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- To achieve this, China must rapidly increase wind and solar installations to over 500 GW between 2020-2025 while phasing out coal capacity. Flexibility measures like markets and storage are also needed to integrate high shares of variable renewables.
- This Below 2°C scenario results in deep decar
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1. China Renewable Energy Outlook 2019
High proportion RE generation drives deep
decarbonization of power sector
Lars Møllenbach Bregnbæk
Chief Modelling Expert
China National Renewable Energy Centre
12.12.19
China Renewable Energy
Outlook
2019Energ
y R
ese
arc
h Institute
of Academ
y of M
acro
econom
ic R
ese
arc
h/N
DRC
Chin
a N
ational Renewable E
nerg
y C
entre
2. Electricity use doubled
• Efficiency increased
• Electrification
• Hydrogen based on
green electricity
introduced
End-use electricity demand in the Below 2°C Scenario
0
2,000
4,000
6,000
8,000
10,000
12,000
14,000
20182020 2025 2030 2035 2040 2045 2050
ElectricityConsumption(TWh)
Agriculture Construction Industry
Transport Buildings Hydrogen Production
4. Supply side transformation – Below 2°C Scenario
Next steps of the transformation - 2025
• Solar and wind generation exceeds 21% by 2025
• Coal capacity is maintained below 1100 GW
Next era achievements – 2035
• Rapid progress in power system decarbonization
• 80% RE share and 82% non-fossil share
The Beautiful China power system – 2050
• Wind and solar above 2600 and 2800 GW
• 90% RE in the power mix
2020 2025 2035 2050
Total Capacity (GW) 2053 2717 5124 6730
Coal 1023 1037 730 445
Natural gas & oil 106 133 197 152
Nuclear 53 66 87 100
Total RE Capacity (GW) 870 1482 4110 6033
Hydro 347 386 455 533
Wind 242 507 1763 2636
Solar 246 536 1836 2803
Bio 35 51 54 55
Geothermal 0.06 0.12 0.60 5.00
Ocean 0.05 0.28 0.87 2.00
Fossil fuels(%) 55% 43% 18% 9%
Non-fossil fuels(%) 45% 57% 82% 91%
Renewable(%) 42% 55% 80% 90%
5. 0
50
100
150
200
250
300
350
400
2018 2020 2025 2035 2050
Averageelectricitycost(RMB/MWh)
Fixed cost Variable cost w.o. fuel
Fuel cost Transmission cost
CO2 cost
Wind and solar electricity is the cheapest energy source
RE drives down average wholesale cost of electricity – including balancing.
Long-term cost per kWh is lower in Below 2, despite higher CO2-price
Below 2°C
Stated Policies
6. Wind deployment Solar deployment
0
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InstalledCapacity(GW)
Onshore Wind Distributed Wind Offshore Wind
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2018 2020 2025 2030 2035 2040 2045 2050
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Central East South North Northeast Northwest
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2018 2020 2025 2030 2035 2040 2045 2050
InstalledCapacity(GW)
Central East South North Northeast Northwest
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2018 2020 2025 2030 2035 2040 2045 2050
InstalledCapacity(GW)
Utility-scale PV Distributed PV CSP
7. Timely development of flexibility
• Our analyses show it is possible to integrate
large shares of fluctuating power production
from wind and solar
• It requires incentives for flexible production
from all types of power plants and flexible
consumption
• Introduction of power markets with dynamic
power prices is crucial for the integration
8. 14th FYP Critical phase for RE power installations
Add 53 GW wind and 58 GW solar per year
• Removal of subsidies
• New risk exposures
• Carbon pricing to take effect
• New deployment paradigms
Post-subsidy support to underpin the RE market
• RE Consumption guarantee
• Strict control on coal plants
• Reducing or eliminating non-technical costs
• Develop flexibility
• Subsidies remain for future RE & storage
0
200
400
600
800
14th FYP 15th FYP 16th FYP
Solar Wind
Wind and solar installations under five-year-plans
Power market reform towards national market
10. 1. RE promotion
2. Coal control
3. Energy efficiency measures
4. Power markets
5. Flexible power system
6. Efficient carbon control policy
Energy transition drivers
11. Decarbonisation of power generation
What drives the transition?
• Least-cost modelling driven by CO2-price
and CO2-cap (Below 2°C)
• Short-term, significant effort needed to
change direction – the ETS price signal will
not be enough!
• In medium-term, cost competitiveness of RE
technologies enables decarbonization at low
cost
• Adding new coal power capacity should be
avoided – will be stranded!
Power supply decarbonisation must be scaled-
up to allow decarbonisation through
electrification 0
500
1000
1500
2000
2500
3000
3500
4000
4500
5000
0
50
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2020
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2038
2040
2042
2044
2046
2048
2050
CO2emission(millitonne)
CO2price(RMB/tonne)
Stated Policies Below 2 Degree
12. The Below 2 scenario supports the Beautiful China vision
Editor's Notes
Generators must navigate the uncertainties of simultaneous reforms.
RE investments must wean off the comfortable business model of fixed price subsidies and navigate the emergence of spot-markets as well as medium- to long-term contracting markets as these are developed.
Investors and asset owners shall have confidence that:
They are able to capture adequate prices for their electricity generation
They will not be curtailed, while being exposed to the market.
There must be evidence that system flexibility develops as needed
or they must develop more complex business models bundling VRE sources with own investments in flexibility and storage.
The market must respond timely to the development of the demand for green, clean or non-fossil electricity – the pull from demand and the requirements from regulation.
There must be confidence that, despite a slowing energy consumption growth resulting from energy efficiency and economic restructuring:
There will be increased electrification,
The authorities will abstain distorting the markets by supporting coal and gas and depress the prices.
The 14th FYP should give priority to developing capacity and balancing capability near consumption centres, including giving focus on wind offshore developing, opening for more distributed siting of wind, and improving conditions for DGPV.
Adding new coal power capacity should be avoided
Adding new coal power capacity, with a lifetime of 40 years or more, would be counterproductive for the energy transition, introducing risks for stranded investments in a competitive power market. Investments in new coal capacity should be avoided or limited as much as possible. The institutional mechanisms for accelerating a smooth retirement of old and inefficient coal plant needs to be put in place. Limiting the share of coal in the electricity generation mix is critical for the reduction CO2 emission and structural enhancement of power supply, especially during 14-FYP, when renewable energies’ cost-competitiveness is just emerging, and the carbon price incentive is weak.