
overcome any bottlenecks, and to meet the N-1 reliability criteria.
e transmission system development plan in Sulbagsel system (Figure-21) is as follows: 275 kV transmission
line connecting Karama hydro power plant – Mamuju – Enrekang – Sidrap – Makassar (Daya Baru) – Bantaeng,
together with a 275/150 kV EHV substation, to evacuate 450 MW of power from the Karama plant; 275 kV
transmission line connecting Enrekang – Palopo, in anticipation of the Poso II hydro power, to be developed
simultaneously to improve system stability (especially Kendari), as well as gain operational flexibility; 275 kV
EHV substation at Enrekang to evacuate power from Bonto Batu, Poko, Malea, as well as Bakaru II hydro
power and channeled to the load center through the 275 kV Enrekang – Sidrap – Makassar – Bantaeng transmission line.
Bitung Diesel PP
57 MW
Minahasa Peaker GT/GE/CC PP
150 MW – 2015/16
Sawangan HEPP
12 MW – 2019
Lopana Diesel PP
10 MW
Sulut I CFPP (FTP1)
2x25 MW – 2016/17
Tolitoli CFPP
3x15 MW – 2016/17
Sulbagut 2 CFPP
2x100 MW – 2021/22
Sulbagut 1 CFPP
2x50 MW – 2019/20
CF
Tolitoli
Amurang Rental CFPP
2x25 MW - 2016
Gorontalo CFPP (FTP1)
2x25 MW – 2015
Leok
EAST
KALIMANTAN
CF
Bintauna
GORONTALO
Buroko
CF
G Likupang
Paniki
Teling Ranomut Bitung
D
H
Tasik Ria
Kema
Sawangan
Tomohon
CF
GEO GEO
Tonsealama
CF
Amurang CFPP
2x25 MW
D
CF
Kawangkoan
GEO
Lopana
Sulut 3 CFPP
2x50 MW - 2018
Lolak
Otam
Lahendong I&II GeoPP
2x20 MW
H
Lahendong III&IV GeoPP
2x20 MW
Isimu
Bangkir
Moutong
Tilamuta
G
Tambu
GEO
D Botupingge
Marisa
Gorontalo Peaker GT/GE/CC PP
100 MW – 2017
Lahendong V&VI GeoPP
2x20 MW – 2017/18
NORTH SULAWESI
CF
CF
Poigar 2 HEPP
32 MW – 2019
Molibagu
Telaga Diesel PP
24 MW
Kotamobagu I GeoPP
2x20 MW – 2022
Molotabu CFPP
2x10 MW – 2013
Kotamobagu II GeoPP
2x20 MW – 2022
Gorontalo Energy CFPP
2x6 MW – 2014
Sulbagut 3 CFPP
2x30 MW – 2018
Palu 3 CFPP
2x50 MW - 2018
Tawaeli Expansion CFPP
2x15 MW - 2016
CF
Ampana CFPP
2x3 MW–2016
Marana/Masaingi (FTP2) GeoPP
20 MW - 2022
CF
GEO
Borapulu (FTP2) GeoPP
55 MW - 2022
Silae
Silae Diesel PP
45 MW
D
Bunta
Talise
Ampana
Luwuk CFPP
2x10 MW–2016
CF
CF
Palu
Baru
Luwuk
GEO
Poso
Toili
CENTRAL
SULAWESI
Pasangkayu
GE
Luwuk Peaker GEPP
2x10 MW–2016/18
Poso HEPP
3x65 MW
H
WEST
SULAWESI
Poso 2 HEPP
2x66 MW – 2021/22
Topoyo
H
Tentena
Kolonedale
Karama (Unsolicited) HEPP
450 MW – 2020/21
Mamuju (FTP2) HEPP
2x25 MW - 2016
H
Malea HEPP
2x45 MW – 2017
Bungku
Tonasa
Palopo
H
Majene
SOUTH EAST
SULAWESI
Bonto Batu HEPP
2x50 MW – 2017
Makale
HH
H
Bakaru
Enrekang
H
Pare
Sidrap
D
CF
Kolaka
Unaaha
Kendari
to
Takalar
CFPP
Laenia GeoPP
2x10 MW - 2022
P
Soppeng
Sungguminasa
to
Tallasa SS
Wajo GEPP
20 MW – 2015
CF
Raha (FTP2) CFPP
