Fuel is the largest operating cost of a thermal power plant, and most of it is committed months before it burns. Coal linkages and supply agreements, imported cargoes, gas contracts with take-or-pay clauses and rail logistics all have to be lined up against a generation plan that keeps changing. Buy too little and the plant runs short of stock when demand peaks; buy the wrong grade and the cost per unit of power rises even when the price per tonne looks good. Fuel procurement planning links demand forecasts, contracts, stock norms, quality and logistics into one plan. This guide covers fuel cost structure, supply agreements, stock norms, quality and grade slippage, imports and gas contracts, landed cost per kWh and how continuous planning protects margin. To see your fuel plan modeled, book a short walkthrough.
Fuel Procurement Planning for Thermal Power Plants: Protect Margin Months Before the Fuel Burns
Coal, imported fuel and gas planned against forecast generation, stock norms and quality, with landed cost per kWh compared across every source and every month.
Why Fuel Decisions Are Made Long Before Fuel Burns
Coal purchase and handling make up about 50–60% of a thermal station’s total operating cost, according to a paper published through the United States Energy Association. Most of that spending is set by decisions taken weeks or months ahead: annual contracted quantities, import cargoes, rail allocation and gas nominations. By the time fuel reaches the bunker, most of the cost is fixed.
The risks are not theoretical. In September 2026, Business Standard reported that coal stock at India’s thermal plants had fallen to about 7 days of cover, 39% of the normative requirement, with 74 of 190 plants in critical condition. In the United States, the Energy Information Administration reported coal stockpiles of 80 million tons in September 2021, the lowest since 1978, and noted that delivery constraints limit how fast plants can rebuild.
Stock shortages force plants to back down, buy expensive spot fuel or run on lower-quality coal. Over-buying ties up working capital and, for gas, can mean paying for fuel that is never burned. Both are planning failures that a forward-looking model can reduce.
A good fuel plan starts from the generation forecast and works backward. We can review your fuel plan on a call.
Coal Supply Agreements and Linkages
In India, most domestic coal for power arrives under fuel supply agreements (FSAs) and linkage policies. The key terms shape every procurement plan.
Tracking supply against ACQ every month, and recording the reasons for shortfall, is the basis for both planning and claims. A plan that knows the contract position can decide early whether to seek more rakes, buy at auction or bring forward an import cargo.
Contract tracking is usually the first module plants use. See it in a demo.
Stock Norms and Days of Cover
Stock norms set how much fuel a plant must hold. In India they vary by plant location and by month.
| Measure | Value | Source |
|---|---|---|
| Normative stock, pithead plants | 12–17 days, varying by month | Ministry of Power reply in Parliament |
| Normative stock, non-pithead plants | 20–26 days, varying by month | Same source |
| Basis of calculation | Consumption at 85% plant load factor | Same source |
| April 2022 requirement | 17 days pithead, 26 days non-pithead | Same source |
| September norm cited in 2026 | 12 days pithead, 20 days non-pithead | Business Standard |
| US measure | Days of burn on current stockpile | US EIA |
Illustrative. Forward cover, not today’s stock, is what shows whether action is needed.
The key point is that norms are measured against consumption, which changes with dispatch. A plant whose schedule rises in a heat wave can fall below norm without any change in supply. Linking the stock plan to the generation forecast shows that risk days or weeks ahead.
Forward stock projection is part of every rollout.
Coal Quality, Grade Slippage and Sampling
Coal is bought by grade, but power is made from heat. When delivered gross calorific value (GCV) falls below the billed grade, the plant pays for heat it does not receive.
CEA operating norms use GCV on an as-received basis, which includes moisture effects.
India’s 2015 third-party sampling policy has CIMFR appoint independent agencies to sample at the loading end.
Under that policy, a referee sample is kept for 30 days, a challenge must be raised within 7 days, and results are due within 18 working days.
Compare billed grade, loading-end results and plant-end analysis.
CEA norms allow 0.2% for captive transport and 0.8% otherwise.
Use reconciled data to pursue credits and adjust future orders.
Quality also affects cost per kWh through heat rate. Lower-GCV coal with more ash and moisture often lowers boiler efficiency and raises auxiliary power, so the cost penalty is larger than the GCV difference alone suggests.
Reconciling quality across rakes and sources often recovers significant value. Discuss it with our specialists.
Imported Coal and Gas Contracts
Imports and gas add flexibility but bring their own price and contract risks.
India advised 10% imported coal blending by weight in 2022 and directed a minimum of 6% through March 2024.
Port price, freight, port handling, rail and GCV together set the cost per kWh.
Imported coal properties limit how much can be blended in existing boilers.
Long-term LNG prices have often followed a slope of 11–16% of crude oil plus a constant, per WilmerHale.
Long-term contracts have often fixed take-or-pay at 95–100% of annual quantity.
Spot LNG and hub-indexed gas add flexibility at volatile prices.
For gas-fired plants, take-or-pay changes the economics of dispatch. Gas already paid for has a low marginal cost, while gas above the contract volume is priced at spot. Fuel planning must reflect that, or the plant will under-use contracted volumes and over-buy spot.
