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1
WIND AND WATER POWER TECHNOLOGIES OFFICE
2014 Wind Technologies Market Report: Summary
Ryan Wiser & Mark BolingerLawrence Berkeley National Laboratory
August 2015
2
2014 Wind Technologies Market ReportPurpose, Scope, and Data:
• Publicly available annual report summarizing key trends in the U.S. wind power market, with a focus on 2014
• Scope primarily includes wind turbines over 100 kW in size
• Separate DOE-funded annual reports on distributed and offshore wind
• Data sources include AWEA, EIA, FERC, SEC, etc. (see full report)
Report Authors:
• Primary authors: Ryan Wiser and Mark Bolinger, Berkeley Lab
• Contributions from others at Berkeley Lab, Exeter Associates, NREL
Funded by: U.S. DOE Wind & Water Power Technologies Office
Available at: http://energy.gov/eere/wind
3
Report Contents
• Installation trends
• Industry trends
• Technology trends
• Performance trends
• Cost trends
• Wind power price trends
• Policy & market drivers
• Future outlook
4
Key Findings• Annual wind capacity additions rebounded in 2014, with
significant additional new builds anticipated for 2015 and 2016• Wind has been a significant source of new electric generation
capacity additions in the U.S. in recent years• Supply chain has been under duress, but domestic manufacturing
content for nacelle assembly, blades, and towers is strong• Turbine scaling is boosting expected wind project performance,
while the installed cost of wind projects is on the decline • Wind power sales prices have reached all-time lows, enabling
economic competitiveness despite low natural gas prices• Growth after 2016 remains uncertain, dictated in part by future
natural gas prices and policy decisions, though recent declines in the price of wind energy boost future growth prospects
5
Installation Trends
6
• $8.3 billion invested in wind power project additions in 2014• Wind build well off annual additions from 2007 through 2012• Cumulative wind capacity up nearly 8%, bringing total to 65.9 GW
Wind Power Additions Rebounded in 2014, with 4,854 MW of New Capacity Added
7
Wind Power Represented 24% of Electric-Generating Capacity Additions in 2014
From 2007-2014, wind comprised 33% of capacity additions nation-wide, and a much higher proportion in some regions
Interior
GreatLakes
West
Southeast
Northeast
0%
10%
20%
30%
40%
50%
0
20
40
60
80
100
2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014Tota
l Ann
ual C
apaci
ty A
dditi
ons
(GW
)
Wind Solar Other RenewableGas Coal Other Non-Renewable
Win
d C
apaci
ty A
dditi
ons
(% o
f T
ota
l Annual C
ap
aci
ty A
dditi
on
s)
Wind (% of Total, right axis)
54% 49%
27% 26%
2%
33%
0%
20%
40%
60%
80%
100%
Interior Great Lakes Northeast West Southeast U.S. Total
Per
cent
age
of G
ener
atio
n C
apac
ity A
dditi
ons
(200
7-2
014)
Wind Solar Other Renewable Gas Coal Other Non-Renewable
8
• Global wind additions reached a new high in 2014• U.S. remains a distant second to China in cumulative capacity• U.S. led the world in wind energy production in 2014
The U.S. Placed 3rd in Annual Wind Power Capacity Additions in 2014
Annual Capacity (2014, MW)
Cumulative Capacity (end of 2014, MW)
China 23,300 China 114,760 Germany 5,119 United States 65,877 United States 4,854 Germany 39,223 Brazil 2,783 India 22,904 India 2,315 Spain 22,665 Canada 1,871 United Kingdom 12,413 United Kingdom 1,467 Canada 9,684 Sweden 1,050 France 9,170 France 1,042 Italy 8,556 Turkey 804 Brazil 6,652 Rest of World 6,625 Rest of World 60,208 TOTAL 51,230 TOTAL 372,112 Source: Navigant; AWEA project database for U.S. capacity
9
U.S. Lagging Other Countries in Wind As a Percentage of Electricity Consumption
Note: Figure only includes the countries with the most installed wind power capacity at the end of 2014
10
Geographic Spread of Wind Projects in the United States Is Reasonably Broad
Note: Numbers within states represent cumulative installed wind capacity and, in brackets, annual additions in 2014
11
Texas Installed the Most Capacity in 2014; 9 States Exceed 12% Wind Energy
• Texas has more than twice as much wind capacity as any other state
• 23 states had >500 MW of capacity at end of 2014 (16 > 1 GW, 10 > 2 GW)
• 2 states have >25% of total in-state generation from wind (9 states > 12%)
