Natural gas rose to 3.36 USD/MMBtu on July 11, 2025, up 0.58% from the previous day. Over the past month, Natural gas's price has fallen 3.89%, but it is still 44.10% higher than a year ago, according to trading on a contract for difference (CFD) that tracks the benchmark market for this commodity. Natural gas - values, historical data, forecasts and news - updated on July of 2025.

Working gas held in storage facilities in the United States increased by 53 billion cubic feet in the week ending July 4 of 2025 . This dataset provides the latest reported value for - United States Natural Gas Stocks Change - plus previous releases, historical high and low, short-term forecast and long-term prediction, economic calendar, survey consensus and news.

This dataset contains information about world's natural gas consumption from 1965. Data from BP. Follow datasource.kapsarc.org for timely data to advance energy economics research.Notes:* Excludes natural gas converted to liquid fuels but includes derivatives of coal as well as natural gas consumed in Gas-to-Liquids transformation.^ Less than 0.05.w Less than 0.05%.n/a not available.# Excludes Estonia, Latvia and Lithuania prior to 1985 and Slovenia prior to 1990.Notes: The difference between these world consumption figures and the world production statistics is due to variations in stocks at storage facilitiesand liquefaction plants, together with unavoidable disparities in the definition, measurement or conversion of gas supply and demand data.Annual changes and shares of total are calculated using billion cubic feet per day figures.

This data is a graphic representation of natural gas pipelines. The file has not been certified by a Professional Surveyor. This data is not suitable for legal purposes. The purpose of this data is to provide a generalized statewide view of natural gas pipelines.The U.S. natural gas pipeline network is a highly integrated network that moves natural gas throughout the continental United States. The pipeline network has about 3 million miles of mainline and other pipelines that link natural gas production areas and storage facilities with consumers. In 2017, this natural gas transportation network delivered about 25 trillion cubic feet (Tcf) of natural gas to 75 million customers.About half of the existing mainline natural gas transmission network and a large portion of the local distribution network were installed in the 1950s and 1960s because consumer demand for natural gas more than doubled following World War II. The distribution network has continued to expand to provide natural gas service to new commercial facilities and housing developments.

This dataset contains Bahrain Natural Gas Production - Million Cubic Feet. Data from Bahrain Open Data Portal. Follow datasource.kapsarc.org for timely data to advance energy economics research.

The Undiscovered Oil and Gas Resources dataset shows the locations of the Assessment Units (AUs) in the U.S. Geological Survey (USGS) World Assessment of Undiscovered Oil and Gas Resources. The assessment was conducted in 2012 and evaluated 313 AUs within 171 geologic provinces (areas where oil and gas occur in commercial quantities). An AU is a mappable volume of rock with homogenous geologic properties. Each AU was assessed for undiscovered oil and gas resources using data from published literature. In each geologic province, total petroleum systems (TPS) were also defined. A TPS is the group of geologic elements needed for oil and gas formation. The Undiscovered Oil and Gas Resources dataset provides an understanding of the quantity, quality and distribution of global conventional oil and gas resources. Conventional oil and gas resources, such as crude oil and natural gas, are found in high porosity/permeability reservoirs. Unconventional oil and gas resources are found in low porosity/permeability reservoirs, such as shale and tar sands. Conventional resources are relatively easy to extract from the earth and do not require fracking. The USGS World Assessment of Undiscovered Oil and Gas Resources determined that a total of 565,298 million barrels of oil, 5,605,626 billion cubic feet of gas and 166,668 million barrels of natural gas liquids remained undiscovered as of 2011. All of these resources are conventionally extractable. However, conventional oil and gas resources are dwindling. Knowing where and how much conventional oil and gas remains undiscovered is important for understanding the world’s energy future. The Undiscovered Oil and Gas Resources dataset is a geologic basis for making decisions about energy. It can help predict future energy production trends and increase understanding of the social and environmental consequences of oil and gas resource exploitation.

This dataset contains information about world's natural gas gas production from 1970. Data from BP. Follow datasource.kapsarc.org for timely data to advance energy economics research.Notes:* Excludes gas flared or recycled. Includes natural gas produced for Gas-to-Liquids transformation.** Excludes Estonia, Latvia and Lithuania prior to 1985 and Slovenia prior to 1990.As the data above are derived from tonnes oil equivalent using average conversion factors, they do not necessarily equate with gas volumes expressed in specific national terms.Annual changes and shares of total are calculated using billion cubic feet per day figures.^ Less than 0.05.w Less than 0.05%n/a not available.

Natural Gas Processing PlantsImportant Note: This item is in mature support as of April 2025 and will be retired in August 2025.This feature layer, utilizing data from the Energy Information Administration (EIA), depicts the daily capacity (Million Cubic Feet per Day (MMcf/d)) of natural gas processing plants in the U.S. Per EIA, "Processing plants are midstream facilities that separate natural gas liquids (NGL) from natural gas. Some natural gas processing plants remove water and other contaminants from the raw natural gas stream and separate NGL streams into component products."Natural Gas Processing PlantsData currency: This cached Esri service is checked monthly for updates from its federal source (Natural Gas Processing Plants)Data modification: NoneFor more information, please visit: Natural Gas; Natural Gas ExplainedFor feedback: ArcGIScomNationalMaps@esri.comEnergy Information AdministrationPer EIA, "The U.S. Energy Information Administration (EIA) collects, analyzes, and disseminates independent and impartial energy information to promote sound policymaking, efficient markets, and public understanding of energy and its interaction with the economy and the environment."

