giz support mechanism for re development in vietnam
DESCRIPTION
Hanoi, 19/09/2014 Ingmar Stelter, Program Manager Werner Kossmann, Chief Technical Advisor GIZ Viet Nam Energy Support Program Energy Sector Development Partners CoordinationTRANSCRIPT
Seite 1
Support Mechanisms for RE Development in Viet Nam
Hanoi, 19/09/2014
Ingmar Stelter, Program ManagerWerner Kossmann, Chief Technical Advisor
GIZ Viet Nam Energy Support Program
Seite 2
Technical Cooperation in Viet Nam
Page 3Energy Sector Development Partners Coordination19.09.2014
National Strategy
PDP VII objectives on RE: Increase in electricity produced from RE sources
5.6% 9.4%
2020 2030
Biomass Wind Biomass Wind
500 MW
1000 MW
Other RE
2000 MW
6200 MW
Other RE
5620 MW
2700 MW
Other RE: Biogas, Waste-to-Energy, Solar PV/ST, SHP etc.
Pla
nn
ed
In
sta
lle
d C
ap
ac
ity
Source: PDP 7
Page 4Energy Sector Development Partners Coordination19.09.2014
Barriers for RE Development in Viet Nam
Lack of national (comprehensive) law
for RELow electricity price
Limited data availability (and poor
data quality)
Limited capacities on central and provincial
level
Difficult access to information
Complex and unclear procedures for RE
investments
Limited access to financing (equity &
loans)
Page 5Energy Sector Development Partners Coordination19.09.2014
Wind PowerSHP
Existing Support Mechanisms for RE – I/II
Decision 18/2008/QD-TTg (18.07.2008)• In 2014: 2.7 – 3.2 US-Cents/kWh (depending on
season and daytime)• Avoided-Cost-Tariff, varied by year• Calculated annually based on 1 kWh electricity
avoided from the most expensive power plant connected to the national grid
• Duration of PPA: 20 Years
Decision 37/2011/QD-TTg (29.06.2011)• Feed-in-Tariff for Wind Power• Tariff: 7,8 US-Cents/kWh (6.8+1)• Duration of PPA: 20 Years• GIZ-supported; currently under revision
Page 6Energy Sector Development Partners Coordination19.09.2014
Solid WasteBiomass
Existing Support Mechanisms for RE – II/II
Decision 24/2014/QD-TTg (29.06.2014)• FiT for electricity from CHP-Biomass
Power: 5.8 US-Cents/kWh• Avoided-Cost Tariff for electricity from
other Biomass plants• Annually calculated based on the
avoided cost for 1 kWh electricity from imported coal
• Duration of PPA: 20 Years• GIZ-supported
Decision: 31/2014/QD-TTg (05.05.2014) • Feed-in-Tariff for electricity from MSW• Incineration: 10.05 US-Cents/kWh• Landfill-Gas: 7.28 US-Cents/kWh• Duration of PPA: 20 Years• GIZ-supported
Page 7Energy Sector Development Partners Coordination19.09.2014
Additional Incentive Mechanisms for RE
• Corporate income tax
• Years 1-4: tax exemption
• Years 5-13: 50% tax reduction
• Import tax (goods, machinery etc.)
• Varying levels of import tax, depending on type of imported goods
• Exemption on goods forming fixed assets, which cannot be produced locally
• Waiving of land use/lease fees
• Land is provided for free as part of the licensing agreement
These are substantial financial incentives for project developers. However, in a situation of financial stress, tax incentives cannot
cushion liquidity problems as there are no tax payments to be made.
Page 8Energy Sector Development Partners Coordination19.09.2014
Revision of the support mechanism for wind – I/III
• Methodology:
• Qualitative: interviews, questionnaires, assessment of exist. framework
• Quantitative: wind data, pre-/feasibility studies, international comparison
• General findings/recommendations (excerpt):
• FiT payment system should be a one-stop-shop (not VNEPF+FiT)
• Government guarantee for payments
• Better wind speed measurements and improved standards are required
• Enforce standard agreements for network connection and power purchase
Page 9Energy Sector Development Partners Coordination19.09.2014
Revision of the support mechanism for wind – II/III
• Basis for analysis:
• PDP target: 1GW wind power by 2020 (currently: ca. 50MW)
• Assumptions for CapEx, O&M, Capacity Factor: based on P/FS, questionnaires, international experience
• Required investment and assumed investor structure:
• 1GW by 2020 = ca. US$ 2.1 billion over the next 6 years
• At average debt level of 70% => US$ 630m equity and 1.47b debt
• This investment level cannot (should not) be reached with public investment only.
