Business energy costs – where can you really find savings?

The energy price expressed in PLN/MWh is the most visible part of any discussion about costs, but on its own it does not explain why a business pays what it does for energy. The final bill is also affected by distribution, contracted capacity, the load profile, tariff group, the capacity charge, reactive energy settlements, gas purchasing terms and – above all – the actual consumption of equipment and technological processes.

For this reason, energy cost analysis is best approached in the reverse order to the conventional search for “cheaper electricity”. First establish which component of the bill generates the cost and why, and only then decide whether the right response is to change contract parameters, reorganise operations or make a technical investment.

The price of 1 MWh is only one part of the bill

In simplified terms, a company’s total energy cost can be divided into several groups:

• the cost of purchasing electricity or gas;
• distribution costs and other charges arising from tariffs and settlement rules;
• costs associated with contracted capacity and any exceedances;
• the capacity charge;
• charges for excess reactive energy;
• costs resulting from the load profile and selected tariff group;
• actual energy consumption by processes, auxiliary systems and buildings.

This distinction matters because a reduction in the active-energy price does not automatically reduce the other components. If a company uses, for example, 2,000 MWh of electricity per year, reducing the purchase price by PLN 20/MWh produces annual savings of PLN 40,000 in the procurement component. That is a tangible benefit, but it says nothing about whether contracted capacity is set correctly, whether the company pays reactive-energy charges, what its load profile looks like or how much energy it consumes unnecessarily.

In practice, therefore, it is worth looking beyond a single rate in a supplier’s offer and considering the full cost of delivering and using energy in the business.

What makes up a company’s energy costs?

Electricity procurement: important, but not the only factor

The active-energy price can be highly significant, especially where annual consumption is high, so purchasing terms should be analysed. Products must, however, be compared on the same basis: not only the PLN/MWh price, but also how it is determined, the contract term, indexation, additional fees, volume and the consequences of a product that does not match the company’s load profile.

Choosing the product and supplier is a separate topic. We discuss it in more detail in our article on the electricity and gas procurement process for businesses. In an energy cost analysis, procurement is only one part of the overall picture.

Electricity distribution: costs depend on more than consumption

For businesses in Poland, distribution costs may include both components linked to the amount of energy consumed and components linked to capacity and other billing parameters. Tariff groups differ, among other things, by voltage level, contracted capacity, settlement method and number of time zones. Exact rates and rules must always be checked against the current tariff of the relevant Polish distribution system operator (DSO).

This is why two companies with similar annual electricity consumption can have different cost structures. One operates evenly around the clock, while another has short, high demand peaks; one benefits from a multi-zone tariff, while another consumes a significant share of its electricity in more expensive time zones.

Contracted capacity: finding the highest peak is not enough

Contracted capacity is a parameter defined in the contract and directly affects distribution settlements. Under the applicable Polish tariff rules, it is linked to active power and values derived from metering, normally over 15-minute intervals. The operator also monitors exceedances of contracted capacity, which may result in additional charges.

A common mistake is simply to compare two numbers. If a company has contracted 600 kW and the highest recorded value over the past year was 480 kW, this does not automatically mean that capacity should be reduced to 500 kW. At a minimum, seasonality, start-ups, planned investments, shutdowns, the risk of exceedances and the rules for changing capacity under the contract and the DSO tariff must be checked.

The timing and procedure for the change must also be checked. Under §49(2) of the Polish tariff regulation, if a customer reduces contracted capacity with the consent of the energy company, the fixed component of the network rate is increased by 10% for the entire period covered by the reduction. The effect should therefore not be calculated simply as “fewer kW × rate” – the contract, tariff and effective date of the change also matter.

Only analysis of the full profile can show whether the issue is excessive contracted capacity, insufficient capacity and the cost of exceedances, or the way loads are started simultaneously.

Load profile and tariff group

Annual consumption in MWh does not show when energy is used. Yet the distribution of consumption across the day, week and year can determine whether a particular tariff group is economical, affect demand peaks and reveal unnecessary consumption outside production hours.

A tariff analysis should therefore not be limited to calculating cost from a single invoice. A 15-minute or hourly profile is needed, together with a simulation of the same actual load under alternative settlement options. Only then can the options be compared without creating savings that exist merely “on paper”.

