API Crude Oil Stock Change in the United States increased to 2.78 BBL/1Million in October 3 from -3.67 BBL/1Million in the previous week. This dataset provides - United States API Crude Oil Stock Change- actual values, historical data, forecast, chart, statistics, economic calendar and news.

The API Crude Oil Stock Change is a weekly report released by the American Petroleum Institute that measures the change in the number of barrels of crude oil held in inventory by commercial firms in the U.S. This data is significant as it provides insights into supply and demand dynamics in the oil market, influencing oil prices and, consequently, inflation and economic growth.

API Gasoline Stocks in the United States increased to 1.90 BBL/1Million in July 11 from -2.20 BBL/1Million in the previous week. This dataset provides - United States Api Gasoline Stocks- actual values, historical data, forecast, chart, statistics, economic calendar and news.

API Crude Runs in the United States increased to 0.09 BBL/1Million in April 5 from -0.01 BBL/1Million in the previous week. This dataset provides - United States API Refinery Crude Runs- actual values, historical data, forecast, chart, statistics, economic calendar and news.

Stocks of crude oil in the United States increased by 1.79million barrels in the week ending September 26 of 2025. This dataset provides the latest reported value for - United States Crude Oil Stocks Change - plus previous releases, historical high and low, short-term forecast and long-term prediction, economic calendar, survey consensus and news.

This dataset provides values for API CRUDE OIL STOCK CHANGE reported in several countries. The data includes current values, previous releases, historical highs and record lows, release frequency, reported unit and currency.

API Distillate Stocks in the United States increased to 0.80 BBL/1Million in July 11 from -0.80 BBL/1Million in the previous week. This dataset provides - United States API Distillate Stocks Change- actual values, historical data, forecast, chart, statistics, economic calendar and news.

The Crude Oil Analysis (COA) database contains the digital data compilation of 9,076 crude oil analyses from samples collected from 1920 through 1983 from the United States and around the world and analyzed by the United States Bureau of Mines (National Institute for Petroleum and Energy Research, 1995). Two laboratories (Bartlesville, Oklahoma, and Laramie, Wyoming) performed routine crude oil analyses by a standardized method, and the data were originally reported in more than 50 reports by the Bureau of Mines. Analyses include specific gravity, API gravity, pour point, viscosity, sulfur content, nitrogen content, and color of the crude oil, as well as the bulk properties of the distillation cuts. The data were digitized in the late 1970s and a database retrieval system was implemented in 1980 and made available to the public. The Department of Energy (DOE) updated this system in 1995-96 with public access through a dial-up bulletin board system. The database was operated by the National Institute for Petroleum and Energy Research (NIPER) in Bartlesville, Oklahoma. A stand-alone version of the database (COADB) was available in 1995 in the form of a series of tables in Foxpro (.dbf) format. In 1998, an updated version of COADB was available on the NIPER website that included a Microsoft Access 97 version of the database called "coadb.mdb". The file contains more tables than the original 1995 version but we believe the number of oil samples and the amount of raw data are the same. The additional tables contain text translations for codes used in other tables regarding color, county, laboratory, formation, geologic age, lithology, and state name. Sample location information is generally inadequate to identify the specific well in most cases. The sample location information lacks lease name and in many cases well number and section-township-range. In rare cases, the latitude and longitude are given. A 2002 version was provided by the National Energy Technology Laboratory.

This dataset contains World IEA Oil Market Report 2001-2021. International Energy Agency Supply, Naphtha, Kerosene, Gasoline, Diesel, Demand, Export API data for more datasets to advance energy economics research

API Cushing Number in the United States remained unchanged at 0.10 BBL/1Million in July 11 from 0.10 BBL/1Million in the previous week. This dataset provides - United States Api Cushing Number- actual values, historical data, forecast, chart, statistics, economic calendar and news.

