Published: February 14, 2026 | Updated: June 18, 2026
POLICY & REGULATION
How does an offshore wind project in Japan actually earn its revenue? The answer is no longer the Feed-in Tariff (FIT) — the fixed-price guarantee that built Japan’s solar boom — but the Feed-in Premium (FIP), a market-linked mechanism that pays the wholesale price plus a premium. The distinction sounds technical, but it decides who carries price risk. And in Round 3 of Japan’s offshore wind auctions, every consortium bid an effectively zero premium — voluntarily taking on the full exposure of the wholesale market. Understanding FIT versus FIP is therefore the starting point for understanding why offshore wind bankability in Japan has become so difficult.
👉 Japan’s Offshore Wind Policy & Regulatory Framework
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FIT guarantees a fixed purchase price for a set period and exempts the generator from imbalance responsibility. FIP pays the wholesale market price plus a premium, but the generator sells into the market, bears imbalance responsibility, and can trade non-fossil value separately. The shift from FIT to FIP is a shift of price risk from the consumer to the developer.
Japan’s offshore wind auctions are structured under FIP. In Round 3 (Aomori and Yamagata fixed-bottom zones, 18 JPY/kWh ceiling), every bidder submitted an effectively zero-premium bid, meaning revenue depends almost entirely on the wholesale price the project can capture.
Merchant price exposure widens the P50–P90 revenue spread that lenders model, pressuring DSCR. This is why the Long-Term Decarbonization Auction (LTDA), which restores long-term fixed income, has become the alternative developers watch.
Two Revenue Models, One Structural Difference
FIT and FIP are not subsidy programs in the everyday sense. They are revenue frameworks: they define how electricity is sold, how price risk is allocated, and therefore what financing assumptions a project can support. For a capital-intensive asset like offshore wind — where most of the cost is incurred up front and recovered over 20 or more years — that allocation is decisive.
Under the FIT scheme, electricity from certified renewable sources is purchased at a fixed price for a predefined period. The generator is insulated from wholesale price movements and exempt from imbalance responsibility (the cost of any gap between forecast and actual output). The cost of this guarantee is socialized across all electricity users through a renewable energy surcharge added to monthly bills. FIT applies to five categories — solar, wind, hydro, geothermal, and biomass — and was deliberately designed to give early-stage technologies the revenue certainty needed to attract capital.
Under the FIP scheme, the generator sells electricity directly into the wholesale market and receives a premium on top of the market price. The premium is the difference between a reference value set by policy (the FIP price) and a market reference price that tracks actual wholesale conditions. In exchange for this flexibility, the generator takes on imbalance responsibility and full exposure to price volatility — but can also monetize non-fossil value as tradable certificates, a revenue stream FIT folds into its fixed price.
| Feature | FIT (Feed-in Tariff) | FIP (Feed-in Premium) |
|---|---|---|
| Purchase price | Fixed rate guaranteed for a set term | Wholesale market price + premium |
| Who bears price risk | Consumers (via surcharge) | The power producer |
| Imbalance responsibility | Exempted | Borne by the producer |
| Non-fossil value | Included in the fixed price | Tradable as separate certificates |
| Policy intent | Revenue certainty, early deployment | Market integration, price-aware dispatch |
The electricity itself is generated the same way under either scheme — the difference is entirely in how it is sold and who absorbs the risk. (For the engineering side of how that electricity is produced, see How a Wind Turbine Works.)
Why Offshore Wind Sits Under FIP — and What Round 3 Revealed
Japan’s offshore wind auctions are structured under FIP, not FIT. Developers compete on a bid price (the FIP reference price), participate in the wholesale market, and receive the premium determined through the auction. This was a deliberate policy choice to integrate offshore wind into the electricity market rather than wall it off behind a fixed tariff.
The consequence became visible in Round 3. For the two fixed-bottom zones offered (off the Sea of Japan side of Aomori and off Yuza, Yamagata), the auction ceiling was set at 18 JPY/kWh — and every competing consortium submitted an effectively zero-premium bid. A zero premium means the bid price sits at roughly the same level as the expected market reference price: the project receives little or no top-up above what it earns selling power into the wholesale market. In practical terms, the developers committed to recovering their costs almost entirely from merchant revenue.
