How Utilities and Industrial Buyers Use Natural Gas Futures Contracts
Natural gas exposure is rarely simple. Utilities and industrial buyers use futures contracts to lock part of future gas cost while keeping physical supply, delivery timing, and cash management under control, as the CFTC explains.
The contract mechanics matter just as much as the hedge idea. The standard Henry Hub contract is physically settled and sized in 10,000 MMBtu units, according to the CME natural gas product overview.
Why Gas Buyers Hedge
The core objective is to reduce budget uncertainty, not to predict where gas prices will go. The CFTC describes hedging as a way for commercial users to limit the risk created by commodity price changes, while the EIA overview of gas price drivers shows that weather, storage, production, and competing fuels can move gas prices quickly.
That is why procurement teams often treat price protection as a separate workstream from physical contracting. One team secures molecules and logistics, while another uses financial instruments to smooth budget volatility. Futures are standardized, exchange-traded contracts, and most positions are closed by offset before delivery.
How a Long Futures Hedge Works
Buying Futures Against Future Consumption
A buyer that expects to consume gas later usually uses a long hedge, meaning it buys futures against unfilled anticipated requirements. The CFTC glossary defines hedge ratio as the ratio of futures contracts purchased or sold to the cash commodity being hedged, a calculation used to reduce basis risk.
If the physical gas price rises, the futures position can offset part of the higher invoice. If the physical price falls, the futures position loses value while the invoice gets cheaper, which is why the program is about stability rather than directional speculation.
Match Months to the Load Profile
Utilities usually hedge month by month or season by season, because gas demand and storage are seasonal. EIA notes that storage generally builds from April through October and draws down from November through March, which is why winter protection is often handled separately from shoulder season exposure.
Industrial buyers often do the same, but they map the hedge to plant run rates, maintenance outages, and fuel switching capability. The more variable the consumption profile, the more important it becomes to hedge only the exposure that is reasonably measurable. (eia.gov)
At Nedjma, our NOOR-Trading division supports this kind of structured market assessment and execution workflow.
What the Standard Henry Hub Contract Gives You
Henry Hub is the benchmark reference point behind the standard natural gas futures contract. Each Henry Hub contract represents 10,000 MMBtu of deliverable natural gas, is priced per MMBtu, and is physically settled at the Henry Hub delivery point in Louisiana.
That standardization matters because it gives procurement teams a common benchmark, a clear contract size, and a defined delivery framework. At the same time, it does not eliminate local differences in pipeline access, transport cost, or regional balance.
Key Contract Features Procurement Teams Check First
The table below shows the features buyers usually review before building a hedge program.
Feature | What it means | Why it matters for buyers |
|---|---|---|
Contract size | 10,000 MMBtu per contract. | It gives the basic unit for sizing monthly or seasonal exposure. |
Settlement | Physically settled at Henry Hub in Louisiana. | It keeps the contract tied to the benchmark cash market, even if local delivered prices differ. |
Margin | Collateral is posted when the position is opened. | Daily marking to market creates variation cash flows that treasury must plan for. |
Offset | Most positions are closed before delivery. | Useful when the goal is price protection, not physical receipt through the futures market. |
Basis risk | Local price can differ from Henry Hub. (eia.gov) | Pipeline access, production, and regional balance can change the final procurement cost. |
A simple sizing rule helps: divide monthly benchmark exposure by 10,000 MMBtu per contract, then adjust for hedge ratio and basis. A 100,000 MMBtu exposure is about 10 full-size contracts, while 250,000 MMBtu is about 25.
Margin, Mark to Market, and Treasury Planning
Futures are efficient, but they are not free of cash flow timing. The CFTC says margin is collateral, not a down payment, and that futures positions are marked to the market daily, with variation margin added or collected as prices move.
For a buyer, that means the hedge can work economically even if it creates short term treasury pressure. Good programs therefore coordinate procurement, risk, and finance before the first contract is placed.
Basis Risk and Residual Exposure
A benchmark hedge rarely matches the delivered invoice exactly. The CFTC glossary defines hedge ratio as a way to minimize basis risk, and EIA regional analysis shows that local gas prices can diverge from Henry Hub when production, pipeline capacity, or transport constraints change.
So the practical question is not just how many contracts to buy, but which month, which tenor, and which residual exposure to leave open. In many procurement programs, the hedge begins with the benchmark price, then the team layers in local basis, freight, storage, and operational flexibility.
Rolling the Hedge Forward
When exposure continues beyond the current delivery month, the position can be rolled forward. The CFTC glossary describes rolling forward as offsetting a position in one delivery month and simultaneously initiating a similar position in another month.
That is useful for utilities and plants with persistent demand, because it lets the hedge stay aligned with the physical calendar without forcing an unwanted delivery.
A Simple Procurement Workflow
Quantify monthly gas demand in MMBtu and decide what share of that exposure you want to stabilize.
Match the hedge month or strip to the load profile and expected storage cycle.
Divide benchmark exposure by 10,000 MMBtu per contract to estimate contract count.
Check margin and treasury capacity before execution.
Monitor basis and roll or offset before delivery if physical receipt is not desired.
This is a procurement framework, not a trading recipe. The purpose is to separate price management from supply execution in a disciplined way.
FAQ
How do utilities use natural gas futures contracts to hedge price risk?
Utilities usually buy futures against expected future consumption. If the cash gas price rises, the futures position can gain value and soften the higher invoice later. The CFTC describes hedging as a way for commercial users to limit price risk, and it notes that most futures positions are closed by offset before delivery. In gas, that means the utility can protect budgeted fuel cost while still buying the physical molecules through its normal supply chain.
How do industrial buyers hedge natural gas costs with futures contracts?
Industrial buyers follow the same logic, but they start from forecast plant burn rather than a utility load curve. Run rates, maintenance outages, and any fuel switching capability decide how much of that burn is measurable enough to hedge. A good program also checks whether monthly usage is stable enough to justify rolling the hedge forward.
What are Henry Hub futures and how do utilities build hedging programs with them?
Henry Hub futures are the standard benchmark natural gas contract. CME says each contract represents 10,000 MMBtu of deliverable gas and is physically settled at Henry Hub in Louisiana. Utilities often build a strip of monthly positions that mirrors their load curve, then manage the fact that storage, weather, and local transport can move the cash price away from the benchmark. That is why the hedge protects price, not the entire delivered invoice.
Why do utilities use futures contracts and swaps for gas procurement instead of fixed-price agreements?
Futures are standardized and easy to offset, which makes them efficient for exchange-based risk management. Swaps sit in a different market structure and can be useful when a procurement team needs a different commercial shape, while a fixed-price supply agreement usually bundles price, volume, and delivery into one contract. Buyers often prefer to separate those variables so they can adjust hedge tenor, manage basis, and keep the physical supply agreement independent from the pricing layer.
How many natural gas futures contracts does a utility typically buy to hedge monthly gas purchases?
There is no universal number. The count starts from monthly benchmark exposure divided by the 10,000 MMBtu contract size, then applies the hedge ratio the buyer has chosen. The result is usually adjusted for basis, operational flexibility, and treasury tolerance for variation margin.
Next Steps
If your team wants to map gas exposure, build a hedge calendar, or review procurement structure, contact us at Nedjma and return to the company home page for the broader platform context.
