lyons (wind energy systems)
TRANSCRIPT
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Energy
Systems
Cornell
12 June, 2009
JP Lyons - CTO
Novus Energy Partners
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Wind Now Mainstream
GE1.5MWTurbines
Lamar,Colorado
,
GE $6.5B 2008 revenues, 10,000 1.5 machines installed
Good US sites (8+ m/s) - lowest COE of any new generation
US 20+ GWs, 8.3 GW 2008, 42% new electricity
20% Wind Energy by 2030 300+GW
GW scale projects in sight
2 /June 2009
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Land Based Technology
Vestas V100-2.75
1.5 3.0 MW Upwind Configuration
80 100 Meter Tower Height
Distributed component drivetrain Full Span Pitch Control
Ta ered C linder Steel Towers
Clipper 2.5-93
~65 kWhr/kg tower top mass
200 MW + Windfarms
Performance
98% Availability
40+% Capacity Factor at IEC-II 8.5 m/sGE 2.5xl
3 /June 2009
CF% +10 pts in last 5 yrs
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GE Wind TurbinesElectrical Pitch
Drives
GE 1.5 MW 77 M Rotor Diameter
50-100 M Tower
Doubly-FedGenerator
98% Availability
Speed 10-20 RPM
Variable Pitch
Gearbox
Epoxy-GlassComposite Blades
Bearing
Transformer &Electrical Power Electronic
Converter
4 /June 2009
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Turbine Speed vs. Size
Southwest Windpower Storm
Clipper 2.5 MW with 93 m
. , .
5 /June 2009
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Wind Energy Conversion
Rotor power: P = 1/2 cp Avw3
cp - rotor power coefficient - a r ens y
A - rotor swept area
Ideal cp = 0.593 (Betz factor)
w ere 2 = 1 w n ve oc y s ows y
Tip speed ratio: = vt / vw
6 /June 2009
cp = f()
Windturbines: Fundamentals, Technologies, Application and Economics , Erich Hau, ISBN: 3540570640; (April 30, 2000)
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Wind
TurbineDynamics
er o c orces xc te ec an ca ystem
bladepassingfrequency(BP)
3P
wind
shear,
yaw
error,
tower
shadow
Protationalfrequency
TurbineNaturalFrequencies
ower
en ng
mo es
Bladeflapbendingmode
Bladeflutter&torsional modes
7 /June 2009
Windturbines:Fundamentals,Technologies,ApplicationandEconomics,ErichHau,ISBN:3540570640;(April30,2000)
Drivetraintorsional oscillation
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IEC Design Envelope
IEC 61400 defines a standard design envelope fordifferent desi n classes.
Assumes most extreme conditions for which a 20 yeardesign life can be maintained.
Air density 1.225 kg/m3, shear coefficient of 0.2 AND
IECIIIB IECIIIA IECIIB IECIIA IECIB IECIA
Mean WS 7.5 7.5 8.5 8.5 10 10
TI@15m/s 16% 18% 16% 18% 16% 18%
V50 - 3s 52.5 52.5 59.5 59.5 70 70
8 /June 2009
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Loads Analysis Aero Elastic Model
9 /June 2009
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Time Series BladeRootB
Main Shaft
R
T
Tower Top
LoadTime Series
Wind speedParameter Iu,,z0
10 /June 2009
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Wind Turbine Performance
-
1,200
1,400
1,600
(kW)
Cut-outRated Power
400
600
800
1,000
lectricalPower
Cut-in
Wind speedWind speed
0
200
0 5 10 15 20 25
Wind Speed (m/s)
Energy in the Wind3
Captured Energy(1/2 V3 S cp)
Wind Distribution
11 /June 2009
Annual EnergyProduction (AEP)
Power Curve
Energy
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Analysing the wind
a s ca me o s
(1)
Once the roughness length and the according
height exponent a is estimated, the formula (1)gives the wind speed (v2) in a projected height (h2):
=
1
212
h
hvv
(2)
Because the estimation of a is subjective, thefollowing formular gives an objective way of
calculating the height exponent out of two differenthei hts of measurement:
( )
( )21
21
ln
ln
hh
vv=
Further formulas for calculation of windcharacteristics:
Vref= 5 x Vm
Ve1 = 0.75 x Ve50
(3)
(4)Empiric ormulas according IE standards
Ve50 = 1.4 x Vref (5)
13 /June 2009
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Tech Improvements
Scale 5MWmachinesontheGreatPlains
GWscalelandprojects
Logistics:insitublade&towermfg
PowerTrain
Compact1stageintegratedgearbox,
90kWhr/kgspecificyield
bearings,generator
Directdrive
PMgenerators WTCompositesSheathedSpaceFrameTower
BendTwistCoupledBlades
Controls
FullMVpowerconversion Multivariablemodelbasedcontrols
Loadmitigation&damping
Cyclic&independentbladepitchcontrol
Blades Largerrotors,higheffairfoils+10%CF
Loadmitigatingsweepandflaptwistcoupledblades
14 /June 2009
u oma e car on ersparcap a eroo
Onsitebladeinfusion
Drivetrain BearingNacelle
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2-Blades: Back to the Future? Nordic1000
rotate 25-30% faster: power with less torque more blade noise
,
Eliminates weight/cost of 3rd blade - decrease in Cpcompensated by slightly longer blades
Teetered hub minimizes bending loads on the mainshaft /gears
Simplified installation logistics
Potential 25% wei ht/cost advanta e: Technolo for COE driven markets e. .