Under FIP, two risks that FIT absorbs land on the developer’s balance sheet. First, imbalance responsibility: the producer pays for any gap between its forecast output and what it actually delivers — a real cost for a weather-driven asset. Second, merchant price exposure: when the premium is near zero, revenue tracks the wholesale price, which can fall well below the levels assumed at financial close. A project that pencils out at an assumed average capture price can become unviable if wholesale prices soften over a 20-year horizon — and that uncertainty is priced in by lenders long before it materializes.
From Revenue Framework to Bankability
This is where the FIT-versus-FIP distinction stops being academic. Project finance for offshore wind is sized on the debt service coverage ratio (DSCR) — how many times over the project’s cash flow can cover its debt repayments. Lenders do not size debt against expected (P50) revenue; they size it against a conservative case (P90), and the wider the gap between P50 and P90, the less debt a project can carry at an acceptable DSCR.
FIP, especially at a near-zero premium, widens that gap. Fixed-price FIT revenue is essentially a flat line a lender can underwrite with confidence. Merchant revenue is a distribution — and a wide one over two decades of wholesale price uncertainty. The result is downward pressure on the financeable debt amount and on DSCR, which in DeepWind’s bankability framing means moving from the Strong band (DSCR ≥1.35x) toward the Borderline (1.20–1.35x) or Difficult (<1.20x) territory where projects stall.
A zero-premium FIP bid is, in financing terms, a merchant project wearing a policy label. Lenders underwriting it must model wholesale price scenarios across the full debt tenor, apply a conservative capture-price assumption, and widen the P50–P90 spread accordingly — all of which shrinks the supportable debt and raises the equity share. This is the mechanism behind Japan’s stalled offshore wind FIDs: not that the policy framework is absent, but that the revenue it provides is too exposed to underwrite at the scale the projects need. It is also why the Long-Term Decarbonization Auction (LTDA), which awards a fixed long-term capacity payment, has drawn developer attention as a more bankable complement to FIP.
The pattern is not hypothetical. The withdrawal of the Round 1 winning consortium from three large fixed-bottom sites turned, at its core, on the gap between auction-era cost and price assumptions and the realities that followed — a revenue-and-cost squeeze that FIP’s market exposure made sharper, not softer.
👉 Mitsubishi’s Offshore Wind Exit: Profitability and the Policy Turning Point
👉 Offshore Wind Cost Structure and Economics in Japan
The Cost Layer: Generator-Side Levy and Post-Procurement Obligations
Two further policy shifts reshape the revenue picture beyond the FIT/FIP choice itself, both pointing the same way — generators are being asked to carry more of the system’s cost.
First, the generator-side levy (a charge for the grid-connection service) took effect in April 2024. It shifts part of the transmission and distribution cost — historically recovered from retailers — onto generators, in a roughly 10% generator / 90% retailer split, with small sources exporting under 10 kW exempt for the time being. Existing FIT- and FIP-certified projects become subject to the levy once their procurement period ends, so it functions as a long-tail cost that revenue models must carry well beyond the support window.
Second, compliance enforcement has tightened. Projects certified under FIT or FIP that were found to violate related laws — such as the Farmland Act or Forest Act — have had their support suspended (the Agency for Natural Resources and Energy applied such a suspension in 2024). The policy direction has moved from rewarding capacity expansion alone toward conditioning support on legal compliance and community coexistence.
The FIT-to-FIP shift moved Japan’s renewable revenue from a guarantee to a market bet — and offshore wind is where that bet is hardest to finance.
FIP is the right long-term design: a mature renewable sector should sell into the market and respond to price signals. But timing matters. Japan asked offshore wind — its most capital-intensive, least commercially proven renewable — to take on near-full merchant exposure before a deep enough market and a stable cost base existed to support it. Round 3’s uniform zero-premium bidding was not a sign of confidence; it was the auction format forcing developers to absorb risk that the financing market then declined to underwrite at scale.
The structural fix is not to abandon FIP but to pair it with a bankable floor. The Long-Term Decarbonization Auction points in that direction, and the June 2026 auction reforms — including a price floor — are an admission that pure market exposure was premature for this asset class. The revenue framework, in other words, is being re-engineered around the bankability test it initially failed.
Related DeepWind Articles
- Japan’s Offshore Wind Policy & Regulatory Framework
- What Is Japan’s LTDA? The Long-Term Decarbonization Auction Explained
- Offshore Wind Cost Structure and Economics in Japan
- Japan Overhauls Offshore Wind Auction Rules
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