Natural Gas Plays in the Marcellus Shale: Challenges and Potential Opportunities

The U.S. has abundant natural gas resources within the Barnett Shale, Haynesville/Bossier Shale, Antrim Shale, Fayetteville Shale, New Albany Shale, and Marcellus Shale. Technically recoverable natural gas from these shales is more than 1,744 trillion cubic feet (Tcf) (50 km3), which includes 211 Tcf of proven reserves (1). At the annual production rate of about 19.3 Tcf, there is enough natural gas to supply the U.S. for the next 90 years with some estimates extending the supply to 116 years. The total number of natural gas and condensate wells in the U.S. rose 5.7% in 2008 to a record 478,562 with some of the produced natural gas lost via flaring (2). However, available data on flaring of natural gas is incomplete and inconsistent.

The data from which these carbon-emissions estimates were derived are values of fuel consumed: in billions of cubic feet, for natural gas; in millions of barrels, for petroleum products; and in thousands of short tons, for coal. The resulting emissions estimates are expressed as teragrams of carbon. A teragram is 1012 grams, or 106 metric tons. To convert from carbon to carbon dioxide, multiply by 44/12 (=3.67). Data are available for over 30 different petroleum products, with the exact breakdown varying somewhat from year to year. These products have been treated separately here until the final step of the estimation, at which time CO2 emissions were summed and attributed to liquid petroleum products. These fuel-consumption data are available from the Energy Information Administration of the U.S. Department of Energy. They are published in the Monthly Energy Review, and are available electronically from the Energy Information Administration. For access to the data files, click this link to the CDIAC data transition website: http://cdiac.ess-dive.lbl.gov/trends/emis_mon/emis_mon_co2.html

According to a 1991 Energy Information Administration estimate, U.S. reserves of natural gas are about 165 trillion cubic feet (TCF). To meet the long-term demand for natural gas, new gas fields from these reserves will have to be developed. Gas Research Institute studies reveal that 14% (or about 19 TCF) of known reserves in the United States are subquality due to high nitrogen content. Nitrogen-contaminated natural gas has a low Btu value and must be upgraded by removing the nitrogen. In response to the problem, the Department of Energy is seeking innovative, efficient nitrogen-removal methods. Membrane processes have been considered for natural gas denitrogenation. The challenge, not yet overcome, is to develop membranes with the required nitrogen/methane separation characteristics. Our calculations show that a methane-permeable membrane with a methane/nitrogen selectivity of 4 to 6 would make denitrogenation by a membrane process viable. The objective of Phase I of this project was to show that membranes with this target selectivity can be developed, and that the economics of the process based on these membranes would be competitive. Gas permeation measurements with membranes prepared from two rubbery polymers and a superglassy polymer showed that two of these materials had the target selectivity of 4 to 6 when operated at temperatures below - 20{degrees}C. An economic analysis showed that a process based on these membranes is competitive with other technologies for small streams containing less than 10% nitrogen. Hybrid designs combining membranes with other technologies are suitable for high-flow, higher-nitrogen-content streams.

What would happen to Alaska's natural gas once it reaches the end of the proposed pipeline, 1,700 miles from Prudhoe Bay? The gas would flow into a vast network of Canadian and U.S. pipelines assembled over the past 60 years. Some key components of that network were built or expanded in the early 1980s in anticipation of Alaska gas starting to flow back then. Those components went into service without Alaska gas and helped Canada double its natural gas exports to the United States in the 1980s, then double them again in the 1990s. In all, the entire network today can move 15 billion to 20 billion cubic feet a day of natural gas, roughly three to four times the volume the Alaska pipeline would deliver to the British Columbia-Alberta border northwest of Edmonton. Of course, the network still moves billions of cubic feet of gas daily. But the volume it handles has been declining, leaving room for Alaska gas, and even if the flow is relatively flush when the Alaska pipeline is finished, the network's capacity could be expanded. No longer is there serious talk of needing a pipeline stretching all the way from Prudhoe Bay to Chicago. But why end the Alaska pipeline near the B.C.-Alberta border as opposed to somewhere else? The answer is simple: Three major North American gas pipeline systems converge there, in the heart of some of Canada's hottest natural gas plays.

Imports of Petroleum - Natural Gas in Mexico decreased to 702300 CU FT./DAY Thousand in February from 738500 CU FT./DAY Thousand in January of 2024. This dataset includes a chart with historical data for Mexico Imports of Petroleum - Natural Gas.

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A brief discussion of some gas production experiments, done to better plan for future drilling events.