Installed Capacity (MW) Percentage of In-State Generation
Annual (2014) Cumulative (end of 2014) Actual (2014)* Texas 1,811 Texas 14,098 Iowa 28.5% Oklahoma 648 California 5,917 South Dakota 25.3% Iowa 511 Iowa 5,688 Kansas 21.7% Michigan 368 Oklahoma 3,782 Idaho 18.3% Nebraska 277 Illinois 3,568 North Dakota 17.6% Washington 267 Oregon 3,153 Oklahoma 16.9% Colorado 261 Washington 3,075 Minnesota 15.9% North Dakota 205 Minnesota 3,035 Colorado 13.6% Indiana 201 Kansas 2,967 Oregon 12.7% California 107 Colorado 2,593 Texas 9.0% Minnesota 48 North Dakota 1,886 Wyoming 8.9% Maryland 40 New York 1,748 Maine 8.3% New Mexico 35 Indiana 1,745 New Mexico 7.0% New York 26 Michigan 1,531 California 7.0% Montana 20 Wyoming 1,410 Nebraska 6.9% South Dakota 20 Pennsylvania 1,340 Montana 6.5% Maine 9 Idaho 973 Washington 6.3% Ohio 0.9 New Mexico 812 Hawaii 5.9% Massachusetts 0.6 Nebraska 812 Illinois 5.0% South Dakota 803 Vermont 4.4% Rest of U.S. 0 Rest of U.S. 4,941 Rest of U.S. 0.9%
TOTAL 4,854 TOTAL 65,877 TOTAL 4.4% * Based on 2014 wind and total generation by state from EIA’s Electric Power Monthly.
12
No Commercial Offshore Wind Turbines Commissioned; 1 Project in Construction and 18 in Various Stages of Development
• 30 MW Block Island project (RI) started construction in 2015
• BOEM has granted 5 competitive leases; DOE funding 3 pilot deployments
• Legal and political headwind for high-profile projects:• Cape Wind (MA) power purchase
agreements cancelled by utilities• Fishermen’s Atlantic City (NJ)
rejected by state PUC• Dominion (VA) announced delay due
to cost
• Pressing challenges include cost, lack of PPAs and policy incentives, regulatory complexity
13
Interconnection Queues Demonstrate that a Substantial Amount of Wind Is Under Consideration
Wind represented 30% of capacity in sampled 35 queues
But… absolute amount of wind (and coal & nuclear) in sampled queues has declined in recent years whereas natural gas and solar capacity has increased
Not all of this capacity will be built….
• AWEA reports 13.6 GW of capacity under construction after 1Q2015
14
Larger Amounts of Wind Planned for Texas, Midwest, Southwest Power Pool, PJM, and Northwest
Not all of this capacity will be built….
15
Industry Trends
16
GE, Siemens, and Vestas Captured 98% of the U.S. Market in 2014
• Recent dominance of the three-largest turbine suppliers in the U.S. market• Globally, Vestas remained the top supplier, followed by Siemens and GE • Chinese suppliers occupied 8 of the top 15 spots in the global ranking,
based almost entirely on sales within their domestic market
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
2005 2006 2007 2008 2009 2010 2011 2012 2013 2014
Tu
rbin
e O
EM
US
Mar
ket S
har
e b
y M
W
Other
Suzlon
Acciona
Clipper
Nordex
Mitsubishi
REpower
Gamesa
Vestas
Siemens
GE Wind
17
Manufacturing Supply Chain Continued to Adjust to Swings in Domestic Demand
Note: map not intended to be exhaustive
Realignment Continued…• Uncertain medium-term demand and
growing global competition led to 12 domestic manufacturing facility closures in 2014; only 1 new facility opened
• Nonetheless, many supply chain manufacturers remain
• Over last decade, manufacturers have localized and expanded U.S. presence
• “Big 3” OEMs all still have at least one domestic facility
• Wind related jobs increased from 50,500 in 2013 to 73,000 in 2014
18
Domestic Manufacturing Capability for Nacelle Assembly, Towers, and Blades Is Reasonably Well Balanced Against Demand Forecasts for 2015 and 2016
19
Turbine OEM Profitability Has Generally Rebounded Over the Last Two Years
20
Imports of Wind Equipment Are Sizable; Exports Continue to Grow Slowly
• Figure only includes tracked trade categories; misses other wind-related imports• See full report for the assumptions used to generate this figure
U.S. is a net importer of wind equipment
Exports of wind-powered generating sets increased modestly in 2014 to $488 billion; no ability to track other wind-specific exports, but total tower exports equalled $116 million
0
1
2
3
4
5
6
7
20062457 MW
20075253 MW
20088362 MW
200910005 MW
20105216 MW
20116820 MW
201213131 MW
20131087 MW
20144854 MW
Bil
lio
n 2
01
4$
US
Other wind-related equipment (est.)
