12 Wind History and Investment Landscape
“Wind power is simultaneously ancient and modern. Humans have harnessed wind for millennia, but the wind industry as we know it is barely forty years old.”
Like solar, wind energy required decades of policy support to achieve commercial viability. Unlike solar’s Japanese and German origins, wind’s modern history began in Denmark and California—an unlikely pairing that created the foundation for today’s industry.
12.1 Early History
12.1.1 Windmills and Mechanical Power
Wind power predates recorded history. By 500-900 CE, vertical-axis windmills in Persia ground grain and pumped water. By 1200 CE, horizontal-axis windmills had spread across Northern Europe, becoming iconic features of Dutch and English landscapes.
These were machines of significant power: a large Dutch windmill produced 20-30 kW of mechanical power, driving pumps that drained polders and transformed the Netherlands from marshland to farmland. At their peak in the 19th century, tens of thousands of windmills operated across Europe.
The steam engine and then electricity displaced mechanical windmills. Why transport grain to the mill when the mill could come to the grain? Why rely on intermittent wind when coal-fired engines provided power on demand?
By 1900, windmills were curiosities rather than necessities.
12.1.2 Early Electricity Generation
The first wind-generated electricity came in 1887-1888, when Scottish engineer James Blyth and American inventor Charles Brush independently built wind-powered generators. Brush’s machine in Cleveland, Ohio, was a 60-foot tower with a 17 m rotor that charged batteries in his basement at 12 kW. It operated for 20 years.
In Denmark, Poul la Cour (1890s-1900s) conducted the first systematic wind tunnel experiments in the world and created the “Society of Wind Electricians.” By 1918, 250 electricity-producing turbines operated in Denmark, 120 of them grid-connected. La Cour established a tradition that Denmark never fully abandoned.
Johannes Juul, who had taken la Cour’s course in 1903, built the Gedser turbine in 1957: 200 kW, 24 m tower, 78-foot rotor. It ran for 10 years as the world’s largest wind turbine and introduced emergency aerodynamic tip brakes, a safety innovation still used today. But it cost 2× the price of fossil fuel electricity, and was shut down in 1967 when cheap oil made it uneconomic.
In the US, the Jacobs brothers of Montana created a different lineage. Wanting electricity 40 miles from the nearest power line, Marcellus Jacobs learned to fly (to understand propeller aerodynamics), then built a three-bladed turbine in 1927. The Jacobs Wind company sold roughly 50,000 small turbines by the 1950s. They were killed not by engineering failure but by the Rural Electrification Administration (REA), which extended grid power to rural areas, making wind uncompetitive.
The large-scale attempt came in 1941: the Smith-Putnam turbine in Vermont, 1.25 MW, 53 m diameter, operated for four years before blade failure.
A recurring pattern emerges: wind thrives where grids cannot reach. The moment cheap centralized power arrives, wind dies. This happened three times: steam killed European windmills (1850s), the REA killed American wind chargers (1950s), and cheap fossil fuels killed wind R&D programs (1960s-1973).
12.2 The Danish Model (1970s-1990s)
12.2.1 Response to Oil Shock
Denmark, unlike most European nations, responded to the 1973 oil crisis with sustained commitment to wind energy. The reasons were partly strategic (energy independence), partly cultural (strong environmental movement), and partly historical (the la Cour legacy).
The Danish approach emphasized:
Domestic manufacturing: Support flowed to Danish companies. Vestas, Bonus, Nordtank, and others emerged as global pioneers.
Incremental scaling: Rather than attempting giant machines (like the failed Smith-Putnam), Danish firms built small (30-75 kW) turbines, proved reliability, then gradually scaled up.
Cooperative ownership: Wind cooperatives (andelsselskaber) allowed communities to invest in local turbines, building political support.
Feed-in tariffs: Guaranteed prices for wind electricity, similar to what Germany would later do for solar.
12.2.2 The Turbine Evolution
Danish manufacturers established the modern turbine paradigm:
- Horizontal axis
- Three blades
- Upwind orientation (rotor faces into wind)
- Stall or pitch control
- Gearbox-connected asynchronous generator
By the mid-1980s, Danish turbines were reliable enough for export. California became the first major foreign market.