Capacity charge: the settlement method, profile and consumption hours matter

In Poland in 2026, not every business customer is billed for the capacity charge in the same way. Until the end of 2027, the Capacity Market Act provides for a flat-rate settlement for the group specified in Article 89a(1)(1). This includes not only households but also, among others, other consumption points supplied from networks with a rated voltage not exceeding 1 kV and contracted capacity not exceeding 16 kW. Other customers referred to in Article 89a(1)(2) are charged a rate applied to energy consumed during selected hours of the day.

For that second group, the Polish capacity-charge rate for 2026 is PLN 0.2194/kWh. Information No. 57/2025 of the President of the Polish Energy Regulatory Office (URE) specifies 15 consecutive hours for each quarter of 2026 on every working day, excluding statutory public holidays: the first starts at 07:00 and the fifteenth at 21:00, so the analysed period runs from 07:00 to 22:00.

The variable charge is affected by more than just the volume consumed during those hours. The Polish Capacity Market Act divides customers into K1–K4 groups and applies an A coefficient of 0.17, 0.50, 0.83 or 1 respectively. The charge for a qualification period is calculated as WOM = A × ZK × SOM, so the load profile also affects customer classification.

For this reason, the simple calculation 100 MWh × PLN 0.2194/kWh = PLN 21,940 is only a base value before applying coefficient A, not a universal charge or guaranteed saving. If – purely for illustration – the full 100 MWh were subject to one coefficient, the result would be PLN 3,729.80 for K1, PLN 10,970 for K2, PLN 18,210.20 for K3 or PLN 21,940 for K4. The actual effect of changing the profile must be calculated from metering data and the actual settlement classification.

This creates scope for load-profile optimisation, but it does not mean every company should move production to night-time. A schedule change only makes sense when the benefit on the full bill exceeds any additional labour, logistics, start-up, process-quality and other operating costs.

Reactive energy: an invoice item may point to a technical problem

Charges for excess reactive energy are not another purchase price for active energy. They arise from installation operating parameters and the settlement method defined in the tariff. Their occurrence may be related, among other things, to the nature of loads, incorrectly matched compensation or a change in the plant’s operating pattern.

A compensation system should therefore not be selected solely on the amount shown on one invoice. First determine whether the issue concerns inductive reactive energy, capacitive reactive energy or both, how it changes over time and in which parts of the installation it arises. Only then should reactive-power compensation be assessed as an investment.

Gas: separate the fuel price from the cost of delivering and using it

For gas, the principle is similar to electricity. A business should separate the purchasing terms for the fuel itself from infrastructure and distribution costs, then compare both with the actual consumption profile. In Poland in 2026, the Polish Gas Company (PSG) tariff provides for fixed and variable distribution-charge components, also differentiated by tariff area. URE approves gas distribution tariffs for all customer groups, whereas gas sales tariffs generally concern households and specified customers performing public-service functions.

At an industrial site, it is therefore worth asking two separate questions: are we buying gas well, and are we using it well? A cheaper contract will not compensate for poor boiler efficiency, high flue-gas temperatures, unnecessarily high process parameters or heat losses in the system.

Actual process consumption: an area hidden by the MWh price

The biggest difference between invoice analysis and a plant energy analysis appears when costs are related to what is actually happening in production. The bill will show how much energy was consumed. It will not show whether a compressor ran unnecessarily, a refrigeration system maintained too low a temperature, a fan ran at constant output despite variable demand, or a line remained energised during downtime.

After analysing invoices and load profiles, it is therefore useful to build indicators linking energy use to business activity, such as kWh per tonne of product, kWh per unit, downtime consumption, night-time baseload or weather-adjusted heat consumption. This helps distinguish a cost increase caused by price from one caused by the way the plant operates.

How to analyse energy costs step by step

The safest sequence of analysis is as follows.

1. Collect invoices and contracts, but do not stop there

A good starting point is 12–24 months of electricity and gas invoices, separately for each consumption point. Sales and distribution contracts should also be collected, together with information on the tariff group, contracted capacity, contract terms and items relating to capacity exceedances and reactive energy.

At this stage, obvious irregularities can already be identified and the cost structure can be seen, but an invoice is primarily a record of settlement – not a complete picture of plant operation.