Wind generators (2012-2014)
Wind blades and hubs (2012-2014)
Towers (estimated through 2010)
Wind-powered generating sets
US Imports:Exports of Wind-Powered Generating Sets
21
Tracked Wind Equipment Imports in 2014: 42% Asia, 39% Europe, 20% Americas
Note: Tracked wind-specific equipment includes: wind-powered generating sets, towers, hubs and blades, wind generators and parts.
22
Source Markets for Imports Vary Over Time, and By Type of Wind Equipment• Majority of imports of wind-powered
generating sets from home countries of OEMs, dominated by Europe and Asia
• Majority of imports of towers from Asia, but decline in recent years after tariff measures largely stopped imports from China and Vietnam
• Majority of imports of blades & hubs from Brazil and China in recent years
• Globally diverse sourcing strategy for generators & parts, dominated by Asian and European countries
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
2005 0.58B
2006 1.42B
2007 2.72B
2008 2.75B
2009 2.52B
2010 1.33B
2011 1.3B
2012 1.01B
2013 0.02B
2014 0.25B
Impo
rt C
ontin
ent (
% o
f ann
ual i
mpo
rts)
Annual Imports
Wind-powered Generating Sets
China
Denmark
Spain
2012 0.92B
2013 0.28B
2014 0.49B
Wind Blades & Hubs
Germany
Spain
Denmark
China
Brazil
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
2011 0.46B
2012 0.85B
2013 0.1B
2014 0.25B
Wind Towers
Spain
Canada
Mexico
Indonesia
South Korea
2012 0.47B
2013 0.2B
2014 0.33B
Wind Generators & Parts
Denmark
Serbia
Spain
Japan
Vietnam
23
Domestic Manufacturing Content Is Strong for Nacelle Assembly, Towers, and Blades, but U.S. Is Highly Reliant on Imports for Equipment Internal to the Nacelle
Imports occur in untracked trade categories, including many nacelle internals
Overall estimated domestic content: ~40% in 2012 for wind turbine equipment; ~60% if considering total projects costs, including balance-of-plant
Generators Towers Blades & Hubs Wind-Powered Generating Sets < 15% 70-80% 45-65% > 90% of nacelle assembly
Domestic Content for 2013 – 2014 Turbine Installations in the U.S.
24
The Project Finance Environment Remained Strong in 2014
• Project sponsors raised $5.8 billion of tax equity (largest single-year amount on record) and $2.7 billion of debt in 2014
• Tax equity yields held steady, while debt interest rates trended lower
0%
2%
4%
6%
8%
10%
12%
Jan-05 Jan-06 Jan-07 Jan-08 Jan-09 Jan-10 Jan-11 Jan-12 Jan-13 Jan-14 Jan-15
Tax Equity Yield (after-tax)
15-Year Debt Interest Rate (after-tax)
15-Year Debt Interest Rate (pre-tax)
25
Utility Ownership of Wind Rebounded Somewhat in 2014; IPPs Still Dominate
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
1998
1999
2000
2001
2002
2003
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
Other
Publicly Owned Utility (POU)
Investor-Owned Utility (IOU)
Independent Power Producer (IPP)% o
f C
um
ula
tive
Inst
alle
d C
apac
ity
Other:1 MW (0%)
IPP: 3,572 MW (74%)
IOU:1,281 MW
(26%)
2014 Capacity byOwner Type
26