• Assumed investor types: highly-subsidized, strategic, fully commercial
Page 10Energy Sector Development Partners Coordination19.09.2014
Revision of the support mechanism for wind – III/III
• FiT calculation:
• All three investor types must be targeted with the FiT
• Assumed IRR: 10% (international experience)
• Basis for FiT calculation: Levelized cost of electricity (LEC)
• Also included: additional incentives like tax breaks etc.
• Result:
• Proposed FiT for on-shore installations: US-cents 10.4 / kWh
• Proposed funding scheme: Tariff-funded, i.e. through a levy on the electricity price: for 1GW by 2020 => less than 5VND/kWh
Page 11Energy Sector Development Partners Coordination19.09.2014
Bioenergy technologies applicable in Vietnam
Biomass- Sugarcane bagasse- Rice straw/husk- Timber waste
Biogas- Animal manure- Industrial wastewater- HDPE covered lagoon
Municipal Solid Waste- Incineration- Landfill Gas
Page 12Energy Sector Development Partners Coordination19.09.2014
FiT for non-CHP biomass power (avoided cost tariff)
Government opted for the avoided cost tariff based on imported coal as reference price for biomass
Reason to apply an avoided cost tariff based on imported coal:
• Coal thermal power plant has the highest share in power mix
• Avoid electricity generated from these plants
• Biomass power plants as substitution to provide base load in the system
Problem:
• Annually calculated and issued
• Fluctuating coal prices
• Inflexible in combination with 20 years PPA
Page 13Energy Sector Development Partners Coordination19.09.2014
Comparison of regulated prices with proposed levels for Bioenergy
Technology Proposed purchasing price (US-Cents/kWh)
Regulated level (US-Cents/kWh)
Sugarcane bagasse 5.6 5.8
Rice husk 7.34
Avoided cost based tariff
Rice straw 10.79
Timber waste 8.77
SW - Landfill gas 7.28 7.28
SW – Incineration 10.05 10.05
Page 14Energy Sector Development Partners Coordination19.09.2014
Thank you for your attention!!
Werner Kossmann Ingmar Stelter
[email protected] [email protected]
04 39 41 26 05 - 15 04 39 34 49 51 - 114
Page 15Energy Sector Development Partners Coordination19.09.2014
Backup: Installed capacity of electricity sources (2013)
Source Capacity (MW) Rate (%)
Big hydropower 13,260 43.21
Coal thermo-electric 7,116 23.19
Gas thermo-electric 7,446 2.97
Oil thermo-electric 912 0.22
RE
Small hydropower (≤ 30MW) 1,670 5.44
Wind 52 0.18
Biomass 150 0.49
Biogas/MSW 4 0.01
Solar PV 4 0.01
Total 30,684
Share of RE: 6.13%
Source: GDE 2014
Page 16Energy Sector Development Partners Coordination19.09.2014
Backup: Electricity production (2013)Source Output (GWh) Rate (%)
Big hydropower 56,943 40.51
Coal thermo-electric 26.843 20.93
Gas thermo-electric 42,650 33.26
Oil thermo-electric 95 0.07
Others 249 0.19
Exported 1,337 1.04
Diesel 7 -
Small hydropower 4,989 3.89
Wind 62 est. 0,05
Bioenergy (Biomass, -gas, MSW)
47 est. 0,04
Solar PV
Total 128,228
Share of RE: 3.98%
Source: GDE 2014
Page 17Energy Sector Development Partners Coordination19.09.2014
5.2 FiT calculations
The following assumptions result from the analysis of the
feasibility studies and questionnaires
• Average CapEx: 2.0 USD Mio. /MW
• Average O&M cost 35,000 USD / MW per year
• Average capacity factor: 30%
This is in line with international experience!
