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SOLAR ENERGY POTENTIAL OF MALAYSIA:
A technological potential assessment with policy
recommendations
ISyE 6701
Stephen Spicher
Jan Moellmann
Mayuri Rajput
Catharina Hollauer
Joshua Oladipo
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INDEX
PROJECT ABSTRACT ................................................................................................................................ 5
I. ECONOMIC AND ENERGY OVERVIEW ............................................................................................ 6
II. POLICY OVERVIEW .............................................................................................................................. 7
a) Feed-in-Tariffs ....................................................................................................................................... 9
b) Net Metering....................................................................................................................................... 11
III. ANALYSIS OF TECHNOLOGY OPTIONS ....................................................................................... 12
i. Large scale solar (LSS) ........................................................................................................................ 12
a) Large Scale Solar Potential ............................................................................................................. 13
• Solar Radiation in Malaysia ............................................................................................................. 13
• Land Availability .............................................................................................................................. 13
• Theoretical Electricity Generation Potential .................................................................................... 15
• Installed Capacity ............................................................................................................................. 15
b) Economic analysis .......................................................................................................................... 16
• Costs ................................................................................................................................................. 16
• Levelized Cost of Energy (LCOE) .................................................................................................... 17
ii. Rooftop potential ................................................................................................................................. 18
• Land availability ............................................................................................................................... 19
• Generation Potential .......................................................................................................................... 19
a) Results.............................................................................................................................................. 20
IV. CARBON EMISSIONS AND TRADING POTENTIAL.................................................................... 21
V. CONCLUSIONS .................................................................................................................................... 23
a) Challenges and further research for LSS ............................................................................................. 23
b) Challenges and further research for Rooftop Solar ............................................................................ 25
c) Regulatory Recommendations ............................................................................................................ 25
d) Non-Regulatory Recommendations .................................................................................................... 27
REFERENCES ............................................................................................................................................ 28
APPENDIX ................................................................................................................................................. 32
A1 ENERGY AND ECONOMY APPENDIX....................................................................................... 32
A2 LARGE SCALE SOLAR APPENDIX............................................................................................. 32
A3 ROOFTOP SOLAR APPENDIX ..................................................................................................... 41
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A4 CARBON EMISSIONS AND TRADING APPENDIX ...................................................................... 42
FIGURES INDEX
Figure 1 – Yearly average solar radiation (kWh/m2)* ............................................................................. 13
Figure 2 – Current land-use in Peninsular Malaysia* .............................................................................. 14
Figure 3 – Large scale solar suitable area in Peninsular Malaysia* ......................................................... 15
Figure 4 – Discounted Cash Flow ........................................................................................................... 18
Figure 5 – Payback Period ....................................................................................................................... 18
Figure 6– Rooftop Solar Case Base Scenario: Discounted Cash-Flow SEDA FiT rates ........................ 21
Figure 7 - Installed Capacity (Million Kilowatts) .......................................................................... ......... 33
Figure 8 – Electricity Generation Mix (GWh) 2015 ................................................................................ 33
Figure 9 – Location and capacity of large scale solar plants in Peninsula Malaysia* ............................. 34
Figure 10 – Daily average solar radiation (MJ/m2 )* .............................................................................. 35
Figure 11 – Initial investment costs in Peninsular (%) ............................................................................ 35
Figure 12 – Scenario Discounted Cash Flow .......................................................................................... 37
Figure 13 – Scenario 4 Payback Period ................................................................................................... 37
Figure 14 – Parameters Sensitivity Analysis Results: Discount Rate and LCOE .................................... 38
Figure 15– Parameters Sensitivity Analysis Results: Efficiency and Energy generation potential ........ 39
Figure 16– Parameters Sensitivity Analysis Results: Efficiency and Emission reduction potential ........ 39
Figure 17– Parameters Sensitivity Analysis Results: Average radiation and required installation capacity
................................................................................................................................................................. 40
Figure 18– Parameters Sensitivity Analysis Results: Average daily radiation and LCOE ....................... 40
Figure 19– Parameters Sensitivity Analysis Results: Avg implementation cost and LCOE .................... 41
Figure 20 – CO2 European Emission Allowances .................................................................................. 43
Figure 21 – Share of GHG emissions covered ........................................................................................ 45
Figure 22 – Prices in implemented carbon pricing initiatives ................................................................. 46
TABLE INDEX
Table 1 - Original Malaysian FiT Rates .................................................................................................. 10
Table 2 – Current Malaysian FiT Rates* ................................................................................................. 10
Table 3 – Displacement Costs .................................................................................................................. 12
Table 4 – Electricity Generation Potential ............................................................................................... 16
Table 5 – Associated Installed Capacity .................................................................................................. 16
Table 6 – Results .................................................................................................................................... 17
Table 7 – Breakdown for Rooftop Solar 2016* ...................................................................................... 20
Table 8 – LSS Carbon Potential Results ................................................................................................. 24
Table 9 – Rooftop Solar Carbon Potential Results ................................................................................. 24
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Table 10 – Yearly radiation in Malaysian towns ..................................................................................... 34
Table 11 – Scenario 5MW Results .................................................................................................. ....... 36
Table 12 – Weak points of EU and China ETS ....................................................................................... 44
Table 13 – Emission reduction potential ................................................................................................. 47
Table 14 – Greenhouse gas offset over project lifetime .......................................................................... 48
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PROJECT ABSTRACT
Malaysia’s rise to prominence in South East Asia has attracted the attention of other regions
and countries, including the United States. The U.S. State Department mission in Kuala Lumpur
is interested in why solar energy holds a small market share and in what might be a path towards
a more diversified energy mix. This report aims to answer these questions by validating solar
energy potential in Malaysia and providing analysis and recommendations of current or potential
policy changes to support growth of solar power.
The charter issued by the U.S. State Department presented the hypothesis that public
perception in Malaysia is that solar power is not viable due to frequent cloud cover. We show that
for both large scale solar (LSS) installations and roof-top solar projects (on current construction),
the energy generation potential is more than enough to meet the 2030 energy requirements.
Moreover, both LSS and roof-top installations indicate positive net present values and levelized
cost of energy (LCOE) in line with current electricity prices, besides substantial CO2 emissions
reduction potential.
We identify constraints on renewable energy development, such as the Feed-in-Tariffs that
are capped or closed, low availability of capital for LSS projects, and the federal funding source
for incentives that is not sustainable for the duration of payment periods. Also, multiple
externalities are not reflected in the market; fossil fuel subsidies and the lack of carbon pricing are
the most significant.