This digital dataset contains historical geochemical and other information for 200 samples of produced water from 182 sites in 25 oil fields in Los Angeles and Orange Counties, southern California. Produced water is a term used in the oil industry to describe water that is produced as a byproduct along with the oil and gas. The locations from which these historical samples have been collected include 152 wells. Well depth and (or) perforation depths are available for 114 of these wells. Sample depths are available for two additional wells in lieu of well or perforation depths. Additional sample sites include four storage tanks, and two unidentifiable sample sources. One of the storage tank samples (Dataset ID 57) is associated with a single identifiable well. Historical samples from other storage tanks and unidentifiable sample sources may also represent pre- or post-treated composite samples of produced water from single or multiple wells. Historical sample descriptions provide further insight about the site type associated with some of the samples. Twenty-four sites, including 21 wells, are classified as "injectate" based on the sample description combined with the designated well use at the time of sample collection (WD, water disposal or WF, water flood). Historical samples associated with these sites may represent water that originated from sources other than the wells from which they were collected. For example, samples collected from two wells (Dataset IDs 86 and 98) include as part of their description “blended and treated produced water from across the field”. Historical samples described as formation water (45 samples), including 38 wells with a well type designation of OG (oil/gas), are probably produced water, representing a mixture of formation water and water injected for enhanced recovery. A possible exception may be samples collected from OG wells prior to the onset of production. Historical samples from four wells, including three with a sample description of "formation water", were from wells identified as water source wells which access groundwater for use in the production of oil. The numerical water chemistry data were compiled by the U.S. Geological Survey (USGS) from scanned laboratory analysis reports available from the California Geologic Energy Management Division (CalGEM). Sample site characteristics, such as well construction details, were attributed using a combination of information provided with the scanned laboratory analysis reports and well history files from CalGEM Well Finder. The compiled data are divided into two separate data files described as follows: 1) a summary data file identifying each site by name, the site location, basic construction information, and American petroleum Institute (API) number (for wells), the number of chemistry samples, period of record, sample description, and the geologic formation associated with the origin of the sampled water, or intended destination (formation into which water was to intended to be injected for samples labeled as injectate) of the sample; and 2) a data file of geochemistry analyses for selected water-quality indicators, major and minor ions, nutrients, and trace elements, parameter code and (or) method, reporting level, reporting level type, and supplemental notes. A data dictionary was created to describe the geochemistry data file and is provided with this data release.

This digital dataset contains historical geochemical and other information for 45 samples of produced water from 38 sites in the Placerita and Newhall Oil Fields in Los Angeles County, southern California. Produced water is a term used in the oil industry to describe water that is produced from oil wells as a byproduct along with the oil and gas. The locations from which these historical samples have been collected include 17 wells, 6 storage tanks, and 15 unidentifiable sample sources. Well depth, perforation depths, and (or) depths referred to on geochemistry reports as interval of zone produced, are available for all 17 wells. Designated well use and sample descriptions provide further insight about what the samples represent. The well use designation for 13 of the wells is OG (oil/gas). The samples (16) associated with these wells likely represent produced water based on well designation and history, although samples from two wells (Dataset ID 23 and 32) are described as formation water. Four wells have a site type designation of "injectate" based on the current designated well use (INJ, injection; or WD, water disposal), but samples from two of the four wells (Dataset ID 31 and 35) likely represent produced or formation water as well history records indicate that sample collection predated conversion to (Dataset ID 31) or the commencement of (Dataset ID 35) use for water disposal. Limited information is available about historical samples from storage tanks and unidentifiable sample sources. These samples may represent pre- or post-treated composite samples of produced water from single or multiple wells. The numerical water chemistry data were compiled by the U.S. Geological Survey (USGS) from the following sources: scanned laboratory analysis reports available from the California Geologic Energy Management Division (CalGEM) Underground Injection Control (UIC) program, analytical reports located within well history files in CalGEM's online Well Finder (WF) database, analytical reports available as PDFs (Portable Document Format) documents located on the State Water Resources Control Board GeoTracker (SWRCB-GT) website, and data compiled by the USGS for the National Produced Water Geochemical Database (USGS PWDB). Sample site characteristics, such as well construction details, were attributed using a combination of information provided with the scanned laboratory analysis reports and well history files from CalGEM Well Finder. The compiled data are divided into two separate data files described as follows: 1) a summary data file identifying each site by name, the site location, basic construction information, and American Petroleum Institute (API) number (for wells), the number of chemistry samples, period of record, sample description, and the geologic formation associated with the origin of the sampled water, or intended destination of the sample (formation into which water was to intended to be injected for samples labeled as injectate), specific sample dates for each site, and an inventory of which constituent groups were sampled on each date; and 2) a data file of geochemistry analyses for selected water-quality indicators, major and minor ions, nutrients, trace elements, dissolved organic carbon (DOC), naturally occurring radioactive material (NORM), tracers, semi-volatile organic compounds (SVOCs), volatile organic compounds (VOCs), hydrocarbons, and organic acids. Ion (charge) balance calculations and percent error of these calculations were included for samples having a complete suite of major ion analyses. Analytical method, reporting level, reporting level type, and supplemental notes were included where available or pertinent. A data dictionary was created to describe the geochemistry data file and is provided with this data release.