12.2.3 Bricolage vs. Big Science
The Danish approach exemplified what anthropologist Claude Levi-Strauss called bricolage: innovation through creative recombination of available materials, tools, and knowledge, as opposed to engineering from first principles.
| Approach | Engineer | Bricoleur |
|---|---|---|
| Starting point | Theory and specifications | Available materials |
| Method | Design, then build | Build, then iterate |
| Failure mode | Catastrophic (big bet) | Incremental (small bets) |
| Scale | Start large | Start small, scale up |
| Examples | Boeing MOD-5B, GE MOD-6 | Vestas, Nordtank, Bonus |
Vestas was founded by a blacksmith’s son and originally made agricultural equipment. Nordtank was a small agricultural machinery maker with 120 employees. They bought blades from activist engineers, licensed designs from tinkerers like Henrik Stiesdal, and iterated relentlessly.
The contrast with the US approach was stark. From 1973-1988, the US government spent $380 million on wind R&D, with 87% going to 8 large defense and aerospace contractors (Boeing, GE, Westinghouse). They designed optimally on paper but failed in the field. Almost all programs were discontinued by the late 1980s.
Denmark spent $15 million (1/25th of the US budget) and built an industry. By 1987, 90% of new wind installations in California were Danish-built.
Bricolage beat big science. Iteration and empirical learning outperformed theoretical optimization. This lesson echoes across energy innovation: the path from technology to product runs through manufacturing floors, not design offices.
12.3 The California Wind Rush (1980-1985)
12.3.1 Tax Credit Bonanza
California in the early 1980s combined ambitious renewable energy goals with generous tax incentives. Federal investment tax credits (25%) stacked with California state credits (25%) and accelerated depreciation, effectively paying 50-70% of project costs through tax benefits.
The results:
| Year | California wind capacity (MW) |
|---|---|
| 1981 | 10 |
| 1982 | 64 |
| 1983 | 300 |
| 1984 | 800 |
| 1985 | 1,200 |
California went from near-zero to 1.2 GW in four years—90% of world wind capacity.
12.3.2 The Problems
The California wind rush revealed what happens when policy incentivizes installation rather than generation:
Reliability disasters: Many early turbines—rushed to market to capture tax credits—failed within months. The Altamont Pass became notorious for rows of broken turbines.
Inappropriate technology: Some manufacturers built machines optimized for tax credits rather than energy production.
Boom and bust: When federal tax credits expired in 1985, installation collapsed. California added almost no new capacity from 1986 to 1998.
Avian mortality: The Altamont Pass turbines killed thousands of raptors annually, creating lasting environmental opposition to wind energy.
The California wind rush illustrated how well-intentioned policy can fail:
Security: Rapid capacity addition improved energy diversity. But unreliable turbines meant capacity didn’t translate to reliable generation.
Equity: Tax credits benefited wealthy investors more than ratepayers or communities. The “tax credit industrial complex” enriched financiers while burdening taxpayers.
Sustainability: Wind is clean, but poorly sited turbines killed protected birds. The environmental benefit was partially negated by ecological damage.
The lesson: policy design matters as much as policy ambition. Incentivizing capacity without performance creates perverse outcomes.
12.3.3 Learning from Failure
The California experience taught hard lessons:
- Performance requirements: Later policies tied incentives to actual generation, not just capacity
- Technology standards: Certification requirements ensured minimum reliability
- Site selection: Environmental review processes became more rigorous
- Graduated support: Declining incentives pushed cost reduction rather than indefinite subsidies
Danish manufacturers, whose reliable turbines had performed well, captured global credibility. California developers eventually replaced failed machines with better Danish and American technology.
12.4 European Leadership (1990-2010)
12.4.1 Germany: Feed-in Tariff for Wind
Germany’s 1991 Stromeinspeisungsgesetz (Electricity Feed-in Act) predated the famous 2000 EEG. It guaranteed wind generators approximately 90% of retail electricity prices.
Wind grew steadily:
| Year | Germany wind capacity (GW) |
|---|---|
| 1991 | 0.1 |
| 1995 | 1.1 |
| 2000 | 6.1 |
| 2005 | 18.4 |
| 2010 | 27.2 |
By 2010, Germany had more onshore wind capacity than any other country except China.
12.4.2 Spain’s Rapid Growth
Spain followed the German model, implementing feed-in tariffs in 1997. Combined with an excellent wind resource (strong Atlantic winds, mountainous terrain), Spain grew from negligible capacity to 20 GW by 2010.
Spanish manufacturers—Gamesa, Acciona—became global competitors, later merging with German competitors (Siemens-Gamesa merger, 2017).
