Crude Oil fell to 59.17 USD/Bbl on December 2, 2025, down 0.25% from the previous day. Over the past month, Crude Oil's price has fallen 3.08%, and is down 15.40% compared to the same time last year, according to trading on a contract for difference (CFD) that tracks the benchmark market for this commodity. Crude Oil - values, historical data, forecasts and news - updated on December of 2025.

This dataset contains information about world's oil production for 1965-2020. Data from BP. Follow datasource.kapsarc.org for timely data to advance energy economics research.Notes:* Includes crude oil, shale oil, oil sands and NGLs (natural gas liquids - the liquid content of natural gas where this is recovered separately).** Excludes liquid fuels from other sources such as biomass and derivatives of coal and natural gas.*** Excludes Estonia, Latvia and Lithuania prior to 1985 and Slovenia prior to 1990.**** Annual changes and shares of total are calculated using million tonnes per annum figures.

This project represents the data used in “Influences of potential oil and gas development and future climate on sage-grouse declines and redistribution.” The data sets describe greater sage-grouse (Centrocercus urophasianus) population change, summarized in different boundaries within the Wyoming Landscape Conservation Initiative (WLCI; southwestern Wyoming). Population changes were based on different scenarios of oil and gas development intensities, projected climate models, and initial sage-grouse population estimates. Description of data sets pertaining to this project: Greater sage-grouse population change (percent change) in a high oil and gas development, low population estimate scenario, and with and without effects of climate change. 1. Greater sage-grouse population change (percent change) over 50-years in a high oil and gas development, low population estimate scenario, and with effects of climate change under an RCP 8.5 scenario (2050) 2. Greater sage-grouse population change (percent change) in a low oil and gas development, high population estimate scenario, and with no effects of climate change (2006-2062) 3. Greater sage-grouse population change (percent change) over 50-years in a low oil and gas development, low population estimate scenario, and with effects of climate change under an RCP 8.5 scenario (2050) 4. Greater sage-grouse population change (percent change) in a moderate oil and gas development, high population estimate scenario, and with no effects of climate change (2006-2062) 5. Greater sage-grouse population change (percent change) in a high oil and gas development, low population estimate scenario, and with no effects of climate change (2006-2062) The oil and gas development scenario were based on an energy footprint model that simulates well, pad, and road patterns for oil and gas recovery options that vary in well types (vertical and directional) and number of wells per pad and use simulation results to quantify physical and wildlife-habitat impacts. I applied the model to assess tradeoffs among 10 conventional and directional-drilling scenarios in a natural gas field in southwestern Wyoming (see Garman 2017). The effects climate change on sagebrush were developed using the National Center for Atmospheric Research (NCAR) Community Climate System Model (CCSM, version 4) climate model and representative concentration pathway 8.5 scenario (emissions continue to rise throughout the 21st century). The projected climate scenario was used to estimate the change in percent cover of sagebrush (see Homer et al. 2015). The percent changes in sage-grouse population sizes represented in these data are modeled using an individual-based population model that simulates dynamics of populations by tracking movements of individuals in dynamically changing landscapes, as well as the fates of individuals as influenced by spatially heterogeneous demography. We developed a case study to assess how spatially explicit individual based modeling could be used to evaluate future population outcomes of gradual landscape change from multiple stressors. For Greater sage-grouse in southwest Wyoming, we projected oil and gas development footprints and climate-induced vegetation changes fifty years into the future. Using a time-series of planned oil and gas development and predicted climate-induced changes in vegetation, we re-calculated habitat selection maps to dynamically modify future habitat quantity, quality, and configuration. We simulated long-term sage-grouse responses to habitat change by allowing individuals to adjust to shifts in habitat availability and quality. The use of spatially explicit individual-based modeling offered an important means of evaluating delayed indirect impacts of landscape change on wildlife population outcomes. This process and the outcomes on sage-grouse population changes are reflected in this data set.

This dataset contains information about world's oil proved reserves for 1980-2020.Explore a treasure trove of data spanning four decades, detailing the world's oil proved reserves from 1980 to 2020. Sourced from BP and supplemented with data from various reputable sources, this dataset offers a comprehensive view of global oil reserves, excluding specific regions and conditions as noted. Dive into the intricacies of total proved reserves of oil and the reserves-to-production (R/P) ratio, which sheds light on the sustainability of oil production in different years. Whether you're an energy economist, researcher, or data enthusiast, this dataset provides a valuable resource for advancing your understanding of the world's oil reserves.

^ Less than 0.05. w Less than 0.05%.

Excludes Estonia, Latvia and Lithuania prior to 1996 and Slovenia prior to 1990.

— 'Remaining established reserves', less reserves 'under active development'.

Notes:Total proved reserves of oil - Generally taken to be those quantities that geological and engineering information indicates with reasonable certainty

can be recovered in the future from known reservoirs under existing economic and operating conditions. The data series for total proved oil does not necessarily

meet the definitions, guidelines and practices used for determining proved reserves at company level, for instance as published by the US Securities and Exchange Commission,

nor does it necessarily represent BP’s view of proved reserves by country.

Reserves-to-production (R/P) ratio - If the reserves remaining at the end of any year are divided by the production in that year, the result is the length of time that those remaining reserves would last if

production were to continue at that rate.