Optimized3blade Optimized2blade
Great Plains, Northern China, Offshore?
15 /June 2009
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New Innovation
FloDesign Turbine
16 /June 2009
Venturi + Mixer/Ejector(Mass)
Coriol is Wind VAWT(Israel)
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Wind Turbine Electrical Conversion
Type 1: Squirrel-cage induction generator - generator
PlantFeeders
Limited LVRT and pf capability
PF contro lcapacitors
generator
PlantFeeders
ype : oun ro or n uc on genera or w var a e ro orresistance
Fixed speed variable pitch turbine Slip poweras heat loss
PF controlcapacitors
ac
to
dc
Plant
Type 3: Doubly-fed wound rotor induction generator -Limited variable speed variable pitch turbine
generator
ee ers
acto
dc
acto
dc
Type 4: Full power converter interface Full variable speed variable pitch turbine
partial power
generator
PlantFeeders
acto
acto
17 /June 2009
full power
dc dc
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-
Grid CodesPower & Frequency Operating Range
, ,FERC/WECC, HQ, UK, ESB, ...
Initiated by e-on 2001
LVRT/ZVRT fault ride-thru & transient volt support
Reactive power specs
Power vs, Frequency
Germany
1.1 pu
1.15 pu
For Br itain React ivePower re uired
Alberta Alberta
Austr
alia,Albert
a
AlbertaAlberta
VARSupport
VoltageTransientRideThruRequirements
Alberta,
Phillipines
, LIPA,
NSP,
PSCO,
Italy
Britain,
Scotland,Thailand,Turkey,
ERCOT,PG&E
and therest onLHS
Vo
ltage
(kV)
1 pu
1.05 pu
Rated Power, Continuous
,
is the same as that for the reduced
output power (poorer pf)
Ontario,
LIPA, NSP,
PG&E and the
rest on RHS
Iris
h,Gr
ee
ce
an
d
theres
t
on
LH
S
Britain, Irish,
Scotland,
Alberta,
Greece,
Phillipines,
Thailand,
Turkey
Austr
alia,
ERC
OT,
PSC
O,
Italy
and
rest
on
RHS
Common,
Except
Australia,
Ontario
(upto upf) Insert another image
Irish,Greece and the rest on
LHS
Irish, Greece
0.95 pu
0.875 pu
0.9 pu
Irish, Alberta, GreeceAustr
alia
and
RHS
Alberta
For ERCOT, at lower powers, Reactive
according to capability (poorer pf)
For Germany, any power level, duration
not specified. (assumed continuous)
18 /June 2009
Power Factor
0.8
50
.9
0.9
5 1
0.9
50
.9
0.8
5
Over ExcitedUnder Excited
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Mimic thermal lants fre droo var su ort
Grid (Friendly) Integration
59.50
60.00
3 GW wind w/ newactive power
controls
59.50
60.00
3 GW wind w/ newactive power
controls
Powerelectronicshavechangedwindtechnology
fromadetrimenttoanattribute
ZVRTfaultridethrutoberequiredbyFERC 58.50
59.00 HQ Base case w/owind - UF LoadShed at 58.5 Hz
58.50
59.00 HQ Base case w/owind - UF LoadShed at 58.5 Hz
Reactivepowercontrol voltageregulation,VAR
supportw/o
power
Activepowercontrolramprates,powercurtailment,HydroQuebec VirtualInertia
58.00
58.0 a fbul 90 Load 220.0 1 1 60.0
58.0 b fbul 90 Load 220.0 1 1 60.0
58.0 c fbul 90 Load 220.0 1 1 60.0
58.0 d fbul 90 Load 220.0 1 1 60.0
Time( sec )
0.0 30.0
new controls
58.00
58.0 a fbul 90 Load 220.0 1 1 60.0
58.0 b fbul 90 Load 220.0 1 1 60.0
58.0 c fbul 90 Load 220.0 1 1 60.0
58.0 d fbul 90 Load 220.0 1 1 60.0
Time( sec )
0.0 30.0
new controls
,
10%Power
Increase
VoltageatPOIWindPlantVoltage
Frequency(Hz)
Power(kW)
4%FrequencyReduction
WindPlantPowerOutput
19 /June 2009
ColoradoGreen220kVBusVoltageRegulation
ActivePowerRampRateControl GE/ESBIreland
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2001 NYISO Day Ahead Forecast E rror (F-A) January
Wind in New York
1500
2500
3500
Erro
Load Error (F-A)
Wind Error (A-F)
Total Error (F - A)
-1500
-500
500
1 49 97 145 193 241 289 337 385 433 481 529 577 625 673 721
Hour
M
NY RPS