We present the following policy options and recommendations:
• Green energy bonds can increase the available capital for solar projects. These
financial instruments provide return on investment and low volatility similar to other bonds, but
their intention is to fund renewable energy projects. Other countries, including China and India,
are issuing green bonds regularly. Private companies can provide additional capital resources by
issuing green bonds on their own; Apple is cited as an exemplary model for this.
• Incentives to promote renewable energy installations can be reopened and
expanded. The sustainable energy fund can to be funded by increasing the current tariff of 1.6%
on electricity consumers above 0.30 MWh..
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• A carbon tax to internalize the impact of fossil fuel sources needs to be analyzed
for economic impact but can support the growth phase of Malaysia’s renewable energy portfolio.
• The balancing of the federal budget, started by the Subsidy Rationalization process
in 2010, will enable the development of renewable energy in Malaysia. Natural gas and coal
subsidies negatively affect the national budget, and artificially lower consumer electricity rates to
a level that eliminates the financial incentives for solar and other renewable energy sources.
The first section focuses on the development of the energy mix over the years. The second
section analyzes the past attempts and current status of renewable energy development in Malaysia.
The third section addresses the technological potential of large scale solar and rooftop solar. The
fourth section evaluates the carbon trading potential as an upside for the project and a possibility
of developments through the carbon development mechanism. Finally, the last sections expose the
conclusions and recommendations for increasing the solar generation in Malaysia.
I. ECONOMIC AND ENERGY OVERVIEW
Malaysia’s favorable economic outlook reflects a well-diversified and open economy that
has successfully weathered the impact of external shocks. Anti-crisis policies such flexible
exchange rate regimes, large international reserves, selective and temporary capital controls to
stabilize capital flows, and careful prudential regulation of the domestic financial sector have been
adopted over the years. (Gan PY, 2008) estimated the expected GDP growth of Malaysia to average
4.6% between 2004 and 2030. Energy consumption is projected to increase by 4.3% annually
through 2030. Although the growth rate of energy consumption is a bit lower than the GDP growth
rate, the absolute amount of energy consumption would be 3 times greater. This growth coupled
with insufficient natural gas supply in high-demand centers is driving the country to diversify its
power generation fuel mix and to add electricity capacity to avoid future power shortages. In 2014,
the generation capacity was approximately 9.0 GW.
Malaysia's electricity demand which is mainly fulfilled by natural gas and coal has
expanded rapidly over the years (Oh TH, 2018), and the crucial challenge facing the power sector
in Malaysia is the issue of sustainability (Ong HC, 2011 ). The development of renewable energy
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policies can ensure secure and sustainable energy supplies at reasonable costs and to address issues
related to global climate change (Kardooni R, 2018 ).
Since the year 2000 in Malaysia (time of the 8th Malaysian Plan), renewable energy has
been included as a key fifth element in the country's fuel policy along with hydro, coal, gas, and
oil, and a target of obtaining 5.0% of the total energy supply from renewable sources was set
(Kardooni R, 2018 ). Since 2010, gas and coal have primarily made up roughly 80–90% of the
domestic's installed generation capacity and output (Oh TH, 2018) as shown in Appendix A1.
Coal and natural gas remain as the two most important sources in powering up the country
and their consumption is projected to escalate when more power plants based on these two
resources go online by 2020. The total installed capacity at present stands at around 30 gigawatt
(GW), with most of the power stations located in the more densely populated and industrialized
Peninsular Malaysia (Oh TH, 2018).
Malaysia targets to increase its renewable energy installed capacity from 220 MW in 2011
to 12 GW by 2050 (Bekhet HA, 2014). A reduced dependency on gas, primarily due to the gradual
retirement of gas turbine units on top of new coal-fired power plants (Oh TH, 2018). However, the
consumption of gas has remained consistent over the years and latest data from TNB showed that
as of August 2016, coal, gas and hydropower remained the top three resources in the generation
mix at 51%, 45% and 3.5%, respectively (Oh TH, 2018) (Tenaga, 2016).
As a country that is rich in fossil fuels, it is no easy hurdle for Malaysia to abandon its
dependence on these resources within a short transition period. Coupled with the long history of
the not-so-efficient policy in enforcement and implementation, it comes as no surprise that even
after more than a decade since renewable energy was introduced and numerous relevant
programmes instigated, renewable energy is only 1.0–2.0% of the total energy mix (Oh TH, 2018).
The next chapter analyzes the policies adopted in Malaysia to foster investments in renewable
energy generation.
II. POLICY OVERVIEW
The National Energy Policy of Malaysia was introduced in 1979 with three main objectives.
The first was based on supply and aimed at ensuring an adequate, secure and cost-effective energy
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supply based on the maximum use of indigenous resources. The second focused on the utilization
aspect, promoting efficiency and conservation measures to eliminate wasteful and non-productive
patterns of energy consumption. And finally, the third states that in achieving the supply and
utilization objectives, environmental concerns will not be neglected (Alam SS, 2013) (Wright,
2008).
From 2001 onwards, new energy policies introduced were mostly RE-related to explore
and promote the use of renewable energy as an alternative fuel source. These steps include the
Fifth-Fuel Policy under the 8th (2001-2005) and 9th (2006-2010) Malaysia Plan, Energy Efficiency
in Commercial Buildings (MS1525), The Kyoto Protocol, the Malaysian Building Integrated
Photovoltaic Programme (MBIPV), and Biomass (Alam SS, 2013) (Haw, 2006).
At the end of 2005, the Fifth-Fuel Policy of the 8th Malaysia Plan, targeted for 0.50GW of
electricity generation from renewable sources to the national grid. However, only 12MW was
delivered from two projects from the Small Renewable Energy Power Programme (SREP). The
SREP was established to support the government’s strategy to intensify the development and
utilization of RE as the fifth fuel resource in power generation. To facilitate the expeditious
implementation of grid-connected RE resource-based small power plants. Although the SREP has
targeted to generate 5.0% or 0.60GW of the country’s electricity from RE by 2005, only 0.30%
was achieved.
In 2011, one of the more impactful and notable policies was adopted under the SEDA`s
purview: the FiT scheme, which allowed the mass public to become power producers (Oh TH,
2018) (SEDA, 2011). SEDA is a statutory body formed under the Sustainable Energy
Development Authority Act 2011 (SEDA, 2011) with the key role to manage and administer the
implementation of the FiT initiatives decreed under the Renewable Energy Act in 2011.
Under FiT, commercial entities and individuals are allowed to generate RE from four
sources (solar PV, biogas, biomass and mini hydro) and sell the energy to TNB through the utility
grid which is obligated under the RE Act 2011. The FiT in Malaysia gives much emphasis on solar
PV and has proven to be increased the investment and development of solar plants of varying sizes.
