Projected Costs of Generating Electricity - OECD Nuclear Energy ...

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Table A8.2 – Expected lower and upper bounds to unit costs for specific fuel cycle activities a Parameter Unit Lower bound Upper bound Description Cost U USD/kg U 3 O 8 20 80 Unit cost of natural uranium Cost Uconv USD/kg U 3 8 Unit cost of conversion Cost Uenr USD/SWU 80 120 Unit cost of enrichment Cost UOXfab USD/kg UOX 200 300 Unit cost of UOX fuel fabrication Cost MOXfab USD/kg MOX 1 000 1 500 Unit cost of MOX fuel fabrication Cost UOXrepro USD/kg HM 500 900 Unit cost of UOX fuel reprocessing (as long as percentage of MOX-fuel is less than 20-30%) Cost MOXrepro USD/kg MOX 500 900 Unit cost of MOX fuel reprocessing Cost UOXIntstore USD/kg UOX 100 300 Unit cost of UOX fuel interim storage (2 years) Cost UOXgeo USD/kg UOX 300 600 Unit cost of UOX fuel geological disposal Cost HLWgeo USD/kg UOX 80 200 Unit cost of HLW geological disposal Cost FR-MOXfab USD/kg MOX 1 200 2 000 Unit cost of FR-MOX fuel fabrication (including fertile blankets) Cost FR-MOXrepro USD/kg MOX 1 000 2 000 Unit cost of FR-MOX reprocessing (+200 to 300 USD/kg FR-MOX for blankets) a. Note that some values were converted from Euro to USD, assumusing that 1 € = 1 USD. In the present study, nuclear fuel cycle costs were provided by respondents to the questionnaire directly in NCU per kWh at 5% and 10% discount rates. References IAEA and NEA (2004), Uranium 2003: Resources, Production and Demand, OECD, Paris, France. IEA (2004), World Energy Outlook 2004, OECD/IEA, Paris, France. NEA (2002), Trends in the Nuclear Fuel Cycle, OECD, Paris, France. 206
Appendix 9 Economic Impacts of Wind Power Integration into Electricity Grids Introduction Several countries have renewables policies targeted specifically at wind power or targeted at goals that are expected to be met by wind power. The increasing shares of wind power draw attention to some important issues for the economic impact of integrating wind power into electricity systems: ● As the share of wind power increases, its intermittency increases the need for flexibility to maintain the system balance. ● Large shares of wind power change the way grids are planned, developed and operated. Single onshore wind turbines are usually connected to the grid at low voltage levels. Large offshore wind farms require the extension of the transmission grids to new territories. The intermittency puts new challenges on the control of the grid. ● Wind power may benefit substantially from international trade. Locations with the best wind resources are concentrated along coast lines and some mountainous regions. The load centers are often far away and the environmental benefits of using renewables for power production instead of Green House Gas emitting fuels are regional or global. This appendix will address economic impacts of the technical and operational integration of wind power. A cost assessment of wind power should also take the economics of external effects of power generation in an international context into account. Costs and benefits should be addressed simultaneously. A number of costs are incurred in “refining” and transporting the electricity production from a wind turbine to the final consumer. The most important of these cost factors are: ● Operational costs in managing the intermittency of wind power; ● Costs in keeping additional reserve generation as backup; ● Costs in reinforcing the grid and maintaining system control. An assessment of these costs is intended to allow for more balanced and efficient investment and policy decisions. This will only be the case, however, if the wind integration costs are compared with the costs of integrating alternative options. There must be a level playing field. This may be met by pricing and allocating costs in a market, where all technologies have equal opportunities. An analytical assessment of the costs may be conducted by comparing total system costs in systems with and without wind power. App. 9 The NEA and the IEA arranged a joint half-day workshop on 25 May 2004 where the issues of integration of wind power into electricity grids were addressed. The presentations by the expert speakers and the lively discussions gave valuable inputs to this appendix. 1 1. The presentations from the workshop are available on the NEA and IEA homepages (www.nea.fr and www.iea.org). 207
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NUCLEAR ENERGY AGENCY INTERNATIONAL
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ORGANISATION FOR ECONOMIC CO-OPERAT
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Table of Contents Table of Contents
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Figures Figure 3.1 Specific overnig
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The introduction of liberalisation
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150 USD/MWh at a 5% discount rate a
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The technologies and plant types co
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locations and/or very favourable co
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conclusions of the study were used
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Chapter 2 Input Data and Cost Calcu
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equipped with emission control devi
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Table 2.2 - Exchange rates (as of 1
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Table 2.4 - Coal plant specificatio
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Table 2.7 - Wind and solar power pl
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Table 2.10 - Other plant specificat
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Figure 3.1 - Specific overnight con
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exchange rates, the coal prices var
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Construction time Gas-fired power p
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USD/MWh 70 60 Figure 3.5 - Levelise
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O&M costs The specific annual O&M c