25% renewables by 2013 (15% existing hydro)
Summer Morning Load Rise - Hourly Variabilit y
+ w n . ac eva e w m nor c anges n operat ons
Day-ahead uncertainty w/ wind similar to load forecast
Wind improves post-fault response of interconnected grid
100
150
200
uency
State Jun-Sep 7AM-9AM 1HR Delta Histogram
Largest Hourly Change
With Day-Ahead
Wind ForecastingWithout WindForecasting
Total variable cost reduction
(includes fuel cost, variable O&M, start-upcosts, and emission payments)
$ 430M $ 335M
Total variable cost reduction per MW-hourof wind generation
$48 / MWh $38 / MWh
$95M
0
50
-3000 -2000 -1000 0 1000 2000 3000
Freq
2756 MW with wind
NYS Benefits
$48/MWhr of Wind Energy Production Cost
Wind revenue $ 315M $ 305MNon-wind generator revenue reductions $ 795M $ 960M
Load payment reductions
(calculated as product of hourly load andthe corresponding locational spot price)
$ 515M $ 720M
MWLoad Load-Wind
20 /June 2009
CostsAnnual Operating Cost Impactsfor 2001 Wind and Load Profi les
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Wind ForecastingEltra, Denmark - 2000 Study
1.9GW onshore farms, 16% consumption
3.4TWh produced, 1.3TWh miscalculated (38%)
Climatology-based forecast, inaccuracies up to 800MW
m a ance paymen s . c
Advanced forecast using a
Current State-of-the-Art
statistical models, and 3D
meso-scale climatology
Local statistical model + 3D climatology model - 10-15% mean abserror for day-ahead and 5-10% error for 6 hr ahead forecasts
2005 regulations in Spain provide:
- Penalties for >20% error on 24hr production forecast
-
2003 Cal ISO regulations unbiased hourly, daily forecasts settlementmonthly for net deviations at average rate
Utilities need short (72h) forecasts
21 /June 2009
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Site Specific Power Forecasting System
Wind SpeedForecast
PowerCurve
PowerForecast
Availability Model
YieldForecast
Assume w e areDown for 5 min(t o)
K
W
K
W
For all Downtimes (t) > (to)Calculate t- to
CalculateAverag e(log( t- to ))
Stddev (log(t- to ))
Increment (to)By 1 hour
while (to)
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Offshore Wind
23 /June 2009
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Offshore Wind
176 MW Siemens/Bonus
90MW VestasBarrow, UK
Offshore Technology
19 Projects, 900 MW Installed, shallow water
,
3 4 MW upwind configuration
5-6 MW turbines in prototype
80 m towers
Monopile & gravity foundations < 15m
Many challenges turbine only 1/3 project costs
Performance Average 45+% Capacity Factor 11 c/kwhr UK Thames Estuary site
40 MW Bonus Middlegrunden
Farm in Copenhagen Harbor
24 /June 2009
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Middlegrunden Copenhagen Harbor
25 /June 2009
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Gamechanger: US Offshore Wind
Wind Map off Long Island Virginia to Boston,densest US population
LIPA lannin 140 MW ilot offshore-electric prices
Huge renewable assetwithin 50 km of coast
and less than 50 m
farm
RPS in NY, Mass, Conn RPS will drive need for large scalerenewables
Deeper water foundation technology & higher power moreeconomic turbines needed
Great Lakes close to large load centers in US & Canada Toronto, Cleveland, Detroit, Chicago, Milwaukee,
Lake Erie shallowest at 15-30 m
26 /June 2009
Foundation technology 50-70 m would enable largedeployment need to withstand ice conditions
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Offshore Machines
Nacelle
Manufacturer ModelPower
(MW)
Rotor
(m)
Weight
+ Rotor
(kg)
GeneratorCf
(%)# Units
Enercon E112 4.5 112 440 WF Sync 44.0 5
Enercon E120 6 120 440 WF Sync 41.6 0*
.
