V164-7.0 MW – Presentation Introducing the V164-7.0 MW 25.05.2011, JLL, ABAAN, V164-7.0 MW team and GMCI
V164-7.0 MW – Presentation
Introducing the V164-7.0 MW
25.05.2011, JLL, ABAAN, V164-7.0 MW team and GMCI
V164-7.0 MW – Presentation2
Agenda
1. Introducing the V164-7.0 MW
2. Lowering your cost of energy offshore
3. The right size
4. Design choices
5. Technical specifications
V164-7.0 MW Technical Presantation3
Disclaimer:
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Vestas disclaims, to the extent permitted by law, all warranties, representations or endorsements,
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V164-7.0 MW Presentation4
1Introducing theV164-7.0 MW
V164-7.0 MW Presentation55
2011-2013:
Design & Test & customer involvement
Q4 2012- Q1 2014:
Construction of first prototype
& ’pedigree’ turbines installed
Q1 2015:
Serial production may begin
2011 2012 2013 2014 2015
March 30, 2011:
Release for
marketing &
dimensions
Forecasted timeline from today to ‘installed at sea’ in 2015Provided the right commitment, involvement & investment
Q3 2014-:
Production ramp-up
V164-7.0 MW Presentation6
2Lowering your cost of energy
offshore
V164-7.0 MW Presentation7
Key objectives
� High energy capture
� High availability at high wind
� High reliability
� Low maintenance
� High serviceability
High yield
Low OPEX
&
High business case certainty
Cost of Energy embraces all aspects in wind power performance
Annualized CAPEX + Annualized OPEX
Annual Energy Production
CoE =
Low Cost of Energy and High Business Case Certainty
V164-7.0 MW Presentation8
Annualized CAPEX and OPEX per MW installed
Offshore Wind Park Assumptions
• “All inclusive” engineer-procure-construct
(EPC) cost .
• The cost structure for actual offshore wind
projects is highly dependent on site specific
conditions.
• Park size: constrained by grid capacity.
Key assumptions: Offshore: 1) Development in supply chain leading to changes in cost base is not considered. 2) Distance to shore 25 km. 3)
No onshore grid extension cost included. 4) Based on V90-3.0 MW turbines. 5) Average annual wind speed ≈ 9,5 m/s.
Taking a customer and power plant perspectiveK
Setting the Offshore value chain in focus
• Foundations
• Wind park design
• Construction and installation
• Operation and service
To reduce cost of energy
Others
Foundation
Electrical Infrastructure
WTG & Installation
OPEX
Offshore
V164-7.0 MW Presentation 9
4The
Right size
V164-7.0 MW Presentation10
Key Market Conditions Qualified
Annual average wind speed and water depth has impact on optimal ration between rotor
diameter and rated power.
12
24
53
83
0
20
40
60
9.6-10.09.1-9.58.5-9.0
% of Total
10.6-11.010.1-10.5
Annual mean wind speed at 100m height (m/s)
4,0
13,0
19,016,0
22,021,0
5,0
0
5
10
15
20
25
% of Total
15-20 < 45-50< 40-45< 35-40< 30-35< 25-30< 20-25
Market outlook Includes:
UK round 2,5 and 3
German North Sea
Scotland
Dutch North Sea
Danish North Sea
Belgian North Sea
Baltic sea (Germany, Denmark
and Sweden)
Water depth mean sea level (m)
V164-7.0 MW Presentation11
An Advanced Cost of Energy-model Adopting Customer’s Perspective
• Rotor diameter• Rotor profile• Tip speed• Rated power• …• …• …
Input parameters
Aero – Power curve
VTS – Baseline load set
Fthrust
..
K
..
..
..
..
...
Main component and BOP load to cost
models
Output:
• Cost of Energy
• IRR
• BCC
• Etc.Annual Energy Production
Reference site information
• Average wind speed
• Water depth
• MW installed
• D
+
Wind Park Economic model
Foundation cost model
Array cable cost model
V164-7.0 MW Presentation12
7 MW - MP
6 MW - MP
5 MW - MP
135 140 145 150 155 160 165 170
CoE [EUR/MWh]
Rotor diameter [m]
Assumptions
Water depth: 35 m
Wind speed: 10 m/s
How to find the right generator to rotor ratio
With monopiles no CoE reduction going to larger turbines
Not
Zero
V164-7.0 MW Presentation13
Foundation
Cost
WTG Size
EPC cost for offshore foundations
• For gravity based foundations
and different types of jacket
foundations there is very little
sensitivity to the weight of the
turbine. It is mainly the rotor
diameter which drives the cost.
• Taking a power plant
perspective in designing the
turbine reduces the cost of
energy and in this case
through reduced foundation
cost.
Conclusion
Taking a power plant perspective choice of size and rating on the turbine is closely related
to foundation costs.