Long-Term Contracted Sales to Utilities Remained the Most Common Off-Take Arrangement, but Merchant Projects Continued to Expand, at Least in Texas
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
19
98
19
99
20
00
20
01
20
02
20
03
20
04
20
05
20
06
20
07
20
08
20
09
20
10
20
11
20
12
20
13
20
14
On-Site
Power Marketer
Merchant/Quasi-Merchant
POU
IOU% o
f C
um
ula
tive
In
sta
lle
d C
ap
ac
ity
Merchant:1,613 MW
(33%)
On-Site:23 MW (0.5%)
IOU:2,497 MW
(51%)
POU:720 MW
(15%)
2014 Capacity byOff-Take Category
• Recently announced wind purchases of ~2 GW from technology companies and business giants to hospitals, universities, and government agencies
27
Technology Trends
28
Turbine Nameplate Capacity, Hub Height, and Rotor Diameter Have All Increased Significantly Over the Long Term
29
Growth in Rotor Diameter Has Outpaced Growth in Nameplate Capacity and Hub Height in Recent Years
Nameplate Capacity
Hub Height
Rotor Diameter
30
Turbines Originally Designed for Lower Wind Speed Sites Have Rapidly Gained Market Share
Specific Power
IEC Class
Specific Power by IEC Class 2 & 3
31
Turbines Originally Designed for Lower Wind Speeds Are Now Regularly Used in Lower and Higher Wind Speed Sites, Whereas Taller Towers Predominate in the Great Lakes and Northeast
By Region By Wind Resource Quality
32
Performance Trends
33
Sample-Wide Capacity Factors Have Increased, but Impacted by Curtailment and Inter-Year Wind Resource Variability
Note: The wind resource index is compiled from NextEra Energy Resources reports
0.00
0.15
0.30
0.45
0.60
0.75
0.90
1.05
1.20
0%
5%
10%
15%
20%
25%
30%
35%
40%
200010
591
200130
943
200273
2,682
200384
3,128
2004106
4,500
2005129
5,142
2006153
7,967
2007196
9,951
2008240
14,926
2009339
23,617
2010452
33,381
2011516
38,562
2012602
44,751
2013748
58,299
2014597
58,685
Long-Term W
ind Resource IndexSa
mpl
e-W
ide
Capa
city
Fac
tor
Capacity Factor Based on Estimated Generation (if no curtailment in subset of regions) Capacity Factor Based on Actual Generation (with curtailment) Wind Resource Index (right scale)
# MW:# Projects:
Year:
34
Wind Curtailment Has Generally Declined in Recent Years; Higher in MISO and New England than in Other Regions
In areas where curtailment has been particularly problematic in the past – principally in Texas – steps taken to address the issue have born fruit
Except for BPA, data represent both forced and economic curtailment
0%
2%
4%
6%
8%
10%
12%
14%
16%
18%
ERCOT MISO BPA NYISO PJM ISO-NE SPP TOTALSAMPLED
Win
d Cu
rtai
lmen
t as P
erce
ntag
e of
Po
tenti
al W
ind
Gen
erati
on
2007 2008 2009 2010 2011 2012 2013 2014
Notes to figure:• BPA's 2014 curtailment estimate was unavailable at the time of publication. A portion
of BPA’s curtailment from 2010-13 is estimated assuming that each curtailment event lasts for half of the maximum possible hour for each event.
• SPP’s 2014 curtailment estimate is for March through December only.• PJM's 2012 curtailment estimate is for June through December only.