Furthermore, a cornerstone of RE incentives is the Feed-in-Tariffs implemented on November
2011 and the net metering policy implemented on November 2016.
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a) Feed-in-Tariffs
Feed-In-Tariff (FiT) is a scheme in which the owner will be paid for any amount of
electricity generated in kilowatt-hour (kWh), with a contract period of typically 20 years. This is
one of the incentives offered to increase the renewable energy penetration, especially for small
scale electricity generation (Muhammad-Sukki, 2011). According to SEDA, the FiT ranges from
1.20 MYR for smaller plants up to 0.85 MYR for larger plants. Additional bonus rates exist if each
plant has the following features (SEDA, SEDA Portal, 2018):
Bonus 1: Use as installation in buildings or building structures.
Bonus 2: Use as Building Material.
Bonus 3: Use of Locally Manufactured or Assembled PV modules.
Bonus 4: Use of locally manufactured or assembled solar inverters.
Table 1 - Original Malaysian FiT Rates Plant Size FiT
Rate
Bonus
1
Bonus
2
Bonus
3
Bonus
4
Total
Up to 4 kW 1.23 0.26 0.25 0.03 0.01 1.78
4 kW – 24 kW 1.20 0.26 0.25 0.03 0.01 1.75
24 kW – 72 kW 1.18 0.26 0.25 0.03 0.01 1.73
72 kW – 1 MW 1.14 0.26 0.25 0.03 0.01 1.69
1 MW – 10 MW 0.95 0.26 0.25 0.03 0.01 1.5
10 MW – 30 MW 0.85 0.26 0.25 0.03 0.01 1.4
Table 2 – Current Malaysian FiT Rates* Description of Qualifying Renewable Energy Installation Jan 2018
a) Basic FiT rates having installed capacity of FiT Rates (RM per kWh)
(i) up to and including 4kW 0.67
0.65 (ii) above 4 kW and up to and including 24 kW
(iii) above 24 kW and up to and including 72 kW 0.44
b) Bonus FiT rates having the following criteria (one or more) Additional (+)
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(i) use as installation in buildings or building structures 0.13
0.08 (ii) use as building materials
(iii) use of locally manufactured or assembled solar PV modules 0.05
(iv) use of locally manufactured or assembled solar inverters 0.05
*Rates are applicable to the project application date
In the tables above, it is possible to note the significant emphasis on smaller plants and
towards utilizing solar plants in or on buildings. The FiT system is considered a successful tool for
RE incentive in any given market. Regarding the cost effectiveness of Malaysia`s FiT policy,
(Muhammad-Sukki, 2011) shows that most typical PV installations obtain between 5.0-10. %
returns over the project lifetime. With a growing number of funding resources for R&D activities,
and supported by numerous government policies, solar could become one of the major renewable
sources for electricity generation in Malaysia.
In comparison to other installation models, (Muhammad-Sukki, 2011) finds only one that
surpass the average employee provident fund and while not immediately profitable over other
investment options, investors have taken advantage of the tariff to greatly expand PV production.
Additionally, the annual discount rate is a built-in reduction of the FiT paid to the producer in order
to track changes in market costs and also account for technology advancements as a technology
matures.
Malaysia uses a fixed 8% discount rate for all FiT applications. This fixed rate provides
security to investors when considering a PV project (Muhammad-Sukki, 2011). The report
stipulates that one of the principal requirements for a successful FiT is to be stable (Couture, 2010).
However, PV technology rapidly decreases which would ultimately hamper the funding of the FiT.
To fund the FiT, the Malaysian government originally implemented a 1.0% and later,
increased to 1.6% the tariff on electricity consumption (Pacudan R., 2014). This distributes the
cost of the program across the entire population which insulates the program from political or
regulatory budgetary constraints. Moreover, given the energy market structure in Malaysia (single-
buyer and highly regulated), this additional revenue is used for other sources such as subsidies to
liquid natural gas electricity generation.
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a) Net Metering
In 2016, Malaysia started its first large scale net metering policy (SEDA, SEDA Portal,
2018). While still in its infancy, net metering has the potential to greatly incentivize small scale
PV implementation. The policy is designed for achieving a capacity of 0.50GW total generation
by 2020, which will be met by phased quotas for each year leading up to 2020. Also, prioritizes
the Peninsula over Sabah (90%-10%) and residential customers are limited to 72 kW, while
industrial customers recently had the capacity of 1.0 MW removed in favor of a 75% of maximum
demand on their current system.
The current structure allows for prosumers to recoup the displaced cost of the energy they
generate. Equation 1 shows the current calculation and it requires the implementation of a second
meter which together with start-up costs might increase the bill. This is opposed to three-meter
systems found elsewhere in the world (Tenaga, Guidelines Solar Photovoltaic Installation on Net
Metering Scheme, 2015).
𝑁𝑒𝑡 𝐵𝑖𝑙𝑙 = [𝑘𝑊ℎ 𝐶𝑜𝑛𝑠𝑢𝑚𝑒𝑑 ∗ 𝐺𝑎𝑧𝑒𝑡𝑡𝑒𝑑 𝑇𝑎𝑟𝑖𝑓𝑓] − [𝑘𝑊ℎ 𝐸𝑥𝑝𝑜𝑟𝑡𝑒𝑑 ∗ 𝐷𝑖𝑠𝑝𝑙𝑎𝑐𝑒𝑚𝑒𝑛𝑡 𝐶𝑜𝑠𝑡]
Equation 1
Moreover, the displacement cost is calculated by yet another adjustment to energy cost by
other-than-renewable means using a tariff. The table below shows the different set displacement
costs based on the connection voltage for any of the renewable energy resources.
Table 3 – Displacement Costs
Peninsula (MYR/kWh) Sabah (MYR/kWh)
50 kV to 230 kV - 0.21
1 kV to 50 kV 0.24 0.22
< 1 kV 0.31 0.30
These displacement costs are lower than the market rate which is set by three electrical
utility monopolies in Malaysia. SEDA operates a live system that updates prosumers on the current
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status of available quotas and while 2018 is currently showing an increase in applications for net
metering, only 2.6% of the available quota from 2016 and 2017 had been used (SEDA, SEDA
Portal, 2018).
III. ANALYSIS OF TECHNOLOGY OPTIONS
i. Large scale solar (LSS)
Malaysia has great potential for LSS power due to its location in the equatorial region
(Mekhilef S, 2012). In the Green Technology Master Plan 2017-2030, LSS farms are promoted
and targeted with 1.2GW until 2020, of which 0.20 GW will be in Sabah and 1.2GW in Peninsular
Malaysia (Malaysia Ministry of Energy, 2017).