Page 18Energy Sector Development Partners Coordination19.09.2014
5.2 FiT calculations; international benchmark: CapEx
Page 19Energy Sector Development Partners Coordination19.09.2014
5.2 FiT calculations; international benchmark: OpEx
Page 20Energy Sector Development Partners Coordination19.09.2014
5.2 FiT calculations; international benchmark: Capacity Factor
Page 21Energy Sector Development Partners Coordination19.09.2014
5.2 FiT calculations
• Levelized Electricity Cost (LEC) as basis of analysis
• LEC is function of CapEx, discounted OM (OpEx) and total electricity production (Capacity factor)
• LEC(
• There is a direct relationship between internal rate of return (IRR) and LEC
• According to intl. experience, investors typically demand a project IRR of 10%, resulting in an LEC of US Cent 10.4
Page 22Energy Sector Development Partners Coordination19.09.2014
5.2 FiT calculations
Sensitivities derived from feasibility studies and questionnaires
Scenario CapEx [million USD/MW] O&M [T USD/MW*year] Capacity Factor Base
case
2.00 35.00 30.0%
CapEx+ 2.25 35.00 30.0%
CapEx- 1.65 35.00 30.0%
O&M+ 2.00 45.00 30.0%
O&M- 2.00 25.00 30.0%
Capacity+ 2.00 35.00 35.0%
Capacity- 2.00 35.00 25.0%
Page 23Energy Sector Development Partners Coordination19.09.2014
5.2 FiT calculations
Scenario LEC
Base Case 10.39
CapEx+ 11.51
CapEx- 8.83
O&M+ 10.80
O&M- 9.98
Capacity+ 8.91
Capacity- 12.47
Min. value 8.83
Max. value 12.47
Page 24Energy Sector Development Partners Coordination19.09.2014
5.3 Financing properties for developing the national wind power market
a. Target installation of 1 GW till 2020 requires investment amount of
about USD 2.1 billion over six years.
b. At average debt level of 70% this translates into:
• USD 630 million equity and
• USD 1,470 million debt
Page 25Energy Sector Development Partners Coordination19.09.2014
5.4 Developing the national wind power market by targeting diverse investor types
Market is assumed to be developed by mixture of three investor types
i. Highly subsidized investors like ODAs: access debt funding at interest rates of 1%-2% and demand single digit project IRRs. These early movers may provide funding of one third of target capacity and lay foundation of wind development by boosting synergy effects
ii. Strategic investors: like turbine manufactures, large industry enterprises and sovereign wealth funds: access pools of debt funding in the range of 6% and accept projects IRRs of about 10%.
iii. Fully commercial investors: have to resort to local loans at interest rates of 10% and above and demand two digit project IRRs. They require additional incentives like tax breaks.
Page 26Energy Sector Development Partners Coordination19.09.2014
5.5 Additional regulatory incentives have been considered and quantified at calculated FiT-level
Tax effects:
a. Reduced corporate tax contributes by 0.3 US Cent/kWh to FiT
b. Exemption from import tax e.g., 10% tax break corresponds to FiT
surplus of 0.7-1.0 US Cent/kWh
Page 27Energy Sector Development Partners Coordination19.09.2014
5.6 FiT funding for 1 GW target installation
Funding requirements for 1GW by 2020 at US 10.4Cent/kWh
Description 2016 2020 2021 2030FIT 10,4 10,4 9,4 9,4ttl Energy Sold TWh 158 243 273 545Wind Energy generated GWh 0 2628 4021 16556Average System Cost 7,7 8,8 9,28 10TTL Cost demand for funding Mio USD 0 42 46 -73Levy per kWh in VND 0 3,7 3,5 -2,8
Page 28Energy Sector Development Partners Coordination19.09.2014
5.6 FiT funding for 1 GW target installation (cont.)
Funding sources of FiT for 1 GW target installation
Tariff funded Tax funded
Advantage Disadvantage Advantage Disadvantage
• Transparency of subsidies
• Independent of budgetary needs
Requires “fair” allocation of costs of customer segments
• Independent of electricity prices for customers
• More flexibility with adjustments
Potential regular disputes with MoF over budget availability, and thus uncertainties for investors
Page 29Energy Sector Development Partners Coordination19.09.2014
Technology Levelized costs in US-Cents/kWh
Base (~ 10% IRR) Low (~ 8% IRR) High (~ 12% IRR)
Biomass Power Plant
Sugarcane bagasse 5.6 5.15 5.85
Rice husk 7.34 6.87 7.84
Rice straw 10.79 10.35 11.27
Timber waste 8.77 8.35 9.22
Biogas Power Plant
Animal manure 7.72 7.11 8.36
Industrial wastewater 12.29 11.20 13.31
HDPE covered lagoon 6.12 5.69 6.57
SW Power Plant
Landfill gas 7.28 6.65 7.95
Incineration 10.05 8.8 11.39
Levelized costs for Bioenergy based power plants