35
Even Controlling for These Factors, Average Capacity Factors for Projects Built After 2005 Have Been Stagnant, Averaging 32% to 35% Nationwide
0%
10%
20%
30%
40%
50%
60%
1998-9925
921
2000-0127
1,760
2002-0338
1,988
2004-0528
3,652
200620
1,708
200737
5,282
200879
8,498
200996
9,578
201048
4,733
201168
5,917
2012117
13,533
20138
969
Weighted Average (by project vintage) Individual Project (by project vintage)
2014
Cap
acit
y Fa
ctor
(by
proj
ect
vint
age)
Sample includes 591 projects totaling 58.5 GW
Vintage:# projects:
# MW:
36
Trends Explained by Competing Influence of Lower Specific Power and Build-Out of Lower Quality Wind Resource Sites
All else equal:• Drop in average specific power will boost capacity factors• Building projects in lower wind resource sites will reduce capacity factors
Reversal of build-out in lower wind speed sites in 2013 and 2014: likely to show up in capacity factor data next year
37
Controlling for Wind Resource Quality and Specific Power Demonstrates Impact of Turbine Evolution
Notwithstanding build-out of lower-quality wind resource sites, turbine design changes are driving capacity factors higher for projects located in given wind resource regimes
0%
5%
10%
15%
20%
25%
30%
35%
40%
45%
50%
Lower174 projects, 12.5 GW
Medium107 projects, 13.8 GW
Higher138 projects, 17.0 GW
Highest149 projects, 14.9 GW
Estimated Wind Resource Quality at Site
Specific Power ≥ 400 (33 projects, 3.0 GW) Specific Power range of 300-400 (391 projects, 41.3 GW) Specific Power range of 220-300 (127 projects, 11.6 GW) Specific Power < 220 (17 projects, 2.2 GW)
Sample includes 568 projects totaling 58.2 GW with a commercial operation date of 1998-2013
Wei
ghte
d-A
vg. R
ealiz
ed C
apac
ity F
acto
r in
2014
38
Controlling for Wind Resource Quality and Commercial Operation Date Demonstrates Impact of Turbine Evolution
Notwithstanding build-out of lower-quality wind resource sites, turbine design changes are driving capacity factors higher for projects located in given wind resource regimes
0%
5%
10%
15%
20%
25%
30%
35%
40%
45%
50%
1998-992000-012002-032004-05 2006 2007 2008 2009 2010 2011 2012 2013Project Vintage
Highest Wind Resource Quality Higher Wind Resource Quality Medium Wind Resource Quality Lower Wind Resource Quality
Wei
ghte
d-Av
g. R
ealiz
ed C
apac
ity F
acto
r in
2014
39
Regional Variations in Capacity Factors Reflect the Strength of the Wind Resource and Adoption of New Turbine Technology
0%
10%
20%
30%
40%
50%
60%
West32 projects3,938 MW
Northeast15 projects1,147 MW
Great Lakes18 projects2,109 MW
Interior59 projects7,253 MW
Weighted Average (by region)
Weighted Average (total U.S.)
Individual Project (by region)
2014
Cap
acity
Fac
tor
Sample includes 124 projects built in 2012-13 and totaling 14.4 GW
40
Cost Trends
41
Wind Turbine Prices Remained Well Below the Levels Seen Several Years Ago
Recent turbine orders reportedly in the range of $850-1,250/kW
42
Lower Turbine Prices Drive Reductions in Reported Installed Project Costs
• 2014 projects had an average cost of $1,710/kW, down $580/kW since 2009 and 2010 (up slightly from small sample of 2013 projects)
• Limited sample of under-construction projects slated for completion in 2015 suggest no material change in costs
0
1,000
2,000
3,000
4,000
5,000
6,000
1982
1983
1984
1985
1986
1987
1988
1989
1990
1991
1992
1993
1994
1995
1996
1997
1998
1999
2000
2001
2002
2003
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
Inst
alle
d Pr
ojec
t Cos
t (20
14 $
/kW
)
Commercial Operation Date
Individual Project Cost (743 projects totaling 54,014 MW)
Capacity-Weighted Average Project Cost
43
Economies of Scale Evident, Especially at Lower End of Project & Turbine Size Range
Project Size
Turbine Size
0
500
1,000
1,500
2,000
2,500
3,000
3,500
≤5 MW9 MW
6 projects
5-20 MW87 MW
6 projects
20-50 MW88 MW
2 projects
50-100 MW312 MW
4 projects
100-200 MW1,713 MW11 projects
>200 MW1,680 MW7 projects
Inst
alle
d Pr
ojec
t Cos
t (20
14 $
/kW
)
Capacity-Weighted Average Project Cost
Individual Project CostSample includes projects built in 2014
Project size:# MW:
# projects:
0
500
1,000
1,500
2,000
2,500
3,000
3,500
>0.1 & <1 MW1 MW
2 projects
≥1 & <2 MW2,237 MW22 projects
≥2 & <3 MW1,445 MW11 projects
≥3 MW205 MW1 project
Inst
alle
d Pr
ojec
t Cos
t (20
14 $
/kW
)
Capacity-Weighted Average Project Cost
Individual Project Cost
Sample includes projects built in 2014
Turbine size:# MW:
# projects:
44
Regional Differences in Average Wind Power Project Costs Are Apparent, but Sample Size Is Limited
Different permitting/development costs may play a role at both ends of spectrum: it’s easier/cheaper to build in the US interior and harder/more expensive along the coasts
0
500
1,000
1,500
2,000
2,500
3,000
3,500
Interior22 projects2,961 MW
West5 projects274 MW
Northeast2 projects
95 MW
Great Lakes6 projects519 MW
Southeast1 project40 MW
Inst
alle
d Pr
ojec
t Co
st (2
014
$/kW
)
Capacity-Weighted Average Project Cost Individual Project Cost Capacity-Weighted Average Cost, Total U.S.