Our engineers can model your import and gas exposure month by month.
Comparing Sources on Landed Cost per kWh
The cheapest tonne is not always the cheapest unit of power. Sources should be compared on landed cost per kWh.
Illustrative. Real comparisons should include heat rate effects of ash and moisture, blending limits and logistics.
Cost per kWh also depends on how the fuel behaves in the boiler. Higher-ash coal raises ash handling and auxiliary power; high-slagging coal can limit load. A planning model that includes these effects gives a truer comparison than price per tonne or price per unit of heat alone.
Comparing your sources on cost per kWh often changes the preferred mix. Ask our team to run the comparison.
Building a Rolling Fuel Procurement Plan
A good fuel plan is rolling, refreshed as forecasts and supplies change.
Month-by-month dispatch forecast, including outages and seasonal demand.
Heat rate and fuel quality turn generation into tonnes or volumes.
Contracted, auction, import and gas volumes allocated against need.
Forward days of cover compared with norms every week.
Delivered GCV and transit losses fed back into the plan.
Orders, rakes and cargoes revised as conditions change.
The rolling plan turns fuel procurement from a series of reactions into a managed process. When a heat wave raises the dispatch forecast, the stock projection shows the gap weeks ahead, while there is still time to act.
- Orders placed when stock falls
- Sources compared on price per tonne
- Quality disputes handled case by case
- Contract shortfalls noticed late
- Take-or-pay volumes under-used
- Plan revised monthly
- Orders placed from forward cover
- Sources compared on cost per kWh
- Quality reconciled for every rake
- ACQ position tracked monthly
- Contract volumes planned into dispatch
- Plan refreshed with every forecast
See the rolling plan in a session.
Fuel Procurement Checklist
Use this checklist to strengthen fuel procurement planning.
Most plants hold this data across several systems. Bringing it together is the first step of a fuel review.
What Better Fuel Planning Is Worth
With fuel at 50–60% of operating cost, small improvements carry large value.
A 1% reduction in fuel cost for a large coal station is often worth more than many maintenance projects combined. The exact figure depends on fuel spend, which plants can estimate in minutes from their own accounts.
A review of last year’s fuel receipts and quality data shows the first opportunities. Book one with our advisors.
How iFactory Delivers Fuel Procurement Planning
Fuel need projected from the dispatch forecast.
ACQ, incentives and take-or-pay positions.
Forward days of cover against monthly norms.
Billed, loading-end and plant-end GCV compared.
Every source ranked on delivered heat and heat rate.
Heat waves, supply delays and price changes tested.
It runs on premises and connects to your ERP, fuel management and scheduling systems. Share a year of receipts and consumption and we will show your cost per kWh by source in a working session.
See Your Fuel Sources on Cost per kWh
Share receipts, quality results and consumption data. We rank every source on landed cost per kWh, project your stock cover and show where grade slippage is costing you.
Stock covers 14 days against a 20-day norm. Two rakes are delayed and the next fortnight’s schedule runs at higher load, so cover falls to 9 days without action.
A Stock Gap Seen Ten Days Early
This exchange shows how a fuel planner might use iFactory.
iFactory ships as a pre-configured NVIDIA AI server, racked and ready with the fuel procurement planning models loaded. Rack it, plug in power and Ethernet, and the AI is live on your network. Our scope covers data connections across fuel yard, receipts, laboratory and planning office, DCS, historian, CMMS, scheduling, market and ERP integration, cabling and network setup, operator and engineer training, and 24×7 remote monitoring. Plans and recommendations run in advisory mode first, reviewed by your planners and engineers before anything changes in operation.
Server installed, DCS, historian, CMMS and schedule links live, historical generation, fuel and maintenance data loaded.
Models calibrated on your own plant data, then run in advisory mode with your planners reviewing every forecast and plan.
Rollout to the agreed units and planning cycles, planner and engineer training, and 24×7 remote monitoring in place.
Software, server and integration come as one package. For pricing on your plant, contact our sales team.
Frequently Asked Questions
A paper published through the United States Energy Association puts coal purchase and handling at about 50–60% of a coal station’s total operating cost.
Normative stock ranges from 12–17 days for pithead plants and 20–26 days for non-pithead plants, calculated at 85% plant load factor and varying by month.
When delivered coal has a lower calorific value than the grade billed. India’s third-party sampling policy uses independent agencies at the loading end to address it.
Because price per tonne ignores calorific value, heat rate and handling effects. A more expensive coal with higher GCV can produce cheaper power.
A clause requiring the buyer to pay for a set share of contracted volume whether or not it is taken. Long-term LNG contracts have often set it at 95–100% of annual quantity.
A rolling fuel plan can typically be in use within a 6–12 week rollout, using your existing receipts and forecasts. Plan it with our planners.
Buy the Fuel That Makes the Cheapest Power
iFactory plans fuel from your generation forecast, compares sources on cost per kWh, tracks contracts and quality and warns of stock gaps early enough to act.
Illustrative. Cost per kWh combines price, freight, GCV, moisture and heat rate, so the cheapest tonne is not always the cheapest unit of power.
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