This dataset evaluates the sandstone-hosted uranium potential of Alberta. An Alberta Geological Survey database of oil and gas well logs were queried to identify wells with gamma values greater than 300 API (American Petroleum Institute units). An algorithm written for this analysis queried more than 48 000 gamma ray logs from more than 22 000 wells. Of those, 11 476 readings greater than 300 API, within the upper 500 metres, were found in 6176 wells. We selected 1318 wells, verified the anomaly and determined rock types using a combination of gamma, density and resistivity logs. This dataset is associated with Alberta Geological Survey Open File Report 2009-0012.

This digital dataset contains historical geochemical and other information for 481 samples of produced water (PW) from 408 sites in the Edison, Mountain View, and Ant Hill Oil Fields in Kern County, California. Produced water is a term used in the oil industry to describe water that is produced from oil wells as a byproduct along with the oil and gas. The locations from which these historical samples have been collected include 199 wells, 67 sumps, 43 storage tanks (not associated with a specific well), and 104 unidentifiable sample sources which could not be classified because of insufficient information. The wells include 176 sites identifiable by an API (American Petroleum Institute) number and 23 sites for which an API designation could not be found, but which based on the water chemistry data source, site name, sample description, or other ancillary information have been classified as wells. Well depth, perforation depths, and (or) depths referred to on geochemistry reports as interval or zone produced, are available for 177 of these wells. Sites representing sumps and storage tanks were classified in a similar manner as wells based on the water chemistry data source, site name, sample description, or other ancillary information. Numerical water chemistry data were compiled from six data sources: 1) California Geologic Energy Management Division (CalGEM) Aquifer Exemptions (AE) Status webpage analytical reports (CalGEM, 2016), 2) CalGEM archived analytical reports (CalGEM, 2021), 3) CalGEM Underground Injection Control (UIC) program hard copies of laboratory analytical reports (CalGEM-UIC, 2017), 4) CalGEM's online Well Finder (WF) database of well history files (CalGEM-WF, 2022), 5) California State Water Resources Control Board GeoTracker (SWRCB-GT) online data portal analytical reports (SWRCB-GT, 2022), and 6) three California Department of Water Resources (CDWR) historical reports with water-chemistry data for samples from oil-producing zones of wells (characterized as "formation" water) and wastewater disposal sumps (CDWR/CVRWQCB-E, 1953; CDWR/CVRWQCB-M, 1956; and CDWR/CVRWQCB-A, 1957). Sample site characteristics, such as well construction details, were attributed using a combination of information provided with the laboratory analysis reports and well history files from CalGEM-WF (2022). The compiled data are divided into two separate data files described as follows: 1) a summary data file (EMA_PW_Summary_Data.xlsx) identifying each site by name, the site _location, basic construction information, and American Petroleum Institute (API) number (for wells), the number of chemistry samples, period of record, sample description, and the geologic formation associated with the origin of the sampled water, or intended destination of the sample (formation into which water was to intended to be injected for samples associated with Site Type labeled as water disposal well), specific sample dates for each site, and an inventory of which constituent groups were sampled on each date; and 2) a data file of geochemistry analyses for selected constituents (EMA_PW_Geochemistry.xlsx) classified into one of the following groups: water-quality indicators, major and minor ions, nutrients, trace elements, naturally occurring radioactive material (NORM), volatile organic compounds (VOCs), and hydrocarbons. Ion (charge) balance calculations and percent error of these calculations were included for samples having a complete suite of major ion analyses. Analytical method, reporting level, reporting level type, dilution factor, and supplemental notes were included where available or pertinent. A data dictionary (EMA_PW_Data-Dictionary. xlsx) describes the geochemistry data file and is provided with this data release.

