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The offshore wind industry in the Asia-Pacific (APAC) region is transforming, facing tough macroeconomic challenges in recent years. These challenges include rising raw material costs, inflation, high financing expenses, and supply chain uncertainties. However, these pressures are now easing, and policymakers are adapting regulations to support the sector’s development. Offshore wind remains cost-competitive, especially in mature markets like the UK, Germany, and China, and APAC countries are working to follow similar trajectories through supportive policies and growing market maturity.
Offshore wind projects are initially expensive in emerging markets due to the lack of established technical, regulatory, and financial frameworks. But as more capacity is installed and experience accumulates, costs tend to decline significantly. This happens typically after the first 2–3 GW of capacity, when investor confidence increases, competition grows, and access to low-cost financing improves. This pattern is already visible in APAC countries. South Korea has passed the ‘One Stop Shop Bill’, Japan has committed to a large green bond initiative under its Climate Transition Bond Framework, the Philippines will conduct its first offshore wind auction by the end of 2025, and Vietnam is advancing through its PDP8 Implementation Plan.
These markets are expected to see cost reductions due to larger installations, economies of scale, better supply chains, and more robust regulations. Offshore wind, although capital-intensive and sensitive to economic trends, shows signs of long-term resilience in the APAC region, with governments showing strong commitment to enabling the industry.
The offshore wind industry is influenced by several key factors. One of them is the levelised cost of electricity (LCOE), which represents the breakeven price needed to recover all project costs. LCOE includes capital expenditure (CapEx), operational expenditure (OpEx), and financing costs. CapEx includes construction, equipment, permitting, and infrastructure costs. OpEx refers to maintenance and operation costs. Financing costs are driven by interest rates and required returns on equity.
Macroeconomic factors heavily influence LCOE. For example, interest rates across APAC rose following the U.S. Federal Reserve’s tightening cycle, which raised borrowing costs and thus increased financing expenses. As offshore wind requires a large upfront investment, higher interest rates significantly impact project economics. It is estimated that every 1% increase in interest rates raises the LCOE by 8%.
Commodity prices also play a role. From 2020 to 2022, prices spiked due to the post-pandemic recovery and the Russia-Ukraine war. Prices of essential materials like steel, copper, and rare-earth minerals increased, driving up the costs of turbines and infrastructure. Although prices have cooled since 2023, they remain higher than pre-pandemic levels.
Market maturity is another critical factor. In new markets, LCOE is high because local supply chains and skilled workforces are not yet developed. Local content requirements may further increase costs if domestic capabilities are lacking. Unclear or inefficient regulatory processes also increase project risks and costs. However, as markets gain experience, adopt efficient auction mechanisms, and develop robust policies, LCOE falls sharply.
Between 2014 and 2024, mature markets showed dramatic LCOE reductions. In the UK, LCOE dropped 61.9% from USD 294/MWh in 2014 to USD 112/MWh by 2021, with further reductions after an additional 5 GW of installed capacity. The Netherlands and Germany followed similar paths. These declines were supported by improved technology, particularly larger turbines that reduce installation and maintenance costs while increasing energy capture. Competitive bidding in auctions also helped drive costs down.
From 2020 to 2024, macroeconomic conditions reversed the downward trend. Inflation and high interest rates caused LCOE to rise again. In the UK, LCOE rose 65% during this period. In the Netherlands, it increased by 94%. Germany was less affected, with a 9% increase. To address this, the UK’s sixth Allocation Round (AR6) in 2024 raised administrative strike prices to better reflect cost realities. Fixed-bottom wind ASP increased from £44/MWh in AR5 to £73/MWh in AR6. The UK government also raised the offshore wind budget to £1.1 billion.
Overall, while recent years posed challenges, offshore wind in APAC is on track for growth. The experiences of mature markets provide a roadmap. Through policy innovation, financial support, and market development, emerging APAC countries can reduce costs and build a competitive offshore wind sector. The industry’s capital-intensive nature makes it vulnerable to economic fluctuations, but with proactive governance and strategic investment, it remains a promising solution for meeting climate and energy goals.