2x3 MW – 2016
Barru
Andolo
Bone
Raha 2 CFPP
2x3 MW – 2018
Tonasa
T
Tona
ona
Pangkep
angkep
a
Tanjung
Bunga
Kendari 3 CFPP
2x50 MW – 2018
CF
Sengkang CCPP (ST 28)
60 MW – 2013
GE
Sulsel Barru 2 CFPP
2x50 MW - 2016
CF
H
Sengkang GTPP (GT 22)
60 MW – 2013
Sengkang
GT
CC
Sulsel Barru CFPP
2x50 MW
Kendari/Nii Tanasa CFPP
2x10 MW
CF
Bosowa
G Mandai
Kima
Tallo G Daya
Lama
Daya Baru
Bontoala
Tello
Panakukang
Kendari (Expansion) CFPP
1x10 MW - 2014
SOUTH
SULAWESI
Maros
300 MW-2016
150 MW-2017
150 MW-2018
Konawe HEPP
2x25 MW – 2021
Siwa
Pinrang
Makassar Peaker GT/GE/CC PP
Wotunohu HEPP
15 MW – 2021
Lasusua
Poko HEPP
2x117 MW – 2020/21
Bakaru 1 HEPP
2x63 MW
to
Sidrap SS
Tello GTPP
123 MW
H
Polman
to
Barru SS
Pangkep
Malili
Wotu
Bakaru II HEPP
2x63 MW – 2020
CF
Maros
Bosowa
Bos
Tello
T
oD
Kajuara
Raha
Kasipute
Bau-Bau CFPP
2x7 MW - 2014
G
Sungguminasa
asa
a
Daya Baru
Bau-Bau CFPP
2x10 MW – 2014/15
CF
CF
Sulsel 2 CFPP
2x200 MW – 2018/19
Tallasa
Sulsel-3/Takalar CFPP
2x100 MW – 2022
Bau-Bau 2 CFPP
2x10 MW – 2018/19
Bantaeng
Jeneponto
Punagaya CF
Wangi-Wangi CFPP
2x3 MW – 2015/16
Sinjai
Bulukumba
CF
CF
CF
Bau-Bau
Bantaeng
Smelter
CF CF
Punagaya CFPP (FTP2)
2x100 MW – 2016
Jeneponto CFPP
2x100 MW
PT PLN (Persero)
SYSTEM PLANNING
SULAWESI SYSTEM
Jeneponto 2 CFPP
2x100 MW – 2016
/
/
/
/
/
/
/
/
/
/
/
/
SS 500 kV Existing / Plan
SS 275 kV Existing / Plan
SS 150 kV Existing / Plan
SS 70 kV Existing / Plan
SS 500/275 kV Existing / Plan
SS 500/275/150 kV Existing / Plan
SS 275/150 kV Existing / Plan
SS 150/70 kV Existing / Plan
T/L 70 kV Existing / Plan
T/L 150 kV Existing / Plan
T/L 275 kV Existing / Plan
T/L 500 kV Existing / Plan
CF
GT
GEO
H
CC
GE
MH
D
/ CF
/ GT
/ GEO
/ H
/
/
/
/
CC
GE
MH
D
CFPP Existing / Plan
GTPP Existing / Plan
GEOPP Existing / Plan
HEPP Existing / Plan
CCPP Existing / Plan
GEPP Existing / Plan
MHPP Existing / Plan
Diesel PP Existing / Plan
PP Existing
PP Plan
Edit December 2013
Figure-21. Transmission System Development Plan for Sulawesi
Executive Summary Electricity Supply Business Plan 2013 - 2022
2013 - 2022
Mamuju
Baru
CF
Mamuju
29
Development of the 150 kV transmission line associated with coal-fired power plants, hydro power plants, gas
turbine/engine plants and interconnection among sub-systems will be carried out as part of the establishment
of the Sulbagsel integrated system. e 150 kV transmission line extending to scattered locations is intended
to overcome the transmission bottleneck, improve service voltage and operational flexibility, and meet the
reliability criteria (N-1).
e development of the transmission grid throughout Sulawesi for the period 2013 - 2022 covers 7,751 kms
and requires investments of US$1.082 billion.