There are 487 onshore oil and gas fields in California encompassing 3,392 square miles of aggregated area. The California State Water Resources Control Board (State Water Board) initiated a Regional Monitoring Program (RMP) in July 2015, intended to determine where and to what degree groundwater quality may be at potential risk to contamination related to oil and gas development activities including well stimulation, well integrity issues, produced water ponds, and underground injection. The first step in monitoring groundwater in and near oil and gas fields is to prioritize the 487 fields using consistent statewide analysis of available data that indicate potential risk of groundwater to oil and gas development. There were limited existing data on potential groundwater risk factors available for oil and gas fields across the state. During 2014-2016, the U.S. Geological Survey (USGS) extracted and compiled data from various sources, including the California Division of Oil, Gas, and Geothermal Resources (DOGGR) and the California Department of Water Resources (DWR). During 2014-2016, the depth to top of perforated intervals and depth to base of freshwater for oil and gas production wells in California were extracted from well records maintained by the DOGGR. Well records including geophysical logs, well history, well completion reports, and correspondences were viewed on DOGGR's Well Finder website at https://maps.conservation.ca.gov/doggr/wellfinder/. This digital dataset contains 3,505 records for production wells, of which 2,964 wells have a recorded depth to top of perforated intervals and 1,494 wells have a recorded depth to base of freshwater. Wells were attributed with American Petroleum Institute (API) numbers, oil and gas field, and well location, well status and type, and nearest oil and gas field for wells that plotted outside field boundaries using the DOGGR All Wells geospatial data included in this data release. Wells were attributed with land surface elevations using the California National Elevation Dataset. Due to limited time and resources to analyze well records for the most recent well configuration, wells spatially distributed throughout the state and accounting for about 2 percent of the more than 185,000 production wells (new, active, idle, or plugged well status) were attributed with depth data.

The formidable problems caused by the presence of sulfur compounds in petroleum, aggravated by the increasing rate of high sulfur crude production, led to the formation in 1948 of API Research Project 48. This project has as it objective the identification and measurement of sulfur compounds in petroleum and the obtaining of fundamental information concerning the physical properties, thermodynamic properties and other characteristics of synthesized sulfur compounds. To accomplish these objectives, it is necessary to develop suitable experimental methods and synthetic procedures.

This report is one of a series of publications resulting from a study of the feasibility of increasing domestic heavy oil production being conducted for the U.S. Department of Energy. This report summarizes available public information on the potential of heavy oil production in Alaska. Heavy oil (10' to 20' API gravity) exists and is produced on the North Slope of Alaska; but the technical, environmental constraints and high cost of transportation to refineries on the U.S. West Coast make the economics for producing significant volumes of heavy oil unfavorable. Volumes of proprietary data and feasibility studies exist within major companies, but only limited data is available in the public domain. Alaskan North Slope crude oil is marketed under the legislative constraints of having to be sold in the U.S., thus, it has to compete in the world market with a delivery constraint. California is the recipient and refines most of Alaska's current 1.7 million barrels per day oil production. Transportation, refining, and competition in the market limit development of Alaska's heavy oil resources. A number of enhanced oil recovery technologies for production of Alaska's heavy oil have been reported in the literature including gas, CO2, in situ combustion, and steam. Thermal production of heavy oil has been attempted but requires close spacing. Several light oil reservoirs, with reserves of >50 million barrels each, have been discovered and deemed non-commercial. Constraints on producing heavy oil in Alaska indicate that without significant economic incentives, very little of the heavy oil in Alaska will be produced and even then the cost may be prohibitively expensive leaving most of Alaska's heavy oil unproduced.

This digital dataset contains historical geochemical and other information for 271 samples of produced water from 143 sites in or near the San Ardo Oil Field in Monterey County, central California. Produced water is a term used in the oil industry to describe water that is produced from oil wells as a byproduct along with the oil and gas. The locations from which these historical samples have been collected include 101 wells; three wells (DataSet_ID 118 ,125, and 130) are located outside of the administrative boundary, but closer to San Ardo (within 3 miles) than any other oil field, and therefore they were included in this dataset. Well depth, perforation depths, and (or) depths referred to on geochemistry reports as interval of zone produced, are available for 97 of these wells. Additional sample sites include 11 storage tanks, and 31 unidentifiable sample sources. Designated well use and sample descriptions provide further insight about what the samples represent. The well use designation of most of the wells (79) is OG (oil/gas) and the samples (188) associated with these wells represent produced water. Samples from two wells (Dataset ID 28 and 130) are described as formation water. One well (Dataset ID 30) was drilled as a water-source well (WS) and used to supply groundwater in support of oil production at the time it was sampled, but later converted to an injection well. Another well (Dataset ID 103) was originally drilled as an oil well, but later abandoned and converted to an irrigation well prior to sampling. Eighteen wells have a site type designation of "injectate" based on the sample description combined with the designated well use at the time of sample collection (SF, steam flood; WD, water disposal; or WF, water flood). Most of the historical samples associated with injectate sites may represent water that originated from sources other than the wells at which they were collected. However, samples from two of these wells (Dataset ID 16 and 76) likely represent produced water as they were sampled prior to the wells being used for injection. Limited information is available about historical samples from storage tanks and unidentifiable sample sources, but these may represent pre- or post-treated composite samples of produced water from single or multiple wells. The numerical water chemistry data were compiled by the U.S. Geological Survey (USGS) from scanned laboratory analysis reports available from the California Geologic Energy Management Division (CalGEM). Sample site characteristics, such as well construction details, were attributed using a combination of information provided with the scanned laboratory analysis reports and well history files from CalGEM Well Finder. The compiled data are divided into two separate data files described as follows: 1) a summary data file identifying each site by name, the site location, basic construction information, and American petroleum Institute (API) number (for wells), the number of chemistry samples, period of record, sample description, and the geologic formation associated with the origin of the sampled water, or intended destination (formation into which water was to intended to be injected for samples labeled as injectate) of the sample; and 2) a data file of geochemistry analyses for selected water-quality indicators, major and minor ions, nutrients, and trace elements, parameter code and (or) method, reporting level, reporting level type, and supplemental notes. A data dictionary was created to describe the geochemistry data file and is provided with this data release.