2. Obtain metering profiles

For electricity, a 15-minute or hourly profile is crucial. It shows demand peaks, consumption in tariff zones, consumption during capacity-charge hours, night and weekend operation, and changes in the nature of demand between months.

If the company has several consumption points, they should be analysed separately. Combining everything into one annual volume can hide the fact that savings are possible only at one facility or one connection point.

3. Break the cost down by source

Each material item should be assigned a category: procurement, distribution, capacity, capacity charge, reactive energy, gas, process consumption or another component. The parameter driving it must then be identified.

This is the point at which the question “how do we reduce the bill?” is replaced by questions that can be quantified: is contracted capacity matched to the profile, would a tariff change reduce cost for the same load, how much energy falls within capacity-charge hours, and does reactive energy occur continuously or only in specific operating modes?

4. Link the profile to plant operation

Energy data becomes useful only when it is compared with production and operating schedules. You need to know what was happening when the peak occurred: was a line starting, were compressors being brought online, were furnaces switched on, did defrosting begin, or was it an unusual incident?

Consumption outside production is analysed in the same way. A constant weekend load may come from equipment that has to run, but it may also indicate uncontrolled ventilation, compressed air, heating, cooling or equipment left in standby mode.

5. Build scenarios and calculate the effect using the same data set

Only after the cause has been identified should scenarios be compared. For tariffs, the same load profile is recalculated under different settlement groups. For contracted capacity, fixed cost is compared with the risk and cost of exceedances. For a schedule change, check whether savings on one charge generate higher operating costs elsewhere. For a technical modernisation, compare the investment with the consumption that will actually be reduced.

This prevents a common mistake: demonstrating savings in one component while another cost increases at the same time.

Which savings may not require investment?

Some cost issues are contractual, settlement-related or organisational. In such cases, buying equipment does not have to be the first action. This group may include:

• adjusting contracted capacity after analysing the profile and exceedance risk;
• changing the tariff group if a simulation on the actual profile shows a benefit;
• changing parameters or terms of electricity and gas purchasing contracts;
• shifting flexible loads away from unfavourable zones or hours where the process allows it;
• sequencing equipment start-ups to limit demand peaks;
• switching off unnecessary loads during downtime;
• adjusting setpoints and schedules in existing automation.

However, the absence of capital expenditure does not mean a change can be made “by feel”. Contracted capacity and tariff selection in particular should be checked against the historical profile and the current terms of the relevant Polish DSO.

When is a technical investment needed?

If the source of the cost is the way an installation operates, changing the contract alone will not remove the problem. Measures that may then be justified include:

• a reactive-power compensation system sized on the basis of measurements;
• a monitoring and sub-metering system where existing data does not allow consumption to be located;
• demand control and load automation;
• variable-frequency drives for motors operating under variable load;
• leak reduction and pressure optimisation in compressed-air systems;
• modernisation of refrigeration, ventilation, heating or lighting;
• heat recovery or improved heat-source efficiency;
• modernisation of the technological process.

The sequence matters. If it is not known how much energy a given installation uses or how it operates, the effect of an investment cannot be calculated reliably. In such cases, energy monitoring and management is a diagnostic tool, not an end in itself.

Why can “cheaper energy” make little difference?

In procurement negotiations it is easy to focus on one number: the price in PLN/MWh. This is logical because it is easy to compare. The problem starts when that figure is treated as synonymous with the entire bill.

If a company reduces the active-energy price by 4%, but the procurement component represents only part of the total cost, the overall bill will not fall by 4%. If process consumption rises at the same time, capacity exceedances occur or the load profile shifts into less favourable hours, the effect may be smaller still.

It is therefore worth assessing separately:

1. unit purchase price – how much one MWh of the product costs;
2. delivery cost – the cost of distribution and network parameters;
3. profile – when energy is consumed and at what demand level;
4. volume – how much energy the company actually uses;
5. energy productivity – how much product or service is generated per unit of energy.

Only by improving one or more of these areas can the full picture of energy-cost optimisation be seen.

The most common mistakes when looking for savings

Comparing offers solely by the PLN/MWh price

A lower product price does not necessarily mean a proportionately lower total bill. The full purchasing terms must be compared and the share of procurement in total cost must be checked.