With the launch of feed in tariffs in 2011, LSS farms became more popular in Malaysia.
Since 2016, several PV plant projects totaling 0.33GW in combined capacity were approved,
showing the increasing interest and activity in LSS. Figure 13 in Appendix A2 displays the location
of those plants (Energy Commission, 2017).
a) Large Scale Solar Potential
This section identifies and quantifies the theoretical potential for LSS PV plants in
Malaysia (in contrast to later presented scenario and sensitivity analyses, this total theoretical
potential is referred to as base case in the following). Therefore, first the solar radiation in specific
areas is examined. Second, land availability is identified. Third, based on this information, the
theoretical power potential is calculated.
• Solar Radiation in Malaysia
Solar radiation is taken from several studies which refer to the NASA website of Surface
meteorology and solar energy. Per year, the average of solar insolation is 1600 kWh/m2 (ranging
from 1400 to 1900 kWh/m2, see graphic below) with recorded sunshine in the range of 4-8 hours
daily (Muhammad-Sukki, 2011). This has significant implications for the location decision of LSS
plants. In terms of radiation, the north of Peninsular as well as Sabah have the greatest potential.
For the daily sun shine (in terms of hours), 6 hours is assumed as the median between above
mentioned 4 and 8 hours/day. Average PV yield based on current development in the country
suggests that 6 hours is an optimistic approximation (SEDA, 2011).
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Figure 1 – Yearly average solar radiation (kWh/m2 )*
* (Muhammad-Sukki, 2011)
• Land Availability
The total area of Malaysia is about 330,000 km2 of which almost 120,000 km2 is made up
of Sarawak, 74,000 km2 by Sabah, and 130,000 km2 by Peninsular Malaysia (Mekhilef S, 2012).
In order to determine the land availability for LSS plants in Peninsular, a study by (Sabo, 2016)
and (Sabo, 2017) is used. The figure below shows a map of Peninsular Malaysia to characterize its
current land-use.
Figure 2 – Current land-use in Peninsular Malaysia*
* (Sabo, 2016)
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The criteria used to detect potential LSS locations include regional solar radiation,
orography (elevation, slope and hill shade), land character (exclusion of water bodies,
environmentally sensitive areas, vulnerable areas like flood plains or areas vulnerable to landslides,
and developed urban areas), technical (access to grid and roads), and acreage (3.3 acres must be
available per individual MW of capacity, at least 170 acres for 50. MW PV plant).
Applying these criteria, the potential area suitable for large scale solar plants in Peninsular
Malaysia is 101,km2 (7.6 %). The figure below displays the result.
Figure 3 – Large scale solar suitable area in Peninsular Malaysia*
* (Sabo, 2016)
The potential area for Sabah and Sarawak were roughly approximated based on the result
(7.6 % of land area in Peninsular) and the criteria of the same approach. Since Sabah and Sarawak
have similar landscapes like Peninsular, but less roads and grid lines (since population density is
lower) and more mountain range, the factor of 7.6 % is reduced to 6.0 % for Sabah and 4.0 % for
Sarawak (since the above-mentioned modifications apply even stronger here and sun radiation is
significantly lower). This means a potential area of 4.4 x 103,km2 in Sabah and 5.0 x 103 km2 in
Sarawak for large scale solar plants.
• Theoretical Electricity Generation Potential
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To calculate the total theoretical electricity generation potential (EGP) of large scale PV
in Malaysia, average annual solar radiation (ASR), a packing factor of 80 % (PF, which expresses
the percentage of actual useful area of the PV panel that absorbs solar radiation (Yang, 2015)),
total potential area, and average panel efficiency of 15 % (PE, which is assumed to already account
for degradation over time by taking the average value of an 16 % efficient solar module at t=0 and
annual output drop of 0.60% (Hernández-Moro, 2013)):
𝐸𝐺𝑃 = 𝐴𝑟𝑒𝑎 ∗ 𝑃𝐹 ∗ 𝐴𝑆𝑅 ∗ 𝑃𝐸 Equation 2
Table 4 – Electricity Generation Potential
Location Electricity generation potential (106
GWh/year)
Peninsular 2.0
Sabah 0.93
Sarawak 0.92
Total 3.87
Based on this electricity generation potential, the greenhouse gas reduction potential was
calculated to be 3 Gt CO2 per year.
• Installed Capacity
The associated installation capacity (IC) is calculated by dividing the total electricity
generation potential per year by the average number of sun hours per year (6 hours/day*365
days/year). This leads to the required installation capacities presented in the table below, used to
realize the electricity generation potential.
Table 5 – Maximum Potential Installed Capacity
Location Installation capacity (GW)
Peninsular 920
Sabah 430
Sarawak 420
Total 1,770
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b) Economic analysis
• Costs
Data for investment and variable cost was taken from a feasibility study of a 5.0 MW solar
power plant in Perlis, Northern Malaysia conducted in 2015 (Kassim MP, 2015). These values can
be found in Appendix A2. Land prices are difficult to estimate and vary for the different parts of
Malaysia. For the base case, a constant land price of 111,000 $/MW is considered for Peninsula
Malaysia (according to the feasibility study) and lower prices for the less populated and developed
Sabah and Sarawak.
Solar module prices are adjusted based on the most recent available data for solar module
prices in Malaysia. A price (including a Goods and Services tax of 6.0 %) lower than the average
module price (2.5 MYR/W, 0.63 $/W) is considered since large scale projects usually enable
cheaper prices due to bulk orders. Compared with other studies, particularly the IEA and SEDA
national survey report of PV power applications in Malaysia 2016 (IEA, 2016), these values for
the total system investment are conservative.
The annual costs consist of O&M and insurance. O&M are approximated and converted
from the same feasibility study in Malaysia that was used for the investment cost (48,000 MYR
per year for 5.0 MW or $0.0024 per watt) (Kassim MP, 2015) and annual insurance costs are
assumed as 0.25 % of the capital cost of the system (Hernández-Moro, 2013).
• Levelized Cost of Energy (LCOE)
With these costs, an assumed lifetime of 21 years, and a discount rate of 6.0 % (Sabo, 2017),
the LCOE is $0.090 per kWh which matches with current values in the 2016 Lazard report, widely
considered to be a benchmark (Lazard, 2017). This value is slightly lower than the average
electricity price for households (0.39 MYR/kWh, 0.10 $/kWh) and for industrial companies (0.41
MYR/kWh, 0.10 $/kWh), and significantly lower than for commercial companies (0.47
MYR/kWh, 0.12 $/kWh), which points to the economic feasibility of the project (IEA, 2016).