Sample includes projects built in 2014
45
Operations and Maintenance Costs Varied By Project Age and Commercial Operations Date
Capacity-weighted average 2000-14 O&M costs for projects built in the 1980s equal $34/MWh, dropping to $24/MWh for projects built in 1990s, to $10/MWh for projects built in the 2000s, and to $9/MWh for projects built since 2010Note: Sample is limited, and consists of 147 wind projects totaling 10,350 MW; few projects in sample have complete records of O&M costs from 2000-14; O&M costs reported here DO NOT include all operating costs
0
10
20
30
40
50
60
70
80
90
1982
1983
1984
1985
1986
1987
1988
1989
1990
1991
1992
1993
1994
1995
1996
1997
1998
1999
2000
2001
2002
2003
2004
2005
2006
2007
2008
2009
2010
2011
2012
Commercial Operation Date
Projects with no 2014 O&M data
Projects with 2014 O&M data
Aver
age
Annu
al O
&M
Cos
t 200
0-2
014
(201
4 $/
MW
h)
46
Operations and Maintenance Costs Varied By Project Age and Commercial Operations Date
Note: Sample size is limited
O&M reported in figure does not include all operating costs: Statements from public companies with large U.S. wind asset bases report total operating costs in 2014 for projects built in the 2000s of ~$21-25/MWh
0
5
10
15
20
25
30
35
40
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
Project Age (Number of Years Since Commercial Operation Date)
1998-2004
2005-2008
2009-2013
Commercial Operation Date:
n=18
Med
ian
Ann
ual O
&M
Cos
t (20
14 $
/MW
h)
n=23
n=25
n=9
n=9
n=6
n=4
n=31
n=25
n=23
n=25
n=13
n=25
n=2
n=6
n=25
n=11
n=29
n=29
n=17
n=6
n=5
n=5
n=5
n=4
n=4
n=5
n=6
n=21
47
Wind Power Price Trends
48
Sample of Wind Power Prices
• Berkeley Lab collects data on historical wind power sales prices, and long-term PPA prices
• PPA sample includes 363 contracts totaling 32,641 MW from projects built from 1998-2014, or planned for installation in 2015 or 2016
• Prices reflect the bundled price of electricity and RECs as sold by the project owner under a power purchase agreement– Dataset excludes merchant plants and projects that sell renewable
energy certificates (RECs) separately
– Prices reflect receipt of state and federal incentives (e.g., the PTC or Treasury grant), as well as various local policy and market influences; as a result, prices do not reflect wind energy generation costs
49
Wind PPA Prices Have Reached All-Time Lows, Dominated by Interior Region
$0
$20
$40
$60
$80
$100
$120
Jan-
96
Jan-
97
Jan-
98
Jan-
99
Jan-
00
Jan-
01
Jan-
02
Jan-
03
Jan-
04
Jan-
05
Jan-
06
Jan-
07
Jan-
08
Jan-
09
Jan-
10
Jan-
11
Jan-
12
Jan-
13
Jan-
14
Jan-
15
PPA Execution Date
Interior (20,611 MW, 212 contracts) West (7,124 MW, 72 contracts) Great Lakes (3,620 MW, 48 contracts) Northeast (1,018 MW, 25 contracts) Southeast (268 MW, 6 contracts)
Leve
lized
PPA
Pric
e (2
014
$/M
Wh)
75 MW
150 MW 50 MW
50
A Smoother Look at the Time Trend Shows Steep Decline in Pricing Since 2009; Especially Low Pricing in Interior Region
$0
$10
$20
$30
$40
$50
$60
$70
$80
$90
$100
1996-9910
553
2000-0117
1,249
2002-0324
1,382
2004-0530
2,190
200630
2,311
200726
1,781
200839
3,465
200949
4,048
201048
4,642
201142
4,572
201214
985
201326
3,674
201413
1,768
Ave
rage
Lev
eliz
ed P
PA P
rice
(Rea
l 201
4 $/
MW
h)
Nationwide Interior
Great Lakes West
Northeast
PPA Year:Contracts:
MW:
51
Relative Competitiveness of Wind Power Improved in 2014: Comparison to Wholesale Electricity Prices
• Wholesale price range reflects flat block of power across 23 pricing nodes across the U.S.• Price comparison shown here is far from perfect – see full report for caveats
0
10
20
30
40
50
60
70
80
90
100
20039
570
200413
547
200517
1,643
200630
2,311
200726
1,781
200839
3,465
200949
4,048
201048
4,642
201142
4,572
201214
985
201326
3,674
201413
1,768
2014
$/M
Wh