Analysing only one invoice

One month does not show seasonality, shutdowns, production changes or the risk of capacity exceedances. It can be useful for initial screening, but not for decisions on parameters for the whole year.

Reducing contracted capacity on the basis of one maximum

A single peak or a single month is not enough. The demand distribution, frequency of events and future needs of the plant must be assessed.

Changing tariff without recalculating the actual profile

A multi-zone tariff is not inherently better than a single-zone tariff. Its economics depend on the hours in which the company actually uses energy and the rates applied by the relevant Polish DSO.

Treating reactive energy purely as an “invoice charge”

This is a cost whose source must be sought in the installation. Without measurement, it is easy to select the wrong solution or overlook the fact that the problem occurs only at certain times.

Investing before diagnosing the source of the cost

Equipment modernisation may be justified, but if the problem is caused by the tariff, contracted capacity or operating schedule, no-cost or low-cost measures should be used first.

What comes from tariffs and regulations, and what comes from analytical practice?

Two layers should be kept separate. Polish regulations and tariffs define the settlement method: the definition of contracted capacity, rules for charges for capacity exceedances and excess reactive energy, tariff-group criteria and the current capacity-charge rate. Specific distribution rates are checked in the current tariff of the relevant Polish DSO.

Analytical practice, by contrast, answers a different question: what do those rules mean for a particular company profile? This requires metering data, process knowledge, scenario simulations and risk assessment. The law will not tell you whether a particular plant should reduce contracted capacity, change compressor operating hours or modernise refrigeration – that decision must be derived from data.

How should a company prioritise actions?

The simplest rule is: diagnose the source of the cost first, then choose the tool.

If the issue is a billing parameter, start with the contract and tariff. If it stems from the profile, examine work organisation and the ability to control loads. If the cost comes from low efficiency or losses, technical analysis and investment will be required. If several issues occur at once, actions should be prioritised according to their real impact, expenditure, risk and effect on production.

Such a diagnosis should be the starting point for a broader corporate energy strategy, in which purchasing, technical and investment decisions are assessed together rather than as separate projects.

If the analysis shows that the main source of cost lies in distribution parameters, the load profile or contracted capacity, a separate next step may be detailed electricity-cost optimisation. This article, however, addresses the earlier stage: identifying where the cost is actually generated and which data must be checked before a decision is made.

Frequently asked questions

Can savings be identified from invoices alone?

Invoices are often sufficient for initial screening: they can reveal the cost structure, reactive energy, exceedances, tariff group and volume changes. Decisions about contracted capacity, tariff, operating schedules or investment usually also require a metering profile and – for technical issues – additional measurements.

Does reducing contracted capacity always lower the bill?

No. Lower capacity can reduce some fixed costs, but an overly aggressive reduction increases the risk of exceedance charges and may constrain plant expansion. The rules and timing of the change must also be considered: under the Polish tariff regulation, reducing contracted capacity with the energy company’s consent entails a 10% increase in the fixed component of the network rate for the period covered by the reduction. The decision should therefore be preceded by an analysis of the load profile, contract, DSO tariff and production plans.

Does changing tariff group require investment?

Often not, where the change concerns a settlement method available under the connection conditions and tariff. The Polish DSO’s requirements must always be checked and the cost recalculated for the actual profile. Changes in voltage level or supply configuration may, however, require investment.

Can the capacity charge be reduced only by operating at night?

No. First identify which loads are genuinely flexible. Sometimes it is enough to shift some auxiliary processes, charging, energy-storage operation or other loads, but only if this does not adversely affect production or the total energy cost.

Sources and data status

The status of Polish regulations and dynamic data was checked on 10 August 2026. In particular, the following sources were used:

• ELI – consolidated text of the Act of 8 December 2017 on the capacity market – including Articles 70a and 89a.
• URE – capacity-charge rates – rate for 2026.
• URE – Information No. 57/2025 of the President of URE – selected hours of the day in 2026.
• ELI – Polish tariff regulation, Journal of Laws 2024 item 904.
• ELI – amendment to the Polish tariff regulation of 12 December 2025.
• URE – electricity sales and distribution tariffs for 2026.
• URE – Polish Gas Company tariff for 2026.