Due to the nature of the LCOE and the fact that all cost components are considered per
capacity (and not generated electricity), the LCOE is constant for different energy generation
potentials but varies with the capacity as can be observed in later scenario and sensitivity analyses.
This means that with the current model an increase in energy generation potential leads to a
proportional increase in the required installation capacity and thus the associated costs. Since the
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LCOE compares the cost to generated electricity, the LCOE does not change. Therefore, this does
not capture the real dynamic situation (e.g. through learning curves and consequently decreasing
production costs). The developed model is viewed as sufficient for evaluating the current state with
static efficiencies, solar radiation per area and packing factors (and therefore static purchasing and
implementation prices per installed watt). A sensitive analysis was conducted and can be found in
Appendix A2 to account for this static characteristic (and for the uncertainty in some other key
variables of the model).
c) Scenario Analysis: Realizing 30 % of renewable energy in 2030
Part of Malaysia’s plan to reduce greenhouse gas emissions is to reach 30 % of renewable
energy in generation capacity by 2030. This scenario presents the implications of this goal being
reached solely with LSS plants. According to a forecast by (Haiges, 2017), Malaysia’s installed
capacity will be 123000 MW in 2030. Currently, approximately 18.6 % of the installed capacity,
or 5800 MW, are supplied by renewable energy sources (PSIE, 2014). Consequently, 31,000 MW
net additions are required until 2030. The values below show the summary of this scenario and
state its feasibility and profitability.
The project revenue is based on feed in tariffs. Assuming that large scale plants have
capacities between 1 MW and 10 MW, a FiT rate of $ 0.24 per kWh is considered (with a
degression rate of 8 %), and an effective contract period of 21 years. Additionally, it is assumed a
discount rate of 6 %. Moreover, the payback period is calculated to estimate the number of years
required for the cash flow to equal the total investment, i.e. how quickly the cost of the investment
can be recovered. The payback period for this project is six years.
Table 6 – Scenario 30% RE Results
Total required installation capacity (GW) 31
Total required energy generation potential
(GWh per year)
68,000
Emission reduction (Gt CO2/year) 0.050
Total investment costs ($Billion) 65
Total annual costs ($MM) 240
LCOE ($/kWh) 0.090
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Figure 4 – Discounted Cash Flow
Figure 5 – Payback Period
ii. Rooftop potential
-80.00
-60.00
-40.00
-20.00
0.00
20.00
40.00
60.00
0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21
TIME (YEARS)
-70.0
-60.0
-50.0
-40.0
-30.0
-20.0
-10.0
0.0
10.0
20.0
0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21
TIME (YEARS)
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There are two types of solar PV connections: on-grid and off- grid. An on-grid connection
simply means that there is interconnection between the building and the national grid, allowing
any generated electricity from solar PV to be exported into the grid. This type of connection is
normally associated with the Feed-in Tariff (FiT) scheme. An off-grid connection on the other
hand does not have any link to the national grid. This type of configuration is normally connected
to a storage bank such as battery, which will store the electricity and is suitable for remote places.
In 2016 alone, a total of 3794 applications for PV under the FiT were approved with a total capacity
of 101,60 MW. For earlier attempts refer to Appendix A3.
• Land availability
The potential of BIPV in the residential, commercial, and industrial sector is huge. For the
residential sector, approximately 2,500,000 households are suitable for BIPV. An evaluation
conducted by Sopian et al assesses the rooftop area available in Malaysia for solar installations
after consideration of orientation, shading and other factors. A typical roof surface of a household
(detached homes), is approximately 10 m2.
Most commercial businesses are located in urban areas with a potential for PV application.
Approximately 45,000 building can be considered for BIPV. About 10 % of these buildings are
not suitable for BIPV due to shading or obstacles on the roof. Shopping mall and a business park
have an available PV installation of 1.0 x 103 m2.
The industry sector is usually bordering the urban centers. They offer large flat roof areas
averaging 2.0 x 103 m2. 10% of the buildings are again not suitable because of influencing factors
(shading, construction not able to carry additional weight). Thus, the total available surface for
BIPV is 110,000,000 m2 (Residential = 2.5 x 106 x 10 m2, Commercial = 4.0 x104 x 1000 m2 and
Industry = 2.1 x 104 x 2000 m2) (Sopian K, 2005).
• Generation Potential
A tropical country such as Malaysia is generally hot all year and experiences its rainy
season during the end of the year. For rooftop solar calculations, the same values regarding solar
radiation are assumed as in the LSS part (average of 6 hours of daily sunshine and average solar
energy received between 1400 and 1900 kWh/m2 annually).
The area considered in theoretical potential for 1kWp of solar installation is of 9.5 m2, while
the total area available is 110 MMm2. Therefore, the installation potential is about 12 x 103 MWp.
20
a) Results
As per the report by SEDA and IEA, cost breakdown for rooftop solar (including goods
and services tax in Malaysia) is shown in the following table.
Table 7 – Breakdown for Rooftop Solar 2016*
* (SEDA, 2018)
Taking average expenses for this project, the cost for a 1kWp system is RM 7,830 (USD
1977). The cost to attain maximum possible installation is RM 90.6 billion (USD 23 billion).
Moreover, the O&M (includes the cost to remove dirt and dust on the PV panel and the PV panel
direction adjustment) cost is RM 10/kW/year.
Summarizing the assumptions for the base case scenario: (i) One entity is taking hold of
all the rooftop area available for installation; (ii) The investment is made in the first year itself
without any loans; (iii) Derating factor=90%; (iv) Discount rate=6%; (v) Lifetime of the system=21
years; (vi) Current FiT rates @RM 0.89, guaranteed for 21 years by SEDA are considered for the
analysis (v) Dollar exchange rate: 1 MYR = 0.252573 US$ (Tenaga, 2015) , (SEDA, 2018).
21
Figure 6– Rooftop Solar Case Base Scenario: Discounted Cash-Flow SEDA FiT rates
As the calculations show, rooftop solar can be profitable with the current FiT rates. The
LCOE for the project is $ 0.1524/kWh. Even though the capital cost for this endeavor would be
high, it makes sense to encourage solar rooftop installations considering the long-term benefits.
Also, as subsidy is being provided to low-income households (if their electricity bill is less than
RM 20 (US$ 5.05), their whole bill is exempted from payment) which can be a large burden on
state funds.
