How to leverage cogeneration for additional benefits – price arbitrage and flexibility

In modern industrial facilities, energy is not only an operating cost but also a variable financial asset. Fluctuations in gas and electricity prices, exposure to the spot market, and the growing importance of ancillary services mean that energy production alone is no longer sufficient to achieve a competitive advantage.

Cogeneration, when treated as a standalone generation source, can stabilize part of the cost base. However, its full economic value is unlocked only when it is integrated with the energy market and flexibility mechanisms. Areas extending beyond electricity and heat production include:

• participation in the balancing market,
• electricity price arbitrage,
• flexibility management of energy generation,
• optimization of exposure to the gas-to-power spread,
• integration with energy storage systems and DSR solutions.

In this model, energy demand management becomes particularly important. Shifting grid consumption over time, reducing operation during peak hours, and optimizing the consumption profile become just as important as energy generation itself. Peak demand remains one of the most expensive components of industrial energy costs, which is why reducing it through operational flexibility and system integration directly translates into improved financial performance for the facility.

The balancing market and ancillary services enable companies to be compensated for their ability to rapidly adjust energy consumption or generation. In the case of cogeneration, this means the ability to control production depending on price signals and the needs of the system operator.

Instead of operating continuously, a CHP unit can be:

• reduced during periods of low electricity prices,
• increased during periods of high market valuation,
• used as a reserve capacity source.

In practice, this means that the same installation can simultaneously produce energy and generate revenue from ancillary services, transforming its role from a cost-generating asset into a revenue-generating one.

Energy arbitrage involves taking advantage of price differences between hours, days, or markets (spot and forward). The spot market is where energy is bought and sold for immediate delivery or within a very short timeframe (most commonly day-ahead trading). The forward market is where energy is bought or sold for delivery at a future date at a predetermined price.

Cogeneration, especially when combined with battery energy storage systems (BESS), enables active management of the timing of energy production and sales. The mechanism works as follows:

• energy production during periods of low fuel costs and high electricity prices,
• reduced operation or energy storage during periods of an unfavorable spread,
• sale of surplus electricity during periods of high spot prices.

The spread is the difference between the cost of generating electricity (primarily gas costs combined with cogeneration efficiency) and the electricity sales price. An unfavorable spread occurs when the electricity market price (e.g., on the spot market) is lower than the cost of generation in the CHP unit, or when the difference between gas prices and electricity prices does not cover the plant’s efficiency losses and operating costs.

Energy flexibility refers to a facility’s ability to modify its energy consumption and generation profile over time. In the case of cogeneration, this includes:

• regulation of CHP unit output,
• management of process heat consumption,
• integration with energy storage systems,
• shifting electricity demand over time (load shifting).

Flexibility enables facilities to reduce peak-related costs (peak shaving), lower capacity charges, and minimize exposure to high electricity prices during peak hours. Energy flexibility directly impacts a plant’s financial performance because it changes the way energy is purchased, generated, and settled over time.

A facility with high flexibility can actively respond to market price signals by reducing consumption during periods of high prices, increasing self-consumption during periods of surplus generation, and shifting the operation of cogeneration units and energy storage systems into the most economically advantageous time windows. As a result, not only are direct electricity purchasing costs reduced (often by 10–25% annually depending on the consumption profile), but peak demand costs and distribution charges resulting from maximum grid withdrawals are also lowered.

In addition, flexibility enables the monetization of energy assets. Through participation in DSR programs and ancillary services markets, facilities can receive compensation simply for being ready to reduce or increase power consumption, even without physically changing production levels. In a well-designed system, flexibility evolves from an operational function into a value stream that generates both cost savings and direct revenue.

A cogeneration installation alone does not guarantee full optimization potential. In the event of changes in energy prices (e.g., gas prices), it may generate losses if it is not managed systematically. The most common challenges include:

• an unfavorable relationship between gas and electricity prices (generation from cogeneration becoming more expensive than purchasing electricity from the market),
• overproduction of electricity sold to the grid at low prices,
• a mismatch between generation and consumption profiles,
• lack of participation in ancillary services markets,
• high peak demand costs.

As a result, cogeneration without an energy management layer becomes merely an energy source rather than a financial optimization tool.

The highest economic value is achieved in an integrated model that combines three elements:

Cost hedging

Securing the gas-to-power spread through long-term contracts. This helps stabilize production costs and limit exposure to spot market volatility.

System flexibility

Battery energy storage systems (BESS) and cogeneration control enable:

• peak shaving,
• price arbitrage,
• optimization of self-consumption.

Monetization of ancillary services

Participation in DSR and capacity markets enables companies to generate additional revenue simply from their ability to respond to the needs of the power system.

The effectiveness of cogeneration in a market-based model depends not on the technology itself, but on the way it is managed. What matters is not only energy production itself, but also the contract structure, market exposure, and the facility’s ability to utilize flexibility. In practice, it is a system of operational and market-based decisions that can generate significant financial benefits if properly designed and managed.

Technologies should not be viewed as standalone generation sources, but as elements of a broader energy and financial ecosystem. In this approach, cogeneration, energy storage, market contracts, and spot market exposure form one integrated mechanism. Leveraging energy market opportunities and contractual structures makes it possible to manage price risk rather than merely react to it. At the same time, ancillary services are becoming increasingly important – participation in balancing markets, DSR programs, and capacity markets is emerging as an additional way to monetize energy assets, often delivering greater benefits than the implementation of new technology alone.