12.4.3 Denmark Offshore Pioneer
Denmark built the first offshore wind farm—Vindeby—in 1991: 11 turbines totaling 5 MW. Though tiny by today’s standards, Vindeby proved the concept.
Denmark continued offshore leadership:
- Horns Rev 1 (2002): 160 MW, demonstrating commercial-scale offshore
- Horns Rev 2 (2009): 209 MW
- Anholt (2013): 400 MW
Offshore wind remained expensive but demonstrated consistent improvement.
12.5 The Chinese Surge (2005-Present)
12.5.1 Industrial Policy at Scale
China’s approach to wind mirrored its solar strategy: use domestic demand to build manufacturing capacity, achieve scale economies, then compete globally.
| Year | China wind capacity (GW) | Global share |
|---|---|---|
| 2005 | 1.3 | 2% |
| 2010 | 44.7 | 22% |
| 2015 | 145.4 | 34% |
| 2020 | 288.3 | 38% |
| 2024 | 450+ | 43% |
China now has more wind capacity than Europe and North America combined.
12.5.2 Domestic Manufacturing
Chinese turbine manufacturers grew to dominate their home market:
| Manufacturer | 2024 China market share |
|---|---|
| Goldwind | 22% |
| Envision | 16% |
| Mingyang | 14% |
| Windey | 12% |
| Others | 36% |
Western manufacturers (Vestas, GE, Siemens Gamesa) have minimal China market share but remain important elsewhere.
12.5.3 Quality Improvements
Early Chinese turbines had reliability problems—echoing California’s 1980s experience. But quality improved rapidly:
- Technology transfers from European partners
- Indigenous R&D (Goldwind pioneered direct-drive)
- Domestic component supply chains
- Scale-driven learning
Today’s Chinese turbines compete on quality as well as price, though Western buyers often prefer established Western brands for warranty confidence.
12.6 The Investment Landscape
12.6.1 Who Finances Wind?
Wind project finance has evolved:
Early era (1980s-1990s): Tax equity investors (in the U.S.) and wealthy individuals/cooperatives (in Denmark/Germany) provided capital.
Maturation (2000s): Utilities and independent power producers (IPPs) became primary developers. Project finance—debt secured by power purchase agreements—became standard.
Institutional capital (2010s-present): Pension funds, infrastructure funds, and sovereign wealth funds invest in operational wind farms as stable, inflation-linked assets.
12.6.2 Power Purchase Agreements (PPAs)
Most wind projects secure revenue through long-term contracts:
Utility PPAs: The wind farm sells to a utility under a 10-25 year contract at a fixed or indexed price.
Corporate PPAs: Large corporations (Amazon, Google, Meta) buy wind output directly, achieving sustainability goals and price certainty.
Merchant exposure: Some projects sell into wholesale markets without contracts, accepting price risk for potential upside.
The shift toward competitive auctions (Chapter 9) has pushed PPA prices lower while reducing windfall profits.
12.6.3 Risk Factors
Wind investments face several risks:
Resource risk: Actual wind speeds may differ from predictions. Banks require extensive measurement campaigns and conservative (P90) projections.
Technology risk: Turbine reliability and performance over 20+ years. Warranty terms and manufacturer creditworthiness matter.
Regulatory risk: Policy changes could affect revenue (feed-in tariff cuts, curtailment rules, tax treatment).
Market risk: For merchant projects, wholesale electricity prices may fall below expectations.
Interest rate risk: Wind is capital-intensive; rising rates increase financing costs.
A 200 MW wind project:
- Capital cost: $220 million ($1,100/kW)
- Debt: 70% ($154 million) at 5% interest, 18-year term
- Equity: 30% ($66 million) expecting 12% return
- PPA price: $35/MWh
- Capacity factor: 38%
- O&M: $30/kW/year
Annual revenue: 200,000 kW × 0.38 × 8,760 h × $35/MWh = $23.3 million
Annual costs:
- Debt service: $154M × 0.08 (approx. payment factor) = $12.3M
- O&M: 200,000 kW × $30 = $6.0M
- Total: $18.3M
Cash flow to equity: $23.3M - $18.3M = $5.0M/year Equity return: $5.0M / $66M = 7.6%
The project doesn’t quite achieve 12% equity returns at $35/MWh—illustrating current margin pressure.