Projected power generation in Sulbagsel from 2013 to 2022 is shown in Figure-22. Power generation from
oil in 2013 is expected to remain high, at 1,250 GWh (22%). However, beginning from 2018, power generated from oil will be replaced by power generated from natural gas in the form of LNG when the Makassar
gas turbine/engine peaker plant and coal fired power plant become operational. Power generated from gas
fired power plants will increase nominally but decrease in terms of percentage, i.e. from 1,693 GWh (33%) in
2013 to 2,902 GWH (18%) in 2022. is is due to additional capacity from gas fired power plants (Sengkang
combined cycle gas-fired plant) owned by the private sector and peaker power plants running on LNG. Power
generated from coal fired power plants will increase from 1,706 GWh (30%) in 2013 to 9,160 GWh (57%) in
2022. Power generated by hydropower will increase from 1,127 GWh (20%) in 2013 to 3,650 GWh (23%) in
2022 when several hydropower projects become operational, namely Bonto Batu, Malea, Karama, Bakaru II,
Poko, Poso II, Konawe and Watunohu.
Oil consumption in the Sulbagsel system is expected to decrease from 297,000 kiloliters in 2013 to 57,000
kiloliters in 2022 after non-BBM plants become operational. e use of coal will continue to increase from
1.06 million tons in 2013 to 5.6 million tons in 2022, or an increase of 5 times. e volume of natural gas
usage, including LNG, will also continue to rise from 13 bcf in 2013 to 24 bcf in 2022. LNG will only be used
for operating peaking power plants. Production from geothermal plants amounting to 479 GWh will commence
in 2022. e use of hydropower will increase sharply given the construction of many new hydro power plants,
increasing from 1,127 GWh in 2013 to 3,650 GWh in 2022, or an increase of 3 times.
16,000
14,000
12,000
GWh
10,000
8,000
6,000
RUPTL
4,000
30
2,000
2013
2014
2015
2016
2017
2018
Solar/Hybrid
HSD
MFO
LNG
Gas
2019
Coal
2020
Geothermal
2021
Hydro
Figure-22. Projected Composition of Power Generation by Fuel Type in Sulbagsel
Executive Summary Electricity Supply Business Plan 2013 - 2022
2022
Meanwhile, the gas supply for power plant in East Indonesia power system can be seen in Table-12.
Table-12. Gas Supply for Power Plant in Eastern Indonesia
Power plant
Gas Supplier
1
Sei Raya
2
Pontianak Peaker
LNG PLN Batam (Plant)
3
Bangkanai
Salamander
2013
2014
2015
2016
2017
LNG PLN Batam (Plant)
2018
2.0
20.0
20.0
2019
2.0
2020
2.0
2021
2.0
2022
2.0
2.0
5.0
5.0
5.0
5.0
5.0
5.0
20.0
20.0
20.0
20.0
20.0
20.0
20.0
5.0
8.0
13.0
13.0
13.0
13.0
6.0
5.0
4.0
3.0
2.0
1.0
1.0
2.0
-
4
Kalsel Peaker
Salamander (Potential)
5
Bontang
Salamander Lapangan Tutung
(Potential)
6
Bontang
Total Bontang
2.0
2.0
2.0
2.0
7
Tanjung Batu
TAC Semco
4.0
4.0
4.0
-
-
-
-
-
-
8
Sambera
VICO (Potential)
-
10.0
10.0
10.0
10.0
10.0
-
-
-
-
9
Kaltim Peaker
JOB Simenggaris (Potential)
21.0
21.0
21.0
21.0
21.0
21.0
21.0
21.0
21.0
10
Nunukan
Pertamina EP TAC Sembakung
2.5
2.5
2.5
11
Nunukan 2
Medco South Sebuku Bengara
(Potential)
2.5
2.5
2.5
2.5
2.5
2.5
12
Tarakan
GSA Pertamina EP
5.0
5.0
5.0
5.0
5.0
5.0
13
Tarakan
Manhattan KI
14
Tanjung Selor
Perusda Nusa Serambi
Persada
15
Senipah
Total Senipah
16
Minahasa Peaker
LNG Sengkang
6.0
6.0
6.0
17
Gorontalo Peaker
Donggi (Potential)
5.0
5.0
5.0
5.0
5.0
5.0
5.0
18
Morowali
Tiaka (Potential)
5.0
5.0
8.0
8.0
8.0
8.0
8.0
8.0
19
Sengkang
Energy Equity Epic (Sengkang)
35.0
35.0
35.0
35.0
35.0
35.0
35.0
35.0
35.0
20
Makassar Peaker
LNG Sengkang
5.0
10.0
15.0
23.0
23.0
21
Lombok Peaker
Marine CNG dari Gresik
6.8
6.8
6.8
6.8
6.8
6.8
9.5
22
KTI Scattered
LNG Sengkang (Potential)
3.0
3.0
4.0
15.0
15.0
15.0
15.0
15.0
15.0
2.5
5.0
5.0
2.5
5.0
5.0
5.0
5.0
5.0
5.0
5.0
5.0
3.0
3.0
3.0
3.0
3.0
3.0
3.0
3.0
3.0
3.0
20.0
20.0
20.0
20.0
20.0
20.0
20.0
20.0
20.0
35.0
5.0
3.0
5.0
Perusda Salawati (Potential)
Total
Sorong Petrochina (plant)
4.0
4.0
