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Prices are in nominal dollars.
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| Imports and Exports |
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EIA reduced the reported volume of gas imported by pipeline from Canada by the amount of natural gas liquids removed from the saturated natural gas carried by Alliance Pipeline. Alliance moves saturated natural gas from the border to a processing plant in Illinois. After the adjustment, volumes of imported natural gas on this pipeline are on the same physical basis as other reported volumes of pipeline imports.
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Prices for LNG imports are reported as “landed,” received at the
terminal, or “tailgate,” after regasification at the terminal. Generally
the reporting of LNG import prices varies by point of entry, and the
average prices are calculated from a combination of both types of prices.
The price of LNG exports to Japan is the “landed” price, defined as received
at the terminal in Japan.
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Annual and monthly data are published from the Office of Fossil Energy,
U.S. Department of Energy, Natural Gas Imports and Exports.
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Totals may not equal sum of components due to independent rounding.
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LNG prices are a volume-weighted average of the prices reported by cargo. See the LNG Monthly from the Office of Fossil Energy, U.S. Department of Energy, for more information on what is included in the individual LNG prices. Beginning in 2019, LNG export prices applying to fewer than three cargos are withheld in accordance with a policy change with the Office of Fossil Energy.
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| Other Prices |
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Average Wellhead Value, Annual Data: Form EIA-895A, "Annual Quantity and Value of Natural Gas Report,"
requests state agencies to report the quantity and value of marketed production. When
complete data are unavailable, the form instructs the state agency to report the available
value and the quantity of marketed production associated with this value. A number of states
reported volumes of production and associated values for other than marketed production.
In addition, information for several states which were unable to provide data was obtained
from Form EIA-176. It should be noted that Form EIA-176
reports a fraction of state production. The imputed value of marketed production in each
state is calculated by dividing the state's reported value by its associated production.
This unit price is then applied to the quantity of the state's marketed production to derive
the imputed value of marketed production.
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Average Wellhead Value, Preliminary Monthly Data: Preliminary values for the monthly U.S. natural gas wellhead price are estimated from the
New York Mercantile Exchange (NYMEX) futures closing price for near-month delivery at the
Henry Hub, and prevailing cash market prices (spot prices) at 5 major trading hubs:
Henry Hub, LA; Carthage, TX; Katy, TX; Waha, TX; and Blanco, NM. The NYMEX price is
reported in the trade publication, Gas Daily (published by Financial Times Energy).
The spot prices are published in another trade publication,
Natural Gas Week (Energy Intelligence Group), and they reflect the spot
delivered-to-pipeline, volume-weighted average prices for natural gas bought and sold at
the specified trading hubs. Prices include processing, gathering, and transportation fees
to the hubs. The estimated wellhead prices are derived with a statistical procedure based
on analysis of monthly time series data for the period 1995 through the present. A
statistical procedure was adopted beginning with publication of the February 1999 issue
of the Natural Gas Monthly. The preliminary estimates are replaced when annual survey
data become available, usually about 10 months after the end of the report year.
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Average Wellhead Value, Final Monthly Data: The Form EIA-895A requests state agencies to report monthly values of marketed production.
Preliminary monthly gas price data are replaced by these final monthly data. Because of data quality concerns, both monthly and annual wellhead prices were discontinued for January 2013 forward.
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City gate prices are calculated from reports to the Form EIA-857 and represent the
total cost paid by gas distribution companies for gas received at the point where
the gas is physically transferred from a pipeline company or transmission system.
This price is intended to reflect all charges for the acquisition, storage, and
transportation of gas as well as other charges associated with the LDC's obtaining
the gas for sale to consumers.
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Published residential, commercial, and industrial prices are
considered to be total prices paid by end-users per thousand cubic feet of natural
gas in the respective sectors, inclusive of all tax, delivery, commodity, demand and
other charges.
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Volumes of natural gas reported for the commercial and industrial sectors include data
for both sales and deliveries for the account of others.