12.7 Policy Evolution in the United States
12.7.1 Production Tax Credit (PTC)
The U.S. primarily supported wind through the Production Tax Credit—a per-kWh payment for the first 10 years of generation:
- Introduced: 1992
- Value: approximately $0.027/kWh (2024, inflation-adjusted)
- Requires 40% U.S. domestic content for full credit (IRA provisions)
The PTC’s on-again, off-again history created boom-bust cycles:
| Period | PTC status | Installations |
|---|---|---|
| 1999-2001 | Active | Growing |
| 2002 | Expired | Collapsed |
| 2003 | Extended | Recovered |
| 2004 | Active | Growing |
| 2005-2012 | On/off | Boom-bust cycles |
| 2013-2022 | Extended, then phasing out | Strong growth |
| 2022+ | IRA 10-year extension | Stability |
The Inflation Reduction Act (2022) finally provided long-term certainty: PTC available through at least 2032, shifting to technology-neutral clean electricity credits thereafter.
12.7.2 State Renewable Portfolio Standards
Many U.S. states mandate renewable procurement:
| State | RPS target | Wind impact |
|---|---|---|
| Texas | Exceeded early | 40+ GW wind |
| Iowa | 105% renewable | 60%+ electricity from wind |
| California | 100% by 2045 | Large but solar-dominated |
| New York | 70% by 2030 | Growing offshore focus |
Texas illustrates wind success without aggressive policy: an enormous wind resource, abundant land, and competitive wholesale market made wind economically attractive even with modest policy support.
12.7.3 Transmission Constraints
American wind faces a critical bottleneck: transmission. The best wind resources are in the Great Plains (Texas, Oklahoma, Kansas, Iowa), far from Eastern population centers.
Key transmission projects:
- CREZ lines (Texas): Competitive Renewable Energy Zones connected West Texas wind to Dallas/Houston. Added 18 GW of transfer capacity.
- Plains & Eastern Clean Line (proposed): Would have connected Oklahoma wind to Memphis area. Failed due to state opposition.
The interconnection queue problem affects wind even more than solar: 500+ GW of wind projects await grid studies, many facing multi-year delays.
12.8 Current Challenges
12.8.1 Cost Pressures
After years of cost decline, wind faced headwinds in 2021-2023:
- Steel prices spiked (Ukraine war, supply chain)
- Logistics costs rose (COVID, shipping disruption)
- Interest rates increased (inflation response)
- Component shortages emerged (bearings, electrical equipment)
LCOE, which had fallen to ~$30/MWh, crept back toward $40-50/MWh in some markets. Projects signed at low auction prices faced margin compression.
12.8.2 Permitting and Opposition
Wind projects increasingly face local opposition:
- Visual impact: Large turbines visible for miles
- Noise: Low-frequency sound concerns (though limited evidence of health effects)
- Property values: Contentious; studies show varied effects
- Wildlife: Bird and bat mortality, particularly at poorly sited projects
European countries with saturated onshore potential (Germany, UK) have faced permitting slowdowns. Offshore offers an escape valve but at higher cost.
12.8.3 Supply Chain Localization
The IRA’s domestic content requirements aim to rebuild U.S. wind manufacturing. Challenges include:
- Limited current domestic capacity
- Higher costs than Asian production
- Workforce development needs
- Competition for manufacturing investment with solar and EVs
Whether these incentives will create durable U.S. manufacturing or simply raise project costs remains uncertain.
12.9 The Path Forward
12.9.1 Offshore Acceleration
Global offshore wind is accelerating:
| Region | 2023 capacity | 2030 target |
|---|---|---|
| Europe | 35 GW | 100+ GW |
| China | 35 GW | 100+ GW |
| USA | 0.2 GW | 30 GW |
| Others | 5 GW | 30+ GW |
Offshore offers:
- Better resource (higher capacity factors)
- Reduced permitting conflict (out of sight)
- Proximity to coastal load centers
- Enormous available area
But execution challenges remain: supply chain bottlenecks, port infrastructure needs, and the sheer scale of investment required.
12.9.2 Hybrid Projects
Increasingly, developers combine wind with solar and storage:
- Wind and solar have complementary generation profiles
- Shared grid connection reduces costs
- Storage enables firm delivery commitments
- Better land utilization
These “hybrid” or “co-located” projects are the emerging standard for large-scale renewable development.
12.10 The Reliability Challenge: Shaner et al. (2018)
As wind (and solar) penetration increases, a critical question emerges: how reliable can a renewables-dominated grid be?