Vestas NM110 4.2 110 214 DFIG 44.6 1
Vestas V120 4.5 120 214 DFIG 46.5 0*GE 3.6s 3.6 104 280 DFIG 45.3 9
GE 3.6sl 3.6 111 265 DFIG 47.9 0*
Siemens/Bonus 3.6 3.6 107 200 Induction 46.4 1
Repower 5M 5 126 400 DFIG 46.3 1
Prokon Nord Multibrid 5 116 280 PM Sync 43.4 1 Vestas V903MW, 90m
Siemens Bonus 3.63.6MW, 107m* planned upgrades
27 /June 2009
Enercon E-112/120m,4.5/6MW
Prokon Nord5MW, 116m
Vestas NM110/V120m4.2/4.5 MW
GE 3.6 MW 104/111m Repower 5M 5MW, 126
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Offshore Installation TechniquesEarly Industry Approach
ump ng ac arge to nsta tur nes notdesigned for offshore wind industry
Separate cable-laying vessel additionalship to charter
Turbine access using conventional boat 1m wave height limit.
Learning from Experience
Mayflower Resolution vessel purpose-designed to install offshorewind turbines and infrastructure
Transports turbines, towers, blades to foundation and erects
Capable of laying cables
Specially-designed Windcat turbine access craft allows installationand commissioning to continue in strong sea-states (2.5m waveheight)
Going Deeper
Floating platforms / turbines can be assembled at a port
Tugs to take assembly to wind farm location
28 /June 2009
ecure y a ac e o anc or ng po n s
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Foundation Technologies
0 20m : Mono ile & ravit foundations are most
Jacket weight increases
with depth even at
constant MW rating
prevalent; Resonance constraints from rotoroperation leads to increasing tonnage &manufacturing limits.
.Depth dependence on weight
can be reduced substantially
with a floating foundation
system
Gravity FoundationNear Shore
Monopile20 m, 12 km
20 40m: Multi-legged jacket/tripod/braced pilestructures from O&G industry experience. JointFatigue & O&M issues are main design drivers.
40m beyond : Floating Platforms: Mini-TLP / Sparbuoy based platforms under investigation; Primary
29 /June 2009
-dependence from water depth.
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Monopile Foundation System Design Drivers
Modal Analysis - 3.6s/sl Tower/Foundation2
2nd Mode Desi n Box :
1.2
1.6
(Hz)
6P +/-10%
(2X BladePass Freq )
15.3r
pm
1440rpm
erator
in=8. 5
rp m
r,800rp m
enerat o
r
Nmax
=21
.3rpm
r otor,20 0
0rpm
gen
era
tor
f1 >1.607
0.8
Frequenc
3P +/-10%
(Blade Pass Freq
Nrtd
rotor,
ge
Nmi
rot g
0
0.41P +/-10%
(Rotor Pass Freq
1st Mode Design Box: 0.28< f0>0.383n = rotor speed
nR = Ratedrotor speed
Note: Range for f1 depen d s on chosen rated rpm
. . . . . .
Relati ve Rotor Speed (n/n R)
30 /June 2009
Eigen Frequency Often Primary Driver for Monopile Designs
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Nysted Rdsand
31 /June 2009
Source: http://www.aarsleff.com/internet/acms.nsf/Webpages/168241DB8B190997C1256D2B0029822E
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Electrical BOP
Radial 33 kV col lector s stem
, ,
maintenance and 20 year design life.