4.0
4.0
4.0
BP Berau (Potential)
3.0
3.0
3.0
3.0
3.0
215.3
176.3
175.3
174.3
177.0
51.5
130.0
145.5
170.3
207.3
DEVELOPMENT PLAN FOR NEW AND RENEWABLE ENERGY
PLN has prepared a development plan for New and Renewable Energy (EBT) as shown in Table -13. e development plan comprises of 1) Mini hydro power plants: PLN encourages the development of mini-hydro plants
by the private sector to meet the local demand and to be distributed to the PLN grid 2) Wind turbine generating plants: As the potential for wind power in Indonesia is limited, the development of wind turbine generating
plants will be limited to areas with wind power potential 3) Biomass: PLN intends to build biomass power
plants if PLN has control over the biomass supply. PLN cooperating with several local government for biomass
industry pioneer 4) Marine energy: While the potential of marine energy is estimated to be large, the technology and economics of marine power plant development are still unknown, hence PLN will conduct small scale
pilot tests as research and development projects 5) Biofuel: Depending on the readiness of the biofuel market,
PLN is prepared to utilize biofuel if it is available 6) Solar power plants: PLN will develop solar plants in 1,000
locations/islands, especially in outlying and isolated areas to improve the electrification ratios.
Executive Summary Electricity Supply Business Plan 2013 - 2022
2013 - 2022
No
31
Development of Solar Power Plants
Taking into account the wide geographical distribution of the population and difficulties in reaching remote
areas, PLN plans to build solar power plants as follows: centralized/communal solar power plants (independent or hybrid operating mode); small scale and dispersed solar home systems (solar panel + LED lamps with
battery), limited to provinces where application of renewable energy is still low and in areas where there will be
no conventional electricity available within 5 years. e development of these solar power plants is intended to
electrify remote areas as soon as possible, avoid utilization of oil if they are served by diesel engine generating
units, and to reduce the generation costs in certain areas where transportation of oil is very expensive, e.g.
around the mountain peaks of Jayawijaya Papua. e electrification program with solar home systems or “super energy saving” lantern (SEHEN) is not a capacity development program for the power system. e SEHEN
electrification program is intended to be a temporary program and is limited to areas with low electrification
ratios, such as in West Nusa Tenggara, East Nusa Tenggara and Papua, after first conducting a feasibility
study. e SEHEN program can be substituted by centralized/communal solar power plants. e construction
of solar power plants and installation of solar home system will be preceded by a feasibility study.
Table-13. Development Plan for New and Renewable Energy
No
New and
renewable
energy power
plant
Capacity
2013
2014
2015
2016
2017
2018
2019
2020
2021
2022
Total
1
MHPP
MW
33
42
96
149
237
192
186
156
190
200
2
Solar Power
MWp
6
104
75
54
36
60
75
75
75
75
1,481
634
3
Wind Power
MW
-
-
50
20
20
20
30
40
50
50
280
363
4
Biomas PP
MW
48
10
15
20
30
40
50
50
50
50
5
Ocean PP
MW
-
-
1
-
1
3
3
5
5
10
28
6
Biofuel PP
ousand Kilo
Liter
15
400
400
500
500
600
600
600
600
600
4,815
MW
87
156
237
243
324
315
344
326
370
385
2,786
Total
DEVELOPMENT PLAN FOR ISOLATED POWER SYSTEMS
Besides the 6 interconnected power systems, there are more than 100 isolated systems spread throughout
the Eastern Indonesia region. e systems are spread over the provinces of Maluku, North Maluku, Papua,
West Papua, West Nusa Tenggara, East Nusa Tenggara and Riau Islands. Even in islands where the power systems are interconnected, there are isolated systems such as in Nias, Belitung, Buton, Selayar, Karimun Jawa,
Bawean and many other islands.
