Captive power generation has stopped being an optional capital expense for Russian industrial sites. Wholesale electricity prices in the first price zone of the wholesale market (ОРЭМ) have moved above 7 RUB/kWh, grid connection costs and lead times keep rising under Government Decree №861, and many enterprises hold valuable but underused energy resources — associated petroleum gas, exhaust steam, low-grade waste heat. A correctly sized turbo-generator monetises these resources at an LCOE that is often 40–70% lower than the grid tariff.

The decision tree at a glance

Selecting a turbo-generator is a sequence of dependent choices: technology of the prime mover (steam, gas, ORC, waste-heat), thermodynamic scheme (condensing, back-pressure, controlled-extraction), generator type and excitation, electrical voltage and integration with the plant grid. Each step narrows the equipment options dramatically. The economic case is then captured in four numbers — CAPEX, OPEX, TCO and LCOE — calculated for a realistic load duration curve, not the peak.

Turbo-generator unit structure
Fig. 1. The turbo-generator unit (TGU) typically includes the prime mover, coupling, generator, excitation system and five auxiliary subsystems: condenser, oil system, ICS, MV switchgear and circulating water.

Sizing: the load duration curve, not the peak

The most expensive sizing mistake is choosing the rated power equal to the plant’s peak demand. With a typical industrial load profile, peak is 1.8–2.5× the average; sized for peak, the turbo-generator runs at a 30–40% capacity factor, raising the levelised cost by 12–18%. The right answer is to size the unit for the base part of the load duration curve (around 70–75% of average demand) and import peaks from the grid, where peaking capacity is paid for by the system operator, not by you.

Drive type by problem

Steam turbines remain the most universal solution for Russian industry, especially for cogeneration. Gas turbines excel where natural gas supply is reliable and fast start-up matters. ORC units turn low-grade heat (80–150 °C) into electricity. Waste-heat recovery sets — usually steam — produce the cheapest electricity (LCOE 1.5–2.5 RUB/kWh) and pay back in 1.5–3 years.

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Cogeneration changes the economics

If the plant has a stable steam load year-round, a back-pressure or extraction turbine almost always beats a condensing one. Because the steam has to be throttled down to process pressure anyway, the turbine extracts that pressure drop as electricity essentially “for free”. Total fuel utilisation rises from 32–38% (condensing) to 80–88% (cogeneration), and the LCOE on natural gas can drop to 2–3 RUB/kWh.

Capital cost is dominated by the machine, not the building

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For a typical 8–12 MW industrial project the turbo-generator and its auxiliaries account for ~48% of CAPEX, civil works ~18%, grid connection ~12%, ICS ~7%, design documentation 6%, commissioning 4%, contingency 5%. Forgetting the grid connection line — which can easily reach 200–500 million RUB for 6–15 MW — is the second most common budgeting mistake.

Regulatory cliff at 25 MW

Paragraph 31 of the Wholesale Market Rules under Government Decree No. 1172 addresses generating facilities connected to the Unified Energy System with installed capacity equal to or greater than 25 MW and provides for exceptions. Assess the facility boundary, grid connection and the requirements for wholesale-market status or confirmation of an applicable exception. Installing two 15 MW units instead of one 30 MW unit does not by itself guarantee retail-market eligibility. Surplus sales and reserve supply also require an appropriate contractual and metering arrangement.

Implementation roadmap

A well-managed project from kickoff to acceptance takes 12–18 months: 0–3 months for audit and feasibility, 3–6 months for permits and grid connection, 6–9 months for design (project and working documentation), 9–14 months for manufacturing in parallel with civil works, 14–18 months for installation and commissioning. Cutting corners on any of these stages typically backfires within the first 2–3 years of operation.

RFP checklist

A useful tender package answers eight questions: (1) operating mode and annual hours, (2) electrical load profile, (3) thermal load and steam parameters, (4) fuel type and properties, (5) grid connection conditions, (6) site conditions and seismic class, (7) scope of supply and options, (8) target CAPEX, payback horizon, warranty and service contract terms. With all eight filled in, vendors return technically meaningful proposals in 2–3 weeks; without, you get sales brochures.

Talk to our team: RUSTRADE turbogenerators, related steam turbines, engineering services, and case studies in references.