IV. CARBON EMISSIONS AND TRADING POTENTIAL
Electric power consumption in Malaysia has grown substantially since 1970, when its
economic dominance shifted from the primary sector (mainly agricultural) to the secondary sector
(industrial) (Begum RA, 2015). Currently, economic development in Malaysia is moving towards
the services sector, which is an energy-intensive sector (Begum RA, 2015). Meanwhile, the
government has set a voluntary target to reduce GDP emission intensity 35% by 2030 (World Bank
Group, 2017) compared to 2005 levels as well as a goal of achieving high-income nation status by
2020 (NEAC, 2009). Carbon prices have the potential to reduce emissions because they increase
the price of carbon-based energy, which decreases demand for it (World Bank Group, 2017).
Pricing carbon can lead to substitution towards less carbon-intensive forms of energy and lower
demand for energy overall. Refer to the Appendix A4 for carbon prices in the EU market.
22
As a developing country, Malaysia joined the CDM voluntarily as one of the non-Annex I
countries. The CDM allows Annex I countries to invest in projects in non-Annex I countries and
receive credits for certified emission reductions (CERs). It can help industrialized countries meet
their obligations under the Kyoto Protocol in a cost-efficient manner while promoting sustainable
development in non-Annex I countries (Zainuddin ZB, 2017).
After joining the UNFCCC on 9 June 1993 and following ratification on 13 July 1994,
Malaysia officially became a member in the Protocol on 4 September 2002 (NRE, 2005). Many
projects in Malaysia have been successfully registered as CDM projects since then. This had
motivated other corporate sectors in the country such as power manufacturing, waste management,
forestry, oil and gas manufacturing, agriculture and transportation to proactively participate in
CDM project applications (Lim X, 2013). By August 2012, the CDM had received a total of 4460
CDM projects in the pipelines. Out of the total CDM projects, 69% are renewable energy projects
and 2.42% are in Malaysia.
In order to simulate the financial upside of an emissions trading scheme implementation in
Malaysia, the analysis for Rooftop Solar and Large Scale Solar takes into account that only 20%
of global annual GHG emissions are covered by carbon trading. The estimation is done considering
the report from (World Bank Group, 2017) in which it is mentioned that European Union
Emissions Trading System – ETS covers 40% of the emissions and in order to be conservative, it
is considered for the estimation that 20% of the emission reduction will be covered by the trading
scheme.
Also, considering the difficulty of forecasting carbon prices and the fact that Malaysia does
not have an ETS system already implemented, the prices used in the evaluation are based on the
EU ETS system. Therefore, given a €13.82 of CO2 European Emission Allowances price as
observed in April 2018 and no discount rate, the results for LSS and Rooftop Solar are shown
below. For more detailed information about the CO2 emissions and ETS systems, refer Appendix
A4.
23
Table 8 – Large Scale Solar and Rooftop Carbon Potential Results
The results demonstrate the carbon trading potential in both models. As the prices present
some variability and are different between ETS systems, the evaluation is considered conservative.
Note that the emissions trading scheme is still under development in Malaysia. The trend is that
the ETS will be implemented in the face of the international emissions trading market growth.
V. CONCLUSIONS
a) Challenges and further research for Large Scale Solar
Target conflict land use: For the implementation of large scale solar plants, much land is
required, and it is currently predominantly used for palm oil or covered by forests and reserves.
Further research is needed here to determine whether the large scale solar has higher economic
potential in the long term than the established palm oil industry and to which extent land is
available for both industries.
Moreover, there is a target conflict with forests since those cannot be removed without far-
reaching impacts on the environment, considering their CO2 capture (Turney, 2011). Other
important forest-provided services include the generation of wood and pulp, moderation of local
air temperatures and mitigation of flood waters by tempering the runoff hydrograph (Turney, 2011).
This last point in particular sticks out for Malaysia since it faces heavy rainfalls during monsoon
season (see next point).
The applied criteria to determine the available land included the exclusion of
environmentally sensitive areas, vulnerable areas like flood plains or areas vulnerable to landslides
and therefore is likely to already account for those mentioned concerns. The maps showing current
Emissions Reduction
(Gt CO2/year)
Carbon Trading Price (EUR/tCO2 )
Coverage Factor
(%)
Conversion Rate (EUR to US$)
Financial Upside (Million
US$/year)
Large Scale Solar 0.05 13.82 20% 1.18 163.08
Rooftop 0.02 13.82 20% 1.18 65.23
24
land use and the result of potential land sites display that no land was determined as ‘available’
that is currently forested.
Monsoon seasons: Heavy rainfalls during monsoon seasons are another major concern. It
is worth mentioning that the considered average values for solar radiation (per year) already
account for those seasons that are characterized by heavy rainfalls and high cloudiness. Moreover,
potential damages due to monsoons are already considered in the insurance costs and therefore
included in the LCOE. However, it is highly recommended to build LSS plants in regions that are
at low risk for monsoons (e.g. the west of Peninsular Malaysia). Additionally, storage solutions
are necessary, particularly for decentralized rooftop solar applications in order to guarantee
electricity even in cases of hour- or week-long rainfalls. Future research should therefore detect
whether those as ‘available’ determined land areas are potential monsoon regions, calculate the
required peak power generation capacity supplied by low-carbon and monsoon-independent
alternatives like natural gas, and investigate the cost impacts of decentralized storage solutions for
solar power that would enable solar-powered electricity supply even during monsoon seasons.
Energy security and safety: Conventional electricity generation is more reliable than solar
energy which depends on the amount of solar radiation and therefore does not generate electricity
during nights. Since storage options are expensive and not sufficient for large-scale
implementation yet, energy security is a reasonable argument against the 100% large scale PV
scenario.
Initial investment and financial support mechanisms: One of the main barriers for large
scale solar as shown in the calculations above is high capital investment. Banks often do not secure
financing of large-scale projects due to too low cash-flows for the perceived higher risks of
renewable energy investments (Petinrin, 2015). Consequently, governmental incentives, financial
support mechanisms, and the attraction of (foreign) direct investment from third party investors
are required to promote large-scale developments in solar installations (Huda M. O., 2017).
Public awareness: Benefits, particularly environmental and economic potential, legal
requirements, and financial aspects are not communicated effectively and therefore hamper
investments (Ab Kadir, 2010). Education and training in renewable energy and energy efficiency
is therefore urgently required and could be implemented in schools, universities, and mass media.