Shaner et al. (2018) analyzed 36 years of hourly US weather data and found a striking result: the first 80% of electricity demand is relatively easy to meet with wind and solar, but going from 80% to 100% is exponentially harder.
At 80% renewable penetration, modest overbuilding (1.5× average demand in nameplate capacity) suffices. At 100%, you need either ~3.5× overbuild (wasting enormous amounts of curtailed energy) or massive storage.
The optimal solar/wind mix varies by region:
| Region | Optimal Wind Share |
|---|---|
| Southwest | ~25% |
| Southeast | ~35% |
| Mid-Atlantic | ~55% |
| Great Plains | ~75% |
| Upper Midwest | ~70% |
Geography determines the answer, not ideology. The Great Plains should lean heavily on wind; the Southwest on solar; the national optimum is roughly 50/50.
12.10.1 The Storage Gap
Shaner et al. estimate that 12 hours of storage would enable ~95% renewable reliability. What does that require?
- Current US grid storage: ~90 GWh (almost all pumped hydro)
- Target for 95% reliability: ~5,400 GWh
- Gap: 60× current capacity
- Cost at $150/kWh: ~$810 billion
This is not impossible (the US spends $400B+ on energy annually), but it illustrates why the “last 20%” problem may cost as much as the first 80%.
12.10.2 A Caution from Hittinger
Hittinger et al. (2010, 2012, 2015) raised an uncomfortable finding: grid storage can actually increase emissions if it charges from the marginal generator, which is often a fossil plant. Storage that shifts fossil generation from low-demand to high-demand periods may increase total fossil burn. The climate benefit of storage depends entirely on what charges it. Storage is not automatically green.
12.11 Key Concepts
- Bricolage: Innovation through creative recombination; Danish firms exemplified this
- Danish model: Incremental scaling, cooperative ownership, feed-in support
- California lesson: Poorly designed incentives can produce poor outcomes
- Chinese surge: Industrial policy creating manufacturing dominance
- PTC: The U.S. Production Tax Credit and its boom-bust history
- Transmission: The critical bottleneck for U.S. wind
- Offshore acceleration: The next growth frontier
12.12 Exercises
Policy comparison: Compare the California tax credit approach (1980s) with the German feed-in tariff (1990s-2000s). Which provided better incentives for: (a) rapid deployment, (b) reliable technology, (c) cost reduction, (d) political sustainability?
Learning curve: Global wind capacity grew from 59 GW (2005) to 906 GW (2023) while LCOE fell from $80/MWh to $35/MWh. Calculate the learning rate. How does it compare to solar’s ~24%?
Investment returns: A wind project has $100 million capital cost, 30% capacity factor, $40/MWh PPA, and $25/kW/year O&M. What is the project IRR over 25 years? How does this change if capacity factor improves to 35%?
Transmission value: A wind farm in Kansas can sell power locally at $25/MWh or transport it to Chicago at $45/MWh with $5/MWh transmission cost. What is the value of the transmission option? How many hours per year does Kansas-to-Chicago transmission need to be available to justify a $100/kW transmission investment?
Offshore economics: An offshore wind project costs $3,500/kW with 48% capacity factor and $80/kW O&M. What LCOE is needed to achieve 8% project IRR? How does this compare to current offshore auction prices?
Domestic content: The IRA offers additional 10% tax credit for projects meeting domestic content requirements. If domestic components cost 15% more than imports, does the bonus justify the premium for a $200 million project?
Wind’s history demonstrates the full Framework for Change cycle:
Principle (Chapter 10): Betz limit, wind shear, and power-velocity relationship established what was physically possible.
Technology (Chapter 11): Three-blade HAWTs, pitch control, and gearbox/direct-drive options translated physics into machines.
Product: Danish manufacturers commercialized reliable turbines with warranties and specifications.
Policy (this chapter): Feed-in tariffs, tax credits, and mandates created markets that enabled scale.
Outcome: Wind now provides 7-8% of global electricity at competitive costs.
The feedback loops are evident: successful Outcomes in Denmark informed Policy elsewhere; scale-driven cost reductions enabled new Policies like competitive auctions; and Technology improvement enabled new Products that changed the economics.
This completes Module 2’s treatment of solar and wind—the two technologies that will provide the bulk of future electricity. The remaining chapters examine biofuels, hydropower, and ocean energy before turning to nuclear and geothermal in Module 3.