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Cost ranges for coal, gas and nucle
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Ratio 1.9 Figure 3.12 - Cost ratios
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Table 3.11 - Overnight construction
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Table 3.14 - Projected generation c
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Except for the offshore plant in th
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At 10% discount rate, the levelised
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At 5% discount rate, hydroelectrici
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Table 4.6 - Projected generation co
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A CHP plant typically supplies heat
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Figure 5.2 - Levelised costs of ele
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lower unit capital and operating co
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cost calculation for some 130 power
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It should be stressed that the plan
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Concluding remarks The lowest level
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Portugal Mr. António B. Gomes EDP
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Table A2.1 - Nuclear plant investme
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Overnight Capital Costs: Constructi
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Table A2.7 - Gas-fired (including C
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Table A2.10 - Wind plant investment
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Cost structure of supported green e
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The highest investment cost arises
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The expected development of the per
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● ● Autoproducers. These firms
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Canada The electricity market situa
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Natural gas - combined cycle gas tu
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Denmark Basic data Denmark has abou
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In the future, both an increase in
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nuclear operator Teollisuuden Voima
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these power generation methods. Two
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Figure 5 - Competitiveness of vario
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2004. It envisages the gradual incr
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Table 4 - Gross electricity supply
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● ● ● ● ● ● ● ● ●
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Electricity generation costs The to
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photovoltaic device. Finally the su
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Table 1 - Installed electric power
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Japan Consumers in Japan are suppli
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BPE will be established not as a bi
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Coal Coal fired power plants have b
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A new sewage treatment plant with a
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The interconnections between Portug
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In order to respond to these basic
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efficient energies and is reducing
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Liberalisation Basic restructuring
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External costs for electricity prod
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At the beginning of plant operation
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and high ash, moisture and sulphur
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The White Paper did not contain pro
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Table 7 shows the projected load fa
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other investment options available
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Page 162 and 163: unmineable coal seams. All three pr
Page 164 and 165: Light water reactors require enrich
Page 166 and 167: concerns. Consequently, the natural
Page 168 and 169: generators and power electronics el
Page 170 and 171: conventional fossil-fired plants. B
Page 172 and 173: ● ● very effective and is used
Page 175 and 176: Appendix 5 Cost Estimation Methodol
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Page 180 and 181: ● ● ● ● Factors under the c
Page 182 and 183: and small power plants. Although th
Page 184 and 185: The general approach remains useful
Page 186 and 187: Two US economic analyses of nuclear
Page 188 and 189: assume future prices follow a rando
Page 190 and 191: The effects of price risk on techno
Page 192 and 193: The option to delay is embedded in
Page 195 and 196: Appendix 7 Allocating the Costs and
Page 197 and 198: Further Fourier’s law for heat tr
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Page 201 and 202: This yields: β = 0.153 α. If α e
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Page 210 and 211: Reliability in electricity systems
Page 212 and 213: is also highly dependent on the typ
Page 214 and 215: In the ILEX study 5 and in another
Page 216 and 217: an increasing share of wind is the
Page 218 and 219: able to work out the optimal operat
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Page 223 and 224: costs of generation. The introducti
Page 225 and 226: price at 3.5 €/GJ are the next fa
Page 227 and 228: Figure A10.5 - Steam coal price var
Page 229 and 230: The longer term impact on investmen
Page 231 and 232: Appendix 11 List of Main Abbreviati
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