Vietnam Power Project Finance: PPAs and Cost of Capital

The same warning from the Ministry of Industry and Trade about securing power for 2026 reads very differently from the desk of someone arranging the financing. The question is not whether Vietnam has enough power. It is how a power project gets structured so that a bank is willing to lend against it. This piece takes apart the mechanism: whether the power purchase agreement is bankable, where grid-connection risk sits, how merchant revenue differs from contracted revenue, and why every loose link adds a premium to the cost of capital.

A generation project in Vietnam typically borrows around 70 percent of its capital from banks and contributes only 30 percent equity. That debt load only holds if future cash flow is predictable. And a power plant’s cash flow rests on three things: who buys the electricity, at what price, and whether the power can actually reach the grid. Break any one of the three and the lender will demand more equity, tighten loan terms, or walk. That is why project structure, not technology or fuel source, is usually where a power project lives or dies.

Unlike the broad piece on how supply security sets the ceiling for capital, this article goes to the core: the specific mechanism that decides whether a project can be financed, and the risk premium added at each link. A reader who wants to understand the door through which capital actually flows into power infrastructure will find the answer in contract terms, not in installed capacity.

The power purchase agreement and whether a project is bankable

At the heart of a financeable power project is the power purchase agreement. This is the document that binds the offtaker, usually the national electricity buyer, to purchase output over many years at a price set by a predetermined formula. Lenders read this contract before anything else, because it is what turns a plant into predictable cash flow. The longer the term, the clearer the price, and the firmer the obligation to buy, the easier the project is to finance.

What weakens bankability lives in clauses that look small. Whether the offtaker can curtail dispatch when the grid is overloaded. Whether the investor is compensated when curtailed. Who bears the currency mismatch between revenue earned in dong and debt denominated in foreign currency. Whether the dispute-resolution mechanism is strong enough to reassure international lenders. Every unsettled clause is a line of uncertainty, and lenders price that uncertainty through a higher interest rate or a thicker equity requirement.

Grid-connection risk: power generated is not power sold

A plant can generate plenty of electricity yet still fail to deliver it if the connecting transmission segment is not ready. This is grid-connection risk, and for wind and solar in regions far from load centres it is especially heavy. When the connecting line is built by another party and runs late, a completed plant sits idle, servicing its debt while earning nothing.

Lenders separate construction risk from connection risk sharply, because the two are held by different parties and often fall out of sync. They ask: who is responsible for the connection, is there a binding schedule commitment, and if the grid is congested, how far does actual output fall below the design figure. A vague answer here pushes the dispatch assumption in the financial model down, which drags projected cash flow lower and shrinks the amount that can be borrowed.

Merchant revenue versus long-term contracted revenue

A project selling under a long-term contract at a fixed price has a stable revenue stream and is easy to finance. A project selling at the spot market price has revenue that swings with hourly supply and demand, more attractive when prices are high but exposed to price risk. Vietnam is shifting gradually toward a more competitive power market, and that shift changes how each project’s risk is priced.

For lenders, the merchant portion is the hardest to finance, because no one guarantees a future price. Many projects therefore adopt a hybrid structure: a share of output locked into a long-term contract to provide the base cash flow needed to service debt, the rest sold at market to capture upside. The ratio of contracted to merchant volume is one of the most important levers an arranger uses to balance bankability against expected return.

Where the cost-of-capital premium is added

Every risk the contract fails to allocate clearly becomes a number in the financial model. Curtailment risk lowers the output assumption. Currency risk thickens the contingency. Connection risk pushes back the point at which revenue begins. Each adjustment either drags the debt-service coverage ratio down or forces more equity in, and both raise the project’s weighted cost of capital.

This premium is not abstract; it shows up as a higher lending rate, a wider margin, and a larger minimum equity stake. A coherent contractual framework that allocates risk well pulls all three down and widens access to capital; a loose one does the reverse. The arranger’s real job, then, is not to find money but to structure risk so that the cash flow is firm enough for money to flow in at a reasonable price.

Why structure, not capital, is the real bottleneck

Capital for power infrastructure in the region is not scarce. What is scarce are projects structured well enough to absorb it. A project with a firm power purchase agreement, a clearly defined connection, and a coherent risk-allocation framework will reach financial close; a project missing those pieces stalls at the financing stage no matter how large the demand for power.

For Vietnam, this is where policy meets the market. A standardised contract framework, a connection mechanism with schedule commitments, and a predictable power-market roadmap would make most projects more bankable without a single dong of additional subsidy. That is the cheapest lever for pulling capital into power infrastructure: not injecting more money, but removing the uncertainties lenders are currently charging for.

Conclusion

Supply security sets the ceiling on capital at the macro level, but at the level of an individual project it is the financial structure that decides whether capital flows in. The power purchase agreement, grid-connection risk, and the choice between merchant and long-term contracted revenue are the three links that determine whether a power project is bankable, and a risk premium is added at each one.

If Vietnam wants to keep capital in power infrastructure, it has to make those links firm and predictable. When risk is clearly allocated in the contract, the cost-of-capital premium shrinks and more projects reach financial close. When risk is left ambiguous, lenders charge for the ambiguity, and capital retreats to markets with clearer structures.

Lotus Investment Group advises on cross-border M&A and FDI into Vietnam and Southeast Asia. If you are underwriting Vietnam exposure, get in touch.