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The percentage of total volume delivered represents sales to the residential, commercial and industrial
sectors. This information may be helpful in evaluating residential, commercial and industrial price data which are based on sales data only.
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Beginning in 1987, prices for deliveries to consumers are calculated using only onsystem sales
data. Due to large amounts of missing data for values of lease and plant fuel since 1987, prices
are not estimated. In previous years, imputations were made for missing data and a price was
calculated using reported and imputed data to derive a total value for gas consumed. Since
total consumption value estimates were not made since 1987, no lease and plant fuel value
estimate was made.
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Beginning in 1996, consumption of natural gas for agricultural use was classified as industrial
use. In 1995 and earlier years, agricultural use was classified as commercial use.
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Average Price of Deliveries to Consumers: Price data are representative of prices for gas sold and delivered to residential,
commercial, and industrial consumers. These prices do not reflect average prices of
natural gas transported to consumers for the account of third parties or "spot-market"
prices.
Coverage for prices varies by consumer sector. All average prices , except
electric power, are computed by dividing the reported revenue by its associated
sales volume. Preliminary monthly prices for deliveries of natural gas to
residential commercial and industrial consumers are calculated from reports to
Form EIA-857, "Monthly Report of Natural Gas Purchases and Deliveries to Consumers."
Final monthly data are calculated by allocating annual consumption data from the
Form EIA-176, to each month in proportion to monthly volumes reported in Form EIA-857.
In the States of Georgia, Maryland, New York, Ohio, Pennsylvania and Virginia, the
residential and commercial sector prices, are collected on the Form EIA-910,
"Monthly Natural Gas Marketer Survey," and include data on prices of gas sold to
customers in those sectors by energy marketers. In the District of Columbia,
Florida and Michigan, the commercial sector prices are also collected on the
Form EIA-910. Additional states (Illinois, Massachusetts, New Jersey and West
Virginia) may be added in the future as data quality becomes acceptable.
In these States, prices in the residential and/or commercial sectors are calculated
by combining the data from the Form EIA-910 with the EIA-857 (for preliminary
monthly prices) and with the Form EIA-176 for final monthly prices. Beginning in January 2005,
the EIA-910 added the States of Florida, Illinois, Massachusetts (which was dropped from the
survey in 2008), Michigan, New Jersey, Virginia, West Virginia, and the District of Columbia.
In 2011, the EIA-910 reduced the number of States for which it is used to collect data to
Georgia, New York and Ohio only.
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The electric power sector comprises electricity-only and
combined-heat-and-power plants within the NAICS 22 category whose primary business
is to sell electricity, or electricity and heat, to the public.
Through 2001, data are for regulated electric utilities only; beginning in 2002,
data also include nonregulated members of the electric power sector. The Electric Power Annual publication is typically released after the Natural Gas Annual Publication, and as a result, the most recent complete year shown in the Natural Gas Annual publication reflects preliminary volumes and prices in the electric sector. These preliminary figures are not finalized until the release of the following Natural Gas Annual. With the unbundling of services in the natural gas industry, pipeline and local
distribution companies provide transportation service for their end-user customers.
Those volumes are described as deliveries of gas for the account of others. When
companies that deliver gas are the sellers of that gas, they are able to report the
associated revenue to the EIA. Those volumes are described as onsystem sales. When the
firm that physically delivers gas to the end user acts as a transportation agent, it
does not know the sales price of the gas. Respondents, therefore, do not report a
revenue amount associated with deliveries for the account of others in their submissions
of the Form EIA-176.
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Standard Error for Natural Gas Deliveries and Price to Consumers by State.
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Statistical Considerations (Sample Design, Estimation Procedures, Final Revisions, Reliability of Monthly Data).
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Beginning in 2009 , Pipeline and distribution use volumes include line loss, defined as known volumes of natural gas resulting from leaks, damage, accidents, migration, and/or blowdowns. They also include fuel used in liquefaction and regasification.
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Definitions