By choosing jackets as foundation the cost of energy is lowered going to a V164-7.0 MW
V164-7.0 MW Presentation14
7 MW - MP
6 MW - MP
5 MW - MP
5 MW - J
6 MW - J
7 MW - J
135 140 145 150 155 160 165 170
CoE [EUR/MWh]
Rotor diameter [m]
Assumptions
Water depth: 35 m
Wind speed: 10 m/s
How to find the right generator to rotor ratio
With monopiles no CoE reduction going to larger turbines
Not
Zero
V164-7.0 MW Presentation15
The right size
• High rated power � Lower CAPEX and OPEX
• Larger rotor diameter � High Energy Capture
V164-7.0 MW
• Rotor diameter: 164m
Airbus A380
• Wingspan: 80m
• Length: 73m
London Eye
• Diameter : 135m
164m
Reducing cost of energy pushes up the turbine size
V164-7.0 MW Presentation16
5Design
choices
V164-7.0 MW Presentation17
Making the right design choicesUsing a 360 degree development process and competing work streams
To secure the best possible design choices and thereby the right solution for our customer we
have worked with competing work streams on key designs elements like the drive train.
V164-7.0 MW Presentation18
How big a deal is OPEX..?Let's take a look at the CoE breakdown..!
Development & Engineering
Electrical infrastructure
Foundation
WTG, Tower
incl. Installation
BoP O&M, Insurance, etc
Running O&M
Main component replacements
V164-7.0 MWV90-3.0 MW
Indicative CoE Breakdown [EUR/MWh]
Main components:
• Blades
• Blade bearings
• Main bearing
• Drive train components
• Generator
• Transformer
Same main component
replacement rate for
V90-3.0 MW and V164-
7.0 MW MW
V164-7.0 MW Presentation19
Hub Main shaft Main bearing housing Bed frame
All wind loads transferred to tower top
Only
torque
How to de-risk the drivetrain K?Separate wind loads and torque will minimize undesired loads in the drivetrain
V164-7.0 MW Presentation20
Medium Speed Drive Offers Highest Return on InvestmentBoth CAPEX, OPEX and supply chain risk are considered in the benchmark
�Medium speed offers the highest
return on investment when
replacement rates for both concepts
is factored in.
�Direct drive IRR has high sensitivity
to replacement rates
�Number of terminations, amount
insulation and air-gap control will
lower the direct drive generator
reliability.
� The medium speed drive train is less
sensitive to price and availability of
strategic raw materialsDrive train replacement rate
Medium speed offers
higher return on
investmentCustomer
IRR %
Direct Drive
Medium Speed
V164-7.0 MW Presentation2121
Two strong arguments: Price and availability?
Supply Chain Risk for Direct Drive?
V164-7.0 MW medium speed magnet weight ≈ 500 kg
V164-7.0 MW direct drive magnet weight ≈ 5000 kg
V164-7.0 MW Presentation22
6Layout& Technical specification
V164-7.0 MW Presentation23
Blade
Hub
Pitch system
Heli hoist
platform
Control panels
Cooling coils
Drive train
Support structure
Main frame
Nacelle
Moving key parts from the nacelle to the tower optimizes serviceability and replacement
is made easy
V164-7.0 MW Presentation24
Tower
Transition piece
Converter panels
Transformer
Switch gear
Working deck
Jacket foundation
Tower
Moving key parts from the nacelle to the tower saves weight in top head mass, optimizes
serviceability and replacement is made easy.
V164-7.0 MW Presentation25
V164-7.0 MW Main Specification
Main dimensions
Blade length
Max chord (preliminary)
Nacelle (incl. hub and coolers)
Height
Length
Width
80 m
5,42 m
7,5 m
24 m
12 m
Weights (± 10%)
Nacelle with hub
Blade (each)
Tower (HH 107m)
390 ton
35 ton
Site dependent
Rotor
Rotor diameter
Swept area
164 m
21.124 m2
V164-7.0 MW Presentation26
V164-7.0 MW Main Specification
Operating data
Rated power
Cut-in wind speed
Operational rotor speed
Nominal rotor speed
Operational temperature range
De-rated temperature range
De-rated temperature range
7,0 MW
4 m/s
4,6 – 12,1 rpm
10,5 rpm
-10 to +25 ºC
-15 to -10 ºC
+25 to +35 ºC
Design parameters
Wind Class - IEC
Annual avg. wind speed
Weibull shape parameter
Weibull scale parameter
Turbulence intensity
1 year mean wind speed V1 (10 min. avg.)
50 year mean wind speed V50 (10 min. avg.)
Max inflow angle (vertical)
Structural design lifetime
IEC S
11 m/s
k 2.2
12.4 m/s
IEC B
40 m/s
50 m/s
0º
25 years
V164-7.0 MW Presentation27
Foundation
Suitable solution needed for water depth range from 20 to 50 m
Water depth [m]
Cum
. P
robabili
ty
[%]
Evaluating the right concept for foundation
Market screening of various
concepts concludes three
mature concepts
Copyright Notice© 2011 Vestas Wind Systems A/S. All rights reserved. This document was created by Vestas Wind Systems A/S on behalf of the Vestas Group and contains copyrighted material, trademarks and other proprietary information. This document or parts thereof may not be reproduced, altered or copied in any form or by any means without the prior written permission of Vestas Wind Systems A/S. All specifications are for information only and are subject to change without notice. Vestas Wind Systems A/S does not make any representations or extend any warranties, expressed or implied, as to the adequacy or accuracy of this information. This product is in its current form a 50 Hz version and therefore not available for 60 Hz markets. This product will not be released for sale in all locations/countries. Vestas Wind Systems A/S shall not have any responsibility or liability whatsoever for the results of use of the documents by you.
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