Nationwide Wholesale Power Price Range (by calendar year) Generation-Weighted Average Levelized Wind PPA Price (by year of PPA execution)
Wind project sample includes projects with PPAs signed from 2003-2014
PPA year:Contracts:
MW:
52
Comparison Between Wholesale Prices and Wind PPA Prices Varies by Region
Notes: Wind PPAs included are those signed from 2012-2014. Within a region there are a range of wholesale prices because multiple price hubs exist in each area; price comparison shown here is far from perfect – see full report for caveats
Wind PPA prices most competitive with wholesale prices in the Interior region
0
10
20
30
40
50
60
70
80
90
100
Interior37 projects5,275 MW
Great Lakes10 projects
755 MW
Northeast1 project69 MW
West5 projects329 MW
Total US53 projects6,427 MW
Average 2014 Wholesale Power Price Range
Individual Project Levelized Wind PPA Price
Generation-Weighted Average Levelized Wind PPA Price
Wind project sample includes projects with PPAs signed in 2012-2014
2014
$/M
Wh
53
Recent Wind Prices Are Hard to Beat: Competitive with Expected Future Cost of Burning Fuel in Natural Gas Plants
Price comparison shown here is far from perfect – see full report for caveats
0
10
20
30
40
50
60
70
80
90
100
2015
2016
2017
2018
2019
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
2034
2035
2036
2037
2038
2039
2040
Range of AEO15 gas price projections AEO15 reference case gas price projection Wind 2012 PPA execution (985 MW, 14 contracts) Wind 2013 PPA execution (3,674 MW, 26 contracts) Wind 2014 PPA execution (1,768 MW, 13 contracts)
2014
$/M
Wh
54
Renewable Energy Certificate (REC) Prices Remain High in Northeast, While Rising Modestly among Mid-Atlantic States
REC prices vary by: market type (compliance vs. voluntary); geographic region; specific design of state RPS policies
$0
$10
$20
$30
$40
2010
2011
2012
2013
2014
2015
Mid-Atlantic Tier I, Texas, & Voluntary Mkt
DC DE IL (wind)MD NJ OH (I-S)OH (O-S) PA TXVol. (natn'l) Vol. (west)
$0
$20
$40
$60
$80
2010
2011
2012
2013
2014
2015
New England Class I
CT MA ME NH RI
2014
$/M
Wh
55
Policy and Market Drivers
56
Availability of Federal Incentives for Wind Projects Built in the Near Term Has Is Leading to a Resurgent Domestic Market, but a Possible Policy Cliff Awaits
• Near-term availability of the PTC/ITC for those projects that reached the “under construction” milestone by the end of 2014 will enable solid growth in 2015 and 2016; uncertain prospects after that
• Prospective impacts of more-stringent EPA environmental regulations, including those related to power-sector carbon emissions, may create new markets for wind energy
57
State Policies Help Direct the Location and Amount of Wind Development, but Current Policies Cannot Support Continued Growth at Recent Levels
• 29 states and D.C. have mandatory RPS programs
• State RPS’ can support ~4-5 GW/yr of renewable energy additions on average through 2025 (less for wind specifically)
Source: Berkeley Lab
NV: 25% by 2025
TX: 5,880 MW by 2015
ME: 40% by 2017NH: 24.8% by 2025VT: 75% by 2032MA: 11.1% by 2009 +1%/yrRI: 16% by 2019CT: 23% by 2020DE: 25% by 2025NJ: 22.5% by 2020DC: 20% by 2020MD: 20% by 2022NC: 12.5% by 2021 (IOUs), 10% by 2018 (co-ops and munis)
AZ: 15% by 2025 NM: 20% by 2020 (IOUs)10% by 2020 (co-ops)
CA: 33% by 2020
MN: 26.5% by 2025Xcel: 31.5% by 2020WI: 10% by 2015
IA: 105 MW by 1999IL: 25% by 2025MO: 15% by 2021
HI: 100% by 2045
NY: 30% by 2015PA: 8.5% by 2020MI: 10% by 2015OH: 12.5% by 2026
CO: 30% by 2020 (IOUs)20% by 2020 (co-ops)10% by 2020 (munis)
MT: 15% by 2015WA: 15% by 2020OR: 25% by 2025 (large utilities)5-10% by 2025 (smaller utilities)
58
Solid Progress on Overcoming Transmission Barriers Continued• Over 2,000 circuit miles of new transmission built in 2014; lower than 2013
but consistent with 2009-2012
