Natural Gas Procurement Services

How a commercial natural gas price is built

A delivered gas price is four numbers stacked, and buyers who negotiate only the first are negotiating the part that is already efficient. The stack runs: the NYMEX Henry Hub futures price for the delivery month, a basis differential for your specific delivery point, the supplier's fee, and the utility's transportation and distribution charges. NYMEX is a deep national market and there is very little edge to be had in it. Basis is local, driven by pipeline capacity into your region, and it is where buyers get hurt.

The failure mode is specific and common: a contract fixes the NYMEX component, the buyer believes they have fixed their gas price, and then a cold January widens regional basis enough that delivered cost rises while national prices fall. New England is the standard example — pipeline constraint into Massachusetts, Connecticut, Rhode Island, New Hampshire and Maine makes winter basis the single largest variable in the regional energy market — but zonal basis matters in New York too, and it is not zero anywhere. Fixing basis alongside NYMEX costs a premium, and it is usually the correct premium to pay.

Transportation, storage and the operational terms

Firm versus interruptible transportation is an operational decision dressed as a pricing one. Interruptible capacity is cheaper and is curtailed when the pipeline is constrained, which is to say on the coldest days of the year. Dual-fuel facilities frequently take it deliberately and switch; single-fuel facilities that took it for the discount have accepted a production risk that never appears in the rate comparison.

Storage and injection rights let a buyer purchase in shoulder months and withdraw in winter, which is the most durable structural hedge available in gas and is underused by mid-size commercial buyers. Balancing and nomination terms govern the difference between gas scheduled and gas burned, settled as an imbalance and sometimes at penalty rates. For facilities with volatile daily load — a food processing plant running variable shifts, a hotel with seasonal occupancy — balancing provisions can matter more than a tenth of a dollar per therm on the commodity.

Who buys gas as a first-order position

For some facilities gas is the larger of the two energy bills, and the procurement strategy should be built around it rather than treated as an appendix to power. Chemical processing and plastics and polymers use gas as process heat and feedstock, so gas price is directly a cost-of-goods input. Steel and metals operations run furnaces and reheat lines that dominate site consumption. Food and beverage plants use it for sanitation, drying and cooking loads with strong seasonal shape. Hospitals, universities and multifamily buildings run heating loads that make winter basis exposure a budget question rather than a technical one, and agricultural operations concentrate gas use into grain drying windows measured in weeks.

Gas and power are one position, whether or not you treat them that way

Natural gas sets the marginal price of electricity in most U.S. markets most hours. A facility that fixes its gas and floats its power — or the reverse — is holding correlated exposure on one side and not the other, and in almost every case that asymmetry was not a decision anyone made. It is the byproduct of two contracts renewing on different dates and being handled by different people.

Buying both from a single supplier is optional and frequently not optimal; planning them as one position is neither. That planning is energy strategy and risk management work, informed by forward curve and basis analysis, and it runs alongside commercial electricity procurement rather than after it. Bill auditing matters on the gas side too, where therm conversion factors, pressure correction and transportation classification produce their own recurring error categories, and budget forecasting is where the combined position becomes a number finance can commit to. Coverage by territory is on the markets page.