Need shelter in case someone gets stranded on the platform.
High capacitances of sea cables - reactive compensation and
regulation can play a substantial role in system design.
Transmission
Connection
xxxx
x x x
CBs
33kV
Collector ESP(500MW block)Collector Circuits
1-7
8-14
15-21
22-28
x x
400kV
Shore Connection(500MW block)
x x132kV
x xCB
132kV
System Layout for 500MW UK Farm
BOP Estim ate
Equipment Cost Total
x Transformer Disconnect/Earthing Switch
-
77-84Disconnect/
Earthing Switch
Transformer
Horns Rev 180 MW ESP
500 MW ESP (electrical equipment) $12,925,000
500 MW ESP (platform) $32,075,000 $45,000,000
33 kV Cable (84 miles) $25,000,000
33 kV Cable installation and burial (84 miles) $33,000,000
115 kV Cable (8 miles submarine, 6 miles land) $64,000,000
33 /June 2009
a e - ns a su mar ne , , , ,
Total $188,000,000
Transmission Options, UMass
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UK Offshore 500MW Farm Thames Estuary
Assumptions
Next-gen turbines: 4, 5, 6, or 7 MW
Swept Area: 2.6 m2/kW (approx. same as 3.6sl)
Specific Weight: 55 kg/kW
Tip clearance to water: 25m
Soil Profile from GunFleet Sands 12 m water depth, 20 km to shore
90 m/s tip speed
4 MW 5 MW 6 MW 7 MW# Turbines 125 100 83 71Rotor (m) 116 130 142 153.5
Hub Height (m) 83 90 96 102
Model Inputs
UK economics structure w/ 10.25 c/kWhr
Tower Top Mass (tonnes) 220 275 330 385
Yield (MWhr) 15600 19500 23400 27650
Capacity Factors 44.5% at Gunfleet 9.3m/s at 78m
After Tax Unlevered IRR = 9.5%
Foundation & Tower costs f(MW size)
Civil installation costs f(MW size)
Electrical BOP costs f(MW size)
ModelOutput
Wind Farm Price/MW f(MW
Size)
34 /June 2009
CSA costs f(MW size)
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Economics of 500 MW Offshore Wind Park
ssump ons
Nextgenturbines:4,5,6,or7MW
SweptArea:2.6m2/kW
SpecificWeight:55kg/kW
.
1400
1450
Cost($)
2.80
2.90
MW
Tipclearancetowater:25m
ThamesEstuary
12
m
water
depth,
20
km
to
shore
90m/stipspeed1200
1250
1300
indfarmC
apital
2.40
2.50
2.60
.
CapitalC
ostpe
($/MW)
InstallationCosts
vs
ElectricalBOPCostsvsTurbineRating
$170M
$180M
$190M
PCost
1150
4 5 6 7
Turbine Rating (MW)
2.30
500MW Wind Farm Breakdown
$1.2B Total w/ 5MW Turb ines
35%
12%
Turbines
Foundation Costs vs Turbine Ratin
ur ne a ng
$160
$180
$200
$220
$MM
$150M
$160M
3 4 5 6 7 8
TurbineMW
BO
12%
15%
CSAConstruction & Installation
BOP Electrics
Project Other
550
600
650
700
750
800
850
900
950
1000
Cost(K$)
60
80
100
120
140
160
180
200
FabCost(K$/MW) $100
$120
3 4 5 6 7 8
35 /June 2009
10%
400
450
500
GE 4 MW uni t GE 5 MW un it GE 6 MW un i t GE 7 MW un i t
0
20
40
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GW Scale Wind
10 MW Turbines 180 m rotor diameter
ownw n a e mac ne
Flexible compliant blades Flow control blades
g rpm p ve oc y > m s
Space frame structure
Multivariable damping controls m wa er ep oun a on
Hurricane ride-thru capability
EU Upwind R&D ProgramCan the economics work?