25
Externalities: Not only are environmental and social consequences (e.g. climate change and
health implications) not internalized in the price for electricity generated by conventional
technologies, but also are fossil fuel subsidized (Ab Kadir, 2010). Therefore, current prices create
an imperfect market and do not incentivize deployment of renewable energies. Reducing the
subsidies for fossil fuels and instead subsidizing renewable energy technologies helps to internalize
environmental and social costs of fossil fuels and will accelerate the installation of large scale solar
plants.
b) Challenges and further research for Rooftop Solar
Individual Installations:
A study was carried out to analyze the return from a solar PV installation as a form of
investment compared to other investment tools available in Malaysia. Malaysians could invest in
unit trusts, national unit trusts, Employee Provident Fund (EPF) government bonds, fixed deposits
and savings accounts. This study, however, indicates that the FiT return is one of the lowest
compared to most of the investment tools available in Malaysia, which further suggests that
Malaysians might not be interested in considering solar PV as a form of investment
(MuhammadSukki, 2011).
c) Regulatory Recommendations
Malaysia and SEDA have been very proactive in implementing modern and robust
incentives and policies in support of their RE goals. However, the current trend lines do not indicate
that their goal of 30% RE production in 2030 will be met (Chen, 2017). To optimize the current
policy structure, the following recommendations should be further analyzed.
The FiT system must be extended. As PV technology become cheaper, investment in
smaller, distributed systems will increase. Incentivizing individual consumers to take advantage of
the FiT will only further increase this effect. There are two areas where the FiT policy can be
improved: implementing a responsive degression model and improving funding for the FiT by
incorporating more RE friendly methods.
The current degression rate of 8% allows for a consistent valuation of projects to be
undertaken by investors. This stability is attractive but is better suited for more developed and less
volatile technologies such as wind or hydro. The variability in PV technology advancement needs
to be accounted for. Germany recently adopted a responsive system based on previous year market
26
conditions and PV capacity. This policy will slow the degression rate if new installations are low
or accelerate the degression rate if installations are high (Couture, 2010). However, in emerging
markets such as Malaysia, an even more responsive approach may be beneficial. Setting degression
rates to be reevaluated at intervals such as every two years will allow real pricing data to drive the
degression rates. While this will eliminate the stability that fixed rates provide, it will ensure that
accurate data influences the rate. In the potentiality of a technology price increase, this system also
accounts for that which would provide a risk mitigation to investors.
As previously stated, the FiT is funded by a 1.6% tariff on consumer electrical consumption.
This situation is more complex as the FiT funding tariff is the intersection with the rest of
Malaysia’s electricity generation market. Specifically, Malaysians pay significantly less than the
natural price for imported LNG due to large subsidies. Coal is also heavily subsidized (Bekhet HA,
2014). While the subsidy rationalization program, enacted in 2010, has effectively reduced these
subsidies to ease strain on the national budget, the cost does pass through to consumers. These two
factors combine to make an increase to the FiT quota unsupportable. Two novel solutions that
should be explored are Green Energy bonds and implementing a carbon tax.
Green Energy bonds allow for investors to commit to rising trends in renewable energy
investment while ensuring a stable return on investment. The return on these bonds would have to
be nominally lower than the return on FiT investing, but current trends in green bonds have shown
success in both China and India (Williams, 2017). Depending on the investment in these bonds,
additional projects could be undertaken beyond funding the FiT.
Implementing a carbon tax can also improve the funding for FiT. While this will inevitably
increase consumer energy prices given the large share of electricity generated by non-renewable
means, the internalization of the impact of the release of carbon is one of the Malaysian energy
market's greatest failures. Given Malaysia’s current market structure (3 utility providers who enjoy
a monopoly in their respective regions) and lack of commitment to energy investment, a tax is
preferable in the first stages in order to provide price certainties during cost valuation (Change.,
2009). As the program matures, a cap and trade policy can be implemented. Regardless, further
analysis on the scope and applicability of such a carbon tax should be undertaken immediately to
correct the effect of carbon externalities in Malaysia.
27
Moreover, the recommendations are not focused on total substitution of the gas and coal
sources but on a more diversified mix. Natural gas always arises as a highly attractive energy
source and combined-cycle and gas-fired power plants are an efficient option to guarantee energy
supply, especially during peak load hours and on electricity markets with high penetration of
renewable energy sources. Therefore, a more diversified mix does not represent backing down
from gas and coal development, but a broader range of investments and subsides.
d) Non-Regulatory Recommendations
Critical to encouraging both economic growth and adherence to their renewable portfolio
standards is private investment in renewable energy sources. Green energy bonds can serve this
purpose as well. For example, Apple has a large green bond portfolio and is seen a success in the
privatization of renewable energy capital acquisition. Encouraging this behavior in Malaysia will
enhance private funding for renewable energy.
As previously mentioned, Large Scale Solar projects were capped by SEDA-mandated
quotas but funded by private capital investment. This method of public-private partnership has
proven successful in utilizing the financial resources of private entities to meet the known enacted
standards. Finally, a system implemented in India of encouraging private power purchasing
agreements between building owners and solar energy generation firms is also promising, allowing
firms with capital available to finance the construction of solar generation plants and sell that power
to the building owners at a lower rate than traditional sources. This will require an adjustment to
FiT quotas to permit more rooftop solar allowances.
28
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32
APPENDIX
A1 ENERGY AND ECONOMY APPENDIX
Figure 7 - Installed Capacity (Million Kilowatts)
Figure 8 – Electricity Generation Mix (GWh) 2015
A2 LARGE SCALE SOLAR APPENDIX
Figure 9 – Location and capacity of large scale solar plants in Peninsula
Malaysia*
0
5
10
15
20
25
30
35
40
Total Electricity (Million Kilowatts)
Total Renewable Installed Capacity (Million Kilowatts)
Total Fossil Fuels Electricity Installed Capacity (Million Kilowatts)
10.74 %
46.29 %
41.04 %
0.03 % 1.05 % 0.85 %
Hydro
Gas
Coal
Oil
Diesel
Others
33
Table 10 – Yearly radiation in Malaysian towns
Figure 10 – Daily average solar radiation (MJ/m2 )*
* Peninsular Malaysia Electricity Supply Outlook 2017
34
LSS Base: Initial Costs
Figure 11 – Initial investment costs in Peninsular (%)
* ( Petinrin, 2015)
8.81
5.24
31.73
29.73
7.22
12.93 3.25 1.09
Management cost Land acquisition
Building, infra and civil work Solar modules
Inverters Installation cost
Electrical equipment Others (Legal Fees/General)
35
LSS Scenario analysis
Since the impact is difficult to fully grasp by those potential numbers, another scenario
shows the results for implementing a single large scale solar farm, here assumed as a 5 MW solar
park in Peninsular Malaysia.
(i) Scenario 5 MW Single Large Solar Park
The scenario shows the most tangible and practical results for implementing a single large
scale solar park in Peninsular Malaysia. The values below show that also the installation of a single
solar farm is profitable with the assumed numbers. But still even for a single plant, the initial
investment cost is high which is one of the main challenges of large scale solar. Project revenues
are based on FiT rates as described in the LSS main part.
