Quick answer
Uncertainty in solar market revenue from uncontracted output or residual contract positions, assessed with matched production, prices and settlement assumptions.
Answer: Merchant risk is exposure to electricity-market revenue uncertainty for a solar project’s uncontracted output or residual contractual positions. Revenue depends on when energy is delivered, the applicable market location and settlement rules, and prices at those times. A PPA or hedge can change that exposure without eliminating every risk. Evaluate production, contract coverage and market scenarios together rather than assume a guaranteed annual price.
Where the exposure occurs
A project may sell all output at market prices, contract only part of it, or face a merchant period after an agreement expires. Contracted volume is not automatically the same as contracted revenue, and an expected future contract is not present protection.
SAM’s financial-model documentation distinguishes its merchant model from PPA models and describes time-varying market energy prices and other revenue categories. This is one documented analytical framework, not a SurgePV capability or a guarantee that a project qualifies for any market service.
Compare the physical delivery and settlement location, price interval, curtailment rules and contract term. For partial contracts, identify which volumes and prices remain exposed. Offtaker creditworthiness is another risk: a fixed contract rate does not ensure the counterparty will pay or the plant will deliver contracted energy.
Capture price uses the production profile
For matched delivery intervals, gross energy revenue is Σ(E_t × price_t), where E is delivered MWh and price is currency/MWh. Capture price is that gross energy revenue divided by the corresponding delivered MWh, before separately stated fees or other settlements.
For a hypothetical two-interval example, delivery is 2 MWh at $20/MWh and 1 MWh at $80/MWh:
Revenue = 2 × 20 + 1 × 80 = $120
Capture price = 120 / (2 + 1) = $40/MWh
The simple average of the two prices is $50/MWh. Multiplying 3 MWh by that average gives $150 and overstates this example’s energy revenue by $30. This is why annual generation multiplied by an unrelated average market price can misstate value.
Prices and energy must use matching time bins, location and settlement basis. Historical capture prices are observations, not future quotes. Negative prices, curtailment and limited delivery can affect revenue differently depending on applicable rules and contracts.
Contracts change rather than erase the risk profile
A power purchase agreement may be physical or financial, fixed or indexed, and have particular delivery/volume obligations. A financial hedge settled at one reference location may leave exposure to a difference between that location’s price and the plant’s realized price. Fixed scheduled volumes can leave production-volume and imbalance exposure.
Do not automatically classify every PPA as low risk or every merchant project as unfinanceable. Review term, credit support, settlement mechanics, termination rights and residual exposures through the applicable project/legal/financial process.
| Scenario dimension | What to retain in the model |
|---|---|
| Price | Interval/location forecast, source date and scenario basis |
| Generation | Matching profile, losses, degradation and availability assumptions |
| Contract | Covered volumes, term, price/index and settlement obligations |
| Grid delivery | Export constraints, curtailment and applicable charges |
| Costs and debt | Operating/replacement costs, debt terms and cash-flow definitions |
| Residual value | Recontracting, repowering or merchant-tail assumptions |
Evaluate downside without inventing probabilities
Run transparent price/production/availability and contract scenarios, including the post-contract period where relevant. Label whether they are sensitivities or outcomes from a defensible joint probability model. A P90 energy quantity multiplied by an assumed price is not automatically P90 revenue; generation and prices can be related.
Debt-service coverage uses the defined cash flow available for debt service and debt-service obligations, not gross energy revenue. Lender thresholds, leverage and rates are specific to the project and financing agreement. There is no universal DSCR or debt-rate premium established by the term merchant risk.
Increasing simultaneous solar supply can depress prices during producing hours under some market conditions. Demand, storage, transmission and market rules also matter; do not extrapolate a historical regional pattern to every future site. Evaluate actual time-resolved prices before recommending an orientation or tracker change.
Storage and operational handover
Storage may shift energy between price intervals, but its economics depend on charge/discharge limits, losses, costs, degradation, dispatch and market eligibility. It can introduce additional exposure and cannot guarantee higher capture value or diversification. Ancillary-service revenue requires the applicable qualification and dispatch assumptions.
Design teams should provide reproducible delivery profiles. Developers should retain actual contract coverage and interconnection constraints. Finance teams should reconcile modeled settlement revenue, costs and debt schedules and disclose scenario limitations. Verify actual software capabilities before promising automatic market-risk analysis or forecast accuracy.
Frequently asked questions
Can a project have a PPA and merchant risk?
Yes. Uncontracted output, a merchant tail and residual price/location or volume exposures can remain.
Is capture price the simple average market price?
No. It weights matched prices by the delivered energy in those intervals.
Is P90 energy automatically P90 revenue?
No. Revenue depends on the joint production, price and settlement assumptions.
Does adding a battery guarantee lower risk?
No. Evaluate storage costs, losses, controls, eligibility and additional exposures in the actual project model.
Related Glossary Terms
About the Contributors
Co-Founder · SurgePV
Akash Hirpara is identified by SurgePV as a company co-founder. His SurgePV author page lists only role information that can be tied to the public profile below; education, certifications, project totals, financial results, speaking engagements, and media appearances are not asserted without retained evidence.
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