36 /June 2009
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Wind Energy
Cornell une
JP Lyons - CTO Novus Energy Partners
20% US Wi d Vi i
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20% US Wind Vision 2030 DOE, AWEA, 20% Energy Roadmap
Black & Veatch US Wind Supply Curve
300+ GW, 15% CAGR, 25 years
$60B investment in Transmission
Benefits (2030):
- 50% reduction NG electric gen
- 18% reduction in coal gen
- 7500 MMTCE cumulative carbon reduction
- 17% water use reduction for west generation
- 150,000 direct jobs created
Great Plains Wind,
38 /June 2009
US Wind Resource
Hi h P t ti Wi d B d 10%
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High Penetration Wind Beyond 10%
--+
Vref(from gridoperator)
Ihs [AB]
Line Drop Compensation
Vhs
Vhs max
Verror
-
HighSide VoltageLimiter
QB up
(MVAr)
Vhs ref
Vhs min
Vhs
-Qi(to NWTGs)
VoltageRegulationMode
-
Y
switchdelay(for sim.model)
deadbandRegulation
ModeSelection
Qtotal
Qshunt
Qwtgnet
from SCADA:NWTGs on-line
N
++
+
Qmax
= Bma
+ N*Qimax
Qmin=B min+ N*Qimin
anti-windupon Qmax/min
PFAref
(from grid
operator)
Ihs[AB]
PFCalculation withLineDropCompensation
Vhs
+
+
PFAc
- PFAerr
anti-windupon Vhs max/min
Power Factor Regulation Mode
Kppf+Kipf/s
1N
1s
IfQerr1 >0then
out=Qerr1elsereset
integrator
Qerr1 out
reset
IfX 1 >MSC/R tol
thendisconnect
LorconnectC
SwitchedLorC?
X1
reset
-
++
QB down
(MVAr)
IfQerr2 < 0 If X2
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ISO
Timers)
Operation Process Issues
Unit Dispatch
600
700
1 Year
Lines
Slower(Yea Resource and
Capacity Planning
(Reliability)0
100
200
300
400
500
0 2000 4000 6000 8000
Hour
MW
(UCAP, ICAP)
andLong-Term Load
Growth Forecasting
Unit Commitmentand
Day-ahead and-
2001 Average Load vs Average Wind
20,000
25,000
30,000
ad(MW)
1,000
1,200
1,400
1,600
ut(MW)
1 Day
Day-AheadScheduling
Forecasting
e
Frame
0
5,000
10,000
15,000
1 6 11 16 21
Hour
NYISOLo
0
200
400
600
800
WindOut
July load August load September load
July w ind August w ind September w ind
3000
Load Following(5 Minute Dispatch)
Ti
Hour-AheadForecasting
andPlant Active PowerManeuvering and
Management500
1000
1500
2000
2500
MW
3 Hours
Frequency andTie-Line Regulation(s
econds)
Real-Time andAutonomo us Pro tection
and Control Functions
0
1 61 121
M in u t e s
S ep tem ber M or ni ng A u gu st Mo rn ing M ay E ve nin g Oc tob er Ev en in g A pr il A f te rn oon
10 Minutes
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(AGC)
Faster (AGC, LVRT, PSS,
Governor, V-Reg, etc.)
References
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8/12/2019 Lyons (Wind energy systems)
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Wind Energy Handbook
References
, , , Hardcover: 642 pages ; Dimensions (in inches): 1.58 x 9.82 x 6.70
Publisher: John Wiley & Sons; ISBN: 0471489972; 1st edition (November 15, 2001)
Windturbines: Fundamentals, Technologies, Application and Economics
by Erich Hau Hardcover: 650 pages
Publisher: Springer Verlag; ISBN: 3540570640; (April 30, 2000)
by Robert Harrison, Eric Hau, Herman Snel Paperback: 200 pages ; Dimensions (in inches): 0.57 x 10.86 x 8.66
Publisher: John Wiley & Sons; ISBN: 0471494569; (January 2001)
Wind Energy Explained
by J. F. Manwell, Jon McGowan,Anthony Rogers Hardcover: 512 pages ; Dimensions (in inches): 1.49 x 9.88 x 6.64
Publisher: John Wiley & Sons; ISBN: 0471499722; 1st edition (June 15, 2002)
Grid Integration of Wind Energy Conversion Systemsby Siegfried Heier, Rachel Waddington (Translator Hardcover: 250 pages ; Dimensions (in inches): 1.01 x 9.92 x 6.80
Publisher: John Wiley & Son Ltd; ISBN: 047197143X; (September 1998)
41 /June 2009