This digital dataset contains historical geochemical and other information for 89 samples of produced water from 84 sites in the Santa Maria Valley Oil Field in Santa Barbara County, California. Produced water is a term used in the oil industry to describe water that is produced from oil wells as a byproduct along with the oil and gas. Additionally, 3 samples from 3 sites that represent source water used in support of oil production were included in this dataset, for a total of 92 samples and 87 sites, respectively. The locations from which these historical samples have been collected include 27 wells, 2 reservoirs, 10 storage tanks, and 49 unidentifiable sample sources. Well depth, perforation depths, and (or) depths referred to on geochemistry reports as interval of zone produced, are available for 25 of the 27 wells. Designated well use and sample descriptions provide further insight about what the samples represent. The well use designation for 23 of the wells is OG (oil/gas). The 27 samples associated with these wells likely represent produced water based on well designation and history. One of the 27 samples is a composite from two wells represented by Dataset ID 46. Three wells have a site type designation of "injectate" based on the current designated well use (WD, water disposal; or WF, water flood). The samples associated with these sites are of unknown origin, but likely represent produced water from OG wells in the Santa Maria Valley Oil Field. The two reservoir samples (Dataset_ID 53 and 54) are freshwater sources that were used in support of oil production, including one reservoir (Dataset_ID 54) described as supplied by groundwater wells. Limited information is available about historical samples from storage tanks and unidentifiable sample sources. These samples may represent pre- or post-treated composite samples of produced water from single or multiple wells. The numerical water chemistry data were compiled by the U.S. Geological Survey (USGS) from the following sources: scanned laboratory analysis reports available from the California Geologic Energy Management Division (CalGEM) Underground Injection Control (UIC) program, analytical reports located within well history files in CalGEM's online Well Finder (WF) database, analytical reports available as PDFs (Portable Document Format) documents located on the State Water Resources Control Board GeoTracker (SWRCB-GT) website, and data compiled by the USGS for the National Produced Water Geochemical Database (USGS PWDB). Sample site characteristics, such as well construction details, were attributed using a combination of information provided with the scanned laboratory analysis reports and well history files from CalGEM Well Finder. The compiled data are divided into two separate data files described as follows: 1) a summary data file identifying each site by name, the site location, basic construction information, and American Petroleum Institute (API) number (for wells), the number of chemistry samples, period of record, sample description, and the geologic formation associated with the origin of the sampled water, or intended destination of the sample (formation into which water was to intended to be injected for samples labeled as injectate), specific sample dates for each site, and an inventory of which constituent groups were sampled on each date; and 2) a data file of geochemistry analyses for selected water-quality indicators, major and minor ions, nutrients, trace elements, volatile organic compounds (VOCs), hydrocarbons, and organic acids. Ion (charge) balance calculations and percent error of these calculations were included for samples having a complete suite of major ion analyses. Analytical method, reporting level, reporting level type, and supplemental notes were included where available or pertinent. A data dictionary was created to describe the geochemistry data file and is provided with this data release.

This dataset contains information about New York's natural gas and oil production for 1985-2018. Data from New York State Department of Environmental Conservation.Notes:New York requires the operator of an oil or gas well to file an Annual Well Report before March 31st each year to report on well status and production values of the previous calendar year Well status and production values remain confidential for the first six months after a reporting period The Division attempts to post that data on our site shortly after July 1 of each year The Division of Mineral Resources has been providing digital production data since 1986 Declaimer Well Names are kept as per source and whenever two API numbers has same name the Name is added with API number