cost benefit analysis of developing offshore windfarms in conjunction with interconnectors
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Cost benefit Analysis of Developing Offshore Windfarms in Conjunction with Interconnectors. European Offshore Wind Stockholm September 14 th , 2009 Joe Corbett, Head of Asset Engineering. Why Interconnection. Capacity Factor Offshore Wind 40% Expensive Unused Capacity Security of Supply - PowerPoint PPT PresentationTRANSCRIPT
Cost benefit Analysis of Developing Offshore Windfarms in Conjunction with InterconnectorsEuropean Offshore WindStockholmSeptember 14th , 2009
Joe Corbett, Head of Asset Engineering
Why Interconnection
• Capacity Factor– Offshore Wind 40%– Expensive Unused Capacity
• Security of Supply
• Lower Risk
• Increased Competition
Interconnection Advantages
• Allowing the variation in renewables output to be smoothed
• Providing the ability to source least cost generation from amongst different countries
• Enhancing security of supply by providing additional sources of power
• Enabling peaks in demand to be met from imports of power
• Providing access to energy storage facilities• Allowing access to more cost effective sources of
ancillary services
Interconnection Example
Marginal Cost of an Interconnection
Item Cost/€ No. Total cost (€m)Cost of additional offshore DC isolators 1 2 2
Cost of DC offshore cabling (per km) 0.8 100 80
Cost of DC onshore cabling (per km) 0.5 0 0
Cost of onshore converter station 120 0 0
Cost of offshore converter station 180 0 0
Total additional capital cost 82
UK Germany
20km 100km100km 50km100km
Potential Revenue GB-DE Interconnection
How Much Would Super Grid Cost?
• Recent UK OFTO valuations provide some context– Just over €350 - 500M per GW of Wind for offshore grid
– Mainstream Model– Assume Super Regulator– Assume Super Operator– Regulated Income = 10% RoE– 21 GW Offshore Wind Connected in Stages– Calculate Use of System (TUOS) if Wind must Pay
Supergrid Phase 1
Base Case Analysis
• Calculate Use of System Charge (TUOS) for 21 GW of Wind assuming:– Standard Project Finance– 70:30 Gearing– 20 Year Debt– 25 year Life– Losses 4%– Inflation 2%
Model CharacteristicsGearing 70/30
Total Capex €34bn
Nameplate Wind Capacity 21GW
Wind Capacity Factor 40%
Return on Equity 10%
TUOS €35 /MWh
Sensitivity Analysis
No Phasing out of Revenue
1% Revenue Inflation
3% Revenue Inflation
1% Capex Inflation
3% Capex Inflation
1% Opex Inflation
3% Opex Inflation
3% Transmission Losses
5% Transmission Losses
Decrease Capex 10%
Increase in Capex 10%
Increase in Capex 15%
Wind Capacity Factor = 41%
Wind Capacity Factor = 38%
Wind Capacity Factor = 39%
65% Gearing
75% Gearing
80% Gearing
6% Debt Interest
8% Debt Interest
9% Debt Interest
11% IRR on Equity
9% IRR on Equity
25 year Debt Tenor
30 year Debt Tenor
€31.0 €33.0 €35.0 €37.0 €39.0 €41.0
TUOS Charge
Work to be Done
• Technical Work• Now there’s a market!• Capacity• Cost• Innovation
• Regulatory Framework• EU Commission• ENTSO-E
Conclusions
• Europe needs:– Energy Security
– Reduce fossil dependence
– Develop where Resource not Constrained
– Deliver to Consumers
• Offshore Wind will be Key• Interconnection makes sense:
– Technically
– Economically
• Competition
• Reduce Cost to End-Users
• Supergrid Costs– TUOS ~ €35 / MWh– Will Reduce when other players given access to Capacity
?European Offshore WindStockholmSeptember 14th , 2009
Joe Corbett, Head of Asset Engineering