• 22,000 additional circuit miles proposed by March 2017, with half having a high probability of completion
• AWEA has identified 18 near-term transmission projects that – if all were completed – could carry 55-60 GW of additional wind power capacity
• FERC continued to implement Order 1000, requiring public utility transmission providers to improve planning processes and determine a cost allocation methodology for new transmission investments
59
System Operators Are Implementing Methods to Accommodate Increased Penetrations of Wind
Notes: Because methods vary and a consistent set of operational impacts has not been included in each study, results from the different analyses of integration costs are not fully comparable. There has been some recent literature questioning the methods used to estimate wind integration costs and the ability to disentangle those costs explicitly, while also highlighting the fact that other generating options also impose integration challenges and costs.
Integrating wind energy into power systems is manageable, but not free of additional costs
$0
$2
$4
$6
$8
$10
$12
$14
$16
$18
$20
0% 10% 20% 30% 40% 50% 60% 70%
Inte
grat
ion
Cos
t ($/
MW
h)
Wind Penetration (Capacity Basis)
APS (2007)
Avista (2007)
BPA (2009) [a]
BPA (2011) [a]
BPA (2013)
CA RPS (2006) [b]
ERCOT (2012)
EWITS (2010)
Idaho Power (2007)
Idaho Power (2012)
MN-MISO (2006) [c]
Nebraska (2010)
NorthWestern (2012)
Pacificorp (2005)
Pacificorp (2007)
PacifiCorp (2010)
PacifiCorp (2012)
PacifCorp (2014)
Portland GE (2011)
Portland GE (2013)
Puget Sound Energy (2007)
SPP-SERC (2011)
We Energies (2003)
Xcel-MNDOC (2004)
Xcel-PSCo (2006)
Xcel-PSCo (2008)
Xcel-PSCo (2011) [d]
Xcel-UWIG (2003)
60
Future Outlook
61
Sizable Wind Additions Anticipated for 2015 & 2016; Downturn and Increased Uncertainty in 2017 and Beyond
Wind additions in 2014 and anticipated additions from 2017-2020 fall below the deployment trajectory analyzed in DOE’s Wind Vision report
62
Current Low Prices for Wind, Future Technological Advancement and New EPA Regulations May Support Higher Growth in Future, but Headwinds Include…• Lack of clarity about fate of federal tax incentives
• Continued low natural gas and wholesale electricity prices
• Modest electricity demand growth
• Limited near-term demand from state RPS policies
• Inadequate transmission infrastructure in some areas
• Growing competition from solar in some regions
63
Conclusions• Annual wind capacity additions rebounded in 2014, with
significant additional new builds anticipated for 2015 and 2016• Wind has been a significant source of new electric generation
capacity additions in the U.S. in recent years• Supply chain has been under duress, but domestic manufacturing
content for nacelle assembly, blades, and towers is strong• Turbine scaling is boosting expected wind project performance,
while the installed cost of wind projects is on the decline • Wind power sales prices have reached all-time lows, enabling
economic competitiveness despite low natural gas prices• Growth after 2016 remains uncertain, dictated in part by future
natural gas prices and policy decisions, though recent declines in the price of wind energy boost future growth prospects
64
For More Information...
See full report for additional findings, a discussion of the sources of data used, etc.
• http://energy.gov/eere/wind
To contact the primary authors• Ryan Wiser, Lawrence Berkeley National Laboratory
510-486-5474, [email protected]• Mark Bolinger, Lawrence Berkeley National Laboratory
603-795-4937, [email protected]
Berkeley Lab’s contributions to this report were funded by the Wind & Water Power Technologies Office, Office of Energy Efficiency and Renewable Energy of the U.S. Department of Energy under Contract No. DE-AC02-05CH11231. The authors are solely responsible for any omissions or errors contained herein.