From the paper: "Numerous areas in both the western and eastern United States contain large reserves of gas trapped in very low permeable reservoirs. The Mesa Verde formation in the Piceance, Green River, and Uinta Basins of the Rocky Mountain region for example, contains reserves of trillions of cubic feet of gas. The Brown Shale of Upper Devonian Age in the eastern United States also holds tremendous reserves of natural gas. The Morgantown West Virginia Energy Research Center of the U.S. Energy Research and Development Agency formerly the U.S. Bureau of Mines, as nart of a long term earth fracture systems evaluation program, has concentrated on developing methods for more efficiently producing gas from these marginal reservoirs. As a result of these studies, ERDA and Columbia Gas Transmission Corporation cooperated on a program to drill a series of wells to test the deviated well concept in the economically marginal Upper Devonian gas reservoir."

Carbon dioxide (CO2) injection data and oil/gas/water production data for the Bell Creek oil field. CO2 injection began in the Bell Creek Field in May of 2013. The data herein includes monthly values from the start of injection through December of 2016. Three Excel spreadsheets are included in the EDX submission. One spreadsheet contains monthly summary information for the oil field, while the other two spreadsheets provide the data on a well-by-well basis (one for injection, one production). The monthly summation data are provided in thousand standard cubic feet (Mscf), cubic meters, short tons, and metric tons. The well-by-well injection data and gas (CO2) production data are reported in Mcf, the water and oil production in barrels. These data were obtained from the Montana Board of Oil and Gas.

Upon the discovery of crude oil, Nigerian economy experienced an interesting leap. Agriculture suffered a setback because so much attention was moved to oil exploration and exploitation since it accounted for over 70% of the country’s foreign exchange earnings. However, oil exploitation precipitated the problem of gas flaring since Nigeria is endowed with more gas reserves than oil (Ashton-Jones, 1998). Gas flaring is the burning of natural gas that is associated with petroleum production while releasing hazardous compounds into the air. In 2015, total crude oil and condensate production was put at seven hundred and seventy-three million, four hundred and fifty-eight thousand, five hundred and ninety-two barrels, while in the gas sector, a total of two thousand, nine hundred and twenty-nine point eighty-five billion standard cubic feet (BSCF) of natural gas was produced by forty companies (Obi et al., 2021). Of the quantity produced, 2588.48BSCF (88.35%) was utilised, while 341.37BSCF (11.65%) was flared. United States energy Information Administrative International energy statistics database (2023) reported that Nigeria flared about 5.318 billion cubic meters of natural gas in 2022 making Nigeria the 9th-highest natural gas flaring country in terms of annual natural gas flaring volume. Some of the hazardous compounds that gas flaring releases into the air are alkanes, alkenes, volatile organic compounds (VOC), polycyclic aromatic hydrocarbons, naphthalene, styrene, acetylene, fluoranthene, anthracene, pyrene, xylene, ethylene, soot, greenhouse gases and carbon monoxide, (Nwokedi, 1992; Strosher, 1996; Kindzierski, 2000). Also, heavy metals are not excluded (Ite et al., 2013).I went on a tour to Ibeno, a gas faring community. As I discussed with the locals, they complained bitterly of experiencing so much hazards as a result of gas flaring. This led to the decision to embark on this journey in an attempt to scientifically validate or invalidate their claims.

Canada has significant proven reserves of crude oil (178 billion barrels), second only to those of Saudi Arabia. Canadian natural gas reserves were 58 trillion cubic feet as of year-end 2006. These resources are found in the country’s seven major sedimentary basins. The primary petroleum-producing sedimentary basin is the Western Canada Sedimentary Basin (WCSB), which extends from the Canadian Shield to the Rocky Mountains through Manitoba, Saskatchewan, Alberta and northeastern British Columbia. There are also producing basins in southern Ontario, offshore Newfoundland, and the Scotian Shelf. Potential reserves are also found in Northern Canada, where an estimated 30 per cent of Canada’s conventional oil resources are located. The map shows the major petroleum-producing fields (or pools) of conventional natural gas, crude oil and the oil sands, as well as the extensive pipeline network.

Exports of Petroleum - Natural Gas in Mexico decreased to 700 CU FT./DAY Thousand in February from 800 CU FT./DAY Thousand in January of 2024. This dataset includes a chart with historical data for Mexico Exports of Petroleum - Natural Gas.

Western gas sands research is conducted by the US Department of Energy's (DOE's) Morgantown Energy Technology Center to encourage the development of very low permeability, lenticular gas sands in the western US. This research is an integral part of DOE's Unconventional Gas Recovery Program, which is a multidisciplinary effort to develop the technology for producing natural gas from resources that have been classified as unconventional because of unique geologies and production mechanisms. The purpose of this research is to demonstrate to private industry the feasibility of economically producing natural gas from these low-permeability reservoirs. The reservoirs, which are found within a resource area that covers 311,000 square miles, contain an estimated several thousand trillion cubic feet (Tcf) of gas-in-place. The western gas resource base continues to be updated as part of the US Geological Survey (USGS) research described in this report. 15 refs., 10 figs., 3 tabs.