What we do for your plant

A solar plant’s weighted sales price can fall well below the daily average PTF. Contract and forward structures should account for this gap.

For YEK-certified plants commissioned between 1 July 2021 and 31 December 2030, the YEKDEM price applies in TL within a US dollar floor and cap. Which channel is worth more should be reviewed every year.

On a sunny noon most plants in a region deviate the same way. Under the 2026 coefficients, deviation with the system is priced at 6% and against it at 3%.

A battery shifts midday output into the evening and captures output above the connection limit. Its economics depend on spreads and ancillary depth.

Correcting the position on the intraday market with an updated forecast reduces the volume left to imbalance.

Imbalance is priced off PTF and SMF. Deviations beyond the tolerance band of the final schedule also incur KÜPST.

Deviations of plants in different regions and technologies offset each other. A balancing group or aggregator portfolio turns this into revenue.

Solar can be added to a wind site as an auxiliary source. Plants whose main source is wind are exempt from the 100 MW limit on auxiliary sources.

Water used at the evening peak rather than at low midday prices earns more for the same MWh. Day-ahead bids are built around this allocation.

Fast-responding hydro plants can take up/down instructions and frequency control reserves. Today hydro and gas plants provide a large share of primary and secondary reserves.

Output falls in a dry year. Forward sales should be limited to output expected with confidence and layered over time.

Hydro plants whose ten-year YEKDEM period ends must set their own sales channel. The transition should be planned before the end date.

Arbitrage, primary and secondary control and balancing exclude each other. Capacity is allocated hour by hour by comparing expected value and risk.

Frequency reserve is capped by system need: in the week of 27 April – 3 May 2026 the average hourly primary reserve was 274 MW and secondary 942 MW. As storage grows this revenue is shared.

Every cycle wears the battery. Trading decisions respect annual cycle and state-of-charge limits in the warranty.

Connection configuration and licence amendment shape the commercial model directly. Energy injected is capped by the accepted electrical capacity.

Generation and storage share one connection limit. Midday output above the limit is sent to the battery instead of being lost.

Energy drawn from the grid into storage and fed back does not benefit from the plant’s incentives or purchase guarantees. This must be reflected correctly in metering and settlement.

Generation needs predictable revenue; storage needs hourly optimisation. Pricing both correctly in one contract is the basis of revenue.

In fully renewable combined plants, net energy fed to the grid is valued under YEKDEM at the lowest of the applicable source prices for the remaining period.

Generation and consumption net separately every hour. The value of energy fed to the grid in hours without consumption follows that hour’s rules.

The incumbent supplier must buy the eligible energy. Plants at the same metering point as consumption can sell all output; plants at a different point can sell only the surplus.

Following the Constitutional Court decision, the licence fee provision expires on 10 December 2026; without new legislation the route from unlicensed to licensed generation lapses.

Since 1 January 2026, storage built by unlicensed generation plants is a separate category subject to the conditions of the Unlicensed Generation Regulation.