RISK ANALYSIS
RUPTL
Based on the probability and impact if the risks occur, the risks have been mapped as shown in Figure-23. e
assessment of the risks and impact have been conducted with qualitative method based on PLN’s experience
in carrying out similar programs in the past, and PLN’s experience in handling such risks in the past.
32
Determination of the risk impact is based on the impact to company cash flow and the impact on smooth
operation of the company.
Executive Summary Electricity Supply Business Plan 2013 - 2022
Very High
PROBABILITY RATE
High
Medium
Low
Very Low
Not Significant
Minor
Medium
Significant
Disaster
IMPACT SCALE
Description :
EXTREME RISK :
3
HIGH RISK :
Limited funding capability risk
1
Change in electricity sector order/policy risk
4
PLN and IPP project completion delay risk
2
Unrealized electricity tariff rationalization risk
5
Unconformity power plant and transmission line risk
6
Non-oil primary energy supply constrain risk
10
Increase of primary energy price risk
7
Electricity consumption higher than demand projection risk
8
Power plant and transmission performance degradation risk
9
Transmission line system bottlenecking risk
11
Environmental risk
12
Disaster risk
CONCLUSION
Assuming the economic growth during the next ten years average 6.9% and increasing from actual electricity
demand in 2012, projected electricity sales in 2022 are estimated to reach 387 TWh or a growth rate of 8.4%
over the next 10 years. Peak load in 2022 is projected to reach 64 GW. To meet electricity demand, the development of new power plants during the period 2013-2022 with total capacity of 60 GW has been planned.
In line with the development of aforementioned power plants, the development of 57,100 kms of transmission system will be required, consisting of 5,600 kms of 500 kV AC EHV transmission lines, 1,100 kms of 500
kV HVDC transmission lines, 462 kms of 250 kV HVDC transmission lines, 6,400 kms of 275 kV AC transmission lines, 39,600kms of 150 kV HV transmission lines and 3,900 kms of 70 kV HV transmission lines. Additional transformer capacity required include 134,000 MVA consisting of 72,900 MVA 150/20 kV transformers,
3,700 MVA 70/20 kV and 35,700 MVA 500/150 kV inter-bus transformers (IBT), 17,100 MVA 275/150 kV
IBT, 480 MVA 150/70 kVIBT, 4,000 MVA 500/275 kV IBT and 600 MVA 250 kV DC. In anticipation of electricity sales growth during the period 2013 - 2022, it will require additional 224,800 kms of medium voltage grids,
217,200 kms of low voltage grid and 35,600 MVA of distribution transformer capacities.
Executive Summary Electricity Supply Business Plan 2013 - 2022
2013 - 2022
Figure-23. Mapping Long-Term Risk Profile for 2013 - 2022
33
e overall investment required for power generation, transmission and distribution for the period 2013 –
2022 to meet the requirement of electrical power infrastructure development in Indonesia is US$125.2 billion,
consisting of power generation investment (including IPP) of US$ 91.3 billion, transmission system investment
of US$ 19.4 billion and distribution system of US$ 14.5 billion.
RUPTL
e funds for PLN investment will be met by the State Budget (APBN) in the form of Government equity participation, new loan, and internal funds. PLN’s internal funding capacity is limited and as such, all funds required
for investment will be obtained from debt. PLN’s investment needs to be supported by increasing capacity
for self-funding and maintaining the ratio of debt to PLN’s assets, so that it would continue to support the
development of electrical power supply. e role of APBN each year will be significant because it is politically
difficult to raise electricity tariff to a level higher than the basic generating cost (BPP) in the near term.
34
Executive Summary Electricity Supply Business Plan 2013 - 2022