Table 11 – Scenario 5.0 MW Results
Total installation capacity (MW) 5
Total energy generation potential
(GWh/year) 11
Emission reduction (kt CO2/ year) 6900
Total investment costs (MM$) 11
Total annual costs ($) 39000
LCOE ($/kWh) 0.10
NPV (MM$) 6.8
36
Figure 12 – Scenario Discounted Cash Flow
Figure 13 – Scenario Payback Period
-12
-10
-8
-6
-4
-2
0
2
4
0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21
TIME (YEARS)
-12
-10
-8
-6
-4
-2
0
2
4
6
8
0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21
TIME (YEARS)
37
LSS Sensitivity analyses
Since all parameters are based on several assumptions and since values are subject to
change in the future, a sensitivity analysis was conducted to observe how the results of the study
change based on variable discount rates, solar modules efficiencies, average solar radiation per day
and average implementation costs of large scale solar projects. The results are presented in the
form of graphics below.
Discount rate: The results indicate that the higher the applied discount rate, the higher the
levelized cost of electricity and the lower the net present value of large scale solar projects. The
basic discount rate of 6 % was used after reviewing several studies. One should have in mind that
a higher discount rate of up to 10 % is not unusual for solar PV projects (Hernández-Moro, 2013).
Figure 14 – Parameters Sensitivity Analysis Results: Discount Rate and LCOE
Solar module efficiency: Efficiency is likely to increase in the following years and decades
due to technology innovations and improved production technologies. The following graphics
show the potential for even higher solar energy generation, larger emission reduction with the same
available area due to efficiency increases.
Figure 15– Parameters Sensitivity Analysis Results: Efficiency and Energy generation potential
- 0.02 0.04 0.06 0.08 0.10 0.12 0.14 0.16 0.18
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
Discount rate (%)
Discount rate and LCOE
LCOE ($/kWh) average household electricity price ($/kWh)
38
Figure 16– Parameters Sensitivity Analysis Results: Efficiency and Emission reduction potential
Average solar radiation per day: Daily solar radiation in Malaysia averages between 4 and
8 hours (Sabo, 2016). The installed capacity highly depends on that number. Lower values increase
the LCOE to the point where it is above the average household electricity price. Therefore, it is
strongly recommended to identify available land areas with longer average solar radiation
(particularly in northern Peninsular and Sabah) since the basic calculation of this report considers
only an overall average of 6 hours for Malaysia as a whole.
-
1.00
2.00
3.00
4.00
5.00
6.00
10 12.5 15 17.5 20
Efficiency (%)
Efficiency and Energy generation potential
- 0.50 1.00 1.50 2.00 2.50 3.00 3.50 4.00 4.50
10 12.5 15 17.5 20
Efficiency (%)
Efficiency and Emission reduction potential
39
Figure 17– Parameters Sensitivity Analysis Results: Average radiation and required installation
capacity
Figure 18– Parameters Sensitivity Analysis Results: Average daily radiation and LCOE
-
0.50
1.00
1.50
2.00
2.50
3.00
4 5 6 7 8
Average daily radiation (h)
Average daily radiation and Required installation capacity
-
0.02
0.04
0.06
0.08
0.10
0.12
0.14
4 5 6 7 8
Average daily radiation (h)
Average daily radiation and LCOE
LCOE ($/kWh) average household electricity price ($/kWh)
40
Average implementation costs: As argued in the main body of this report, the current model
is static in the sense that it does not capture the expected increases in efficiencies and therefore
price drops per installed watt which leads consequently to the problem of constant LCOE for
different parameters (see section “economic analysis”). Therefore, consequences of different prices
per installed watt are displayed below. Since this report shows the total theoretical potential that is
achievable in the long-term future, lower prices per watt due to increases in efficiency are highly
probable. History shows and several studies projects that due to the laws of mass production and
experience learning, future costs will come down substantially in the next decades (Hernández-
Moro, 2013). Therefore, the current estimations with static prices is conservative. The graphics
below show how investment costs and LCOE increase.
Figure 19– Parameters Sensitivity Analysis Results: Average implementation cost and LCOE
-
0.02
0.04
0.06
0.08
0.10
0.12
1.5 1.55 1.6 1.65 1.7 1.75 1.8 1.85 1.9 1.95 2 2.05 2.1 2.15
Average implementation cost ($/W)
Average implementation cost and LCOE
LCOE ($/kWh) average household electricity price ($/kWh)
41
A3 ROOFTOP SOLAR APPENDIX a) Earlier attempts
Small Renewable Energy Power Program (SREP): Launched on the 11th May 2001 to
encourage the participation of private sectors in the RE sectors, and the possible sources recognized
under this program including solar, biomass, biogas, wind, and mini-hydro energy. The RE
developers can sell the generated electricity to utility suppliers, such as Tenaga Nasional Berhad
(TNB) in West Malaysia, or Sabah Electricity Sendirian Berhad (SESB) in Sabah. The electricity
is then sold to end-users through the National Grid. Despite of the high expectation (5.0 x 102 MW)
when SREP was launched, from 2001 to 2005, only 12 MW of RE from two projects went on-grid
(Wong, 2015).
The Malaysia Building Integrated Photovoltaic (MBIPV): to investigate the feasibility of
solar PV in urban areas, the Malaysia Building Integrated Photovoltaic (MBIPV) Technology
Application Project was launched on the 25th July 2005 with support and funding from United
Nations Development Program (PSIE, 2014). The main objective of this program was to reduce
long-term cost of BIPV technology in Malaysia, which would lead to an increase in BIPV
technology applications whilst reducing emissions of green- house gases. The MBIPV project
focused on market development for BIPV technology and on building national capacity in three
major areas: (i) policy and education; (ii) technical skill and market implementation, and (iii)
technology development support (Muhammad-Sukki, 2011).
Solar Home Rooftop Program (SHRP): Launched by SEDA Malaysia on 24th September
2012 to boost the public participation in RE generation. Through this program, Malaysians can
participate in the RE as individuals. At the end of April 2013, a total of 15 MW was approved in
the form of 1079 Feed-in Approvals (FiA) application for individuals. The number rose to 1316
applications with the total capacity of 17 MW (Wong, 2015) at the end of August 2013 (SEDA,
2018).
42
A4 CARBON EMISSIONS AND TRADING APPENDIX
Figure 20 – CO2 European Emission Allowances
Table 12 – Weak points of EU and China ETS
43
* (Zhang M, 2018 )
Figure 21 – Share of GHG emissions covered
* (World Bank Group, 2017)
44
Figure 22 – Prices in implemented carbon pricing initiatives
45