Source of data - The estimates in this table have been compiled using a combination of primary official sources, third-party data from the OPEC Secretariat, World Oil, Oil &

Gas Journal and an independent estimates of Russian reserves based on official data and Chinese reserves based on information in the public domain.

Canadian oil sands 'under active development' are an official estimate. Venezuelan Orinoco Belt reserves are based on the OPEC Secretariat and government announcements.

Reserves include gas condensate and natural gas liquids (NGLs) as well as crude oil.

Annual changes and shares of total are calculated using thousand million barrels figures.

How it can be used: Energy economists and analysts can leverage this dataset to conduct in-depth research into the global oil industry. By examining the changes in oil reserves over time and calculating R/P ratios, one can gain insights into the dynamics of oil production and sustainability. Policymakers can also use this data to inform energy policies and resource allocation, ensuring a more secure and sustainable energy future. Additionally, researchers can explore this dataset to uncover patterns and trends in oil reserves, contributing to a deeper understanding of global energy economics.

The Petroleum Recovery Research Center (PRRC), the only research center of its kind in New Mexico, is a scientific research organization dedicated to solving problems related to the oil and gas industry.

Crude Oil Production in Saudi Arabia increased to 10002 BBL/D/1K in October from 9966 BBL/D/1K in September of 2025. This dataset provides the latest reported value for - Saudi Arabia Crude Oil Production - plus previous releases, historical high and low, short-term forecast and long-term prediction, economic calendar, survey consensus and news.

Crude Oil Production in Trinidad And Tobago increased to 51 BBL/D/1K in July from 50 BBL/D/1K in June of 2025. This dataset provides - Trinidad And Tobago Crude Oil Production- 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.

India Petroleum: Under Recovery: Burden Sharing: Oil Marketing Companies data was reported at 180.000 INR mn in 2016. This records a decrease from the previous number of 21,840.000 INR mn for 2015. India Petroleum: Under Recovery: Burden Sharing: Oil Marketing Companies data is updated yearly, averaging 21,840.000 INR mn from Mar 2006 (Median) to 2016, with 11 observations. The data reached an all-time high of 161,250.000 INR mn in 2008 and a record low of 0.000 INR mn in 2009. India Petroleum: Under Recovery: Burden Sharing: Oil Marketing Companies data remains active status in CEIC and is reported by Ministry of Petroleum and Natural Gas. The data is categorized under India Premium Database’s Energy Sector – Table IN.RBJ006: Petroleum: Fiscal Subsidy and Under Recovery.

"Shown dramatically by the recent crisis involving petroleum and natural gas, shortages and rising prices foreshadow an end to unlimited consumption of natural resources at traditionally low prices. Alleviating these growing shortages of fossil fuels will require increased production from traditional sources and development of new sources. These new sources include tar sand, oil shale, and the in situ combustion of coal. The U.S. tar sand resource and related recovery technology has never been a target of a major research effort by the private sector, perhaps due in part to the fact that most of the known resource is on federal land. Due to this low level of activity by the petroleum industry to develop the domestic tar sand resource, the United States Department of Energy's Laramie Energy Technology Center (LETC) began in 1971 working with the tar sand resource in Utah. The initial work was with the defining, characterizing and analyzing of deposits and the determining of the most promising recovery methods for testing. Specifically the objectives were: 1. To determine the feasibility of in situ oil recovery methods applied to tar sand. 2. To establish a system for classifying tar sand deposits relative to those characteristics that would affect the design and operation of in situ recovery processes. The LETC tar sand activity has created the only multi-disciplined tar sand research staff in the United States. The LETC tar sand program technical staff members and support staff represent approximately 200 man years of tar sand research experience in resource characterization, resource recovery, product treatment, reservoir access, environmental mitigation, and control technology and compliance. The LETC assembled and managed tar sand data base is the only significant compilation of tar sand resource and technology data in the public sector. A program of informal data and information exchange has been developed and is maintained by the LETC technical program management staff between the LETC and all interested private and governmental concerns. The purpose of this report is to document all of the LETC tar sand activity on tar sand deposits in the Uinta Basin in Utah."

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 dataset is a market activity representing the consumption market of the region. The dataset includes transport, freight from the factory gate to the consumer end, and transport services are calculated based on the transport situation of the product in the region. This dataset represents the bill of materials from cradle to gate for the product. The dataset encompasses multi-technology including waterflooding and gas injection. In China, the technology distribution for petroleum production is 80% waterflooding and 20% gas injection, and thus this dataset can represent the average production mix of China. Waterflooding technology: As an essential method to increase oilfield recovery rates, waterflooding involves injecting water or other fluids into the reservoir to increase formation pressure and push petroleum towards the wellhead. Gas injection technology: a gas injection process for reservoirs to enhance oil recovery. Through a series of injection wells, the working agent (natural gas or air) is injected into the reservoir, thereby driving the residual petroleum into the surrounding production wells. Low-permeability oil fields refer to those with low permeability, low abundance, and low single-well production capacity in the oil strata reservoir. The net heating value of petroleum is 43.4MJ/kg, and the average heating value of natural gas is 36MJ/Sm3.

The oil and gas producing regions of Alaska have nearly 45 billion barrels of oil which will be left in the ground, or ?stranded?, following the use of today's oil recovery practices. A major portion of this ?stranded oil? is in reservoirs technically and economically amenable to enhanced oil recovery (EOR) using carbon dioxide (CO2) injection. This report evaluates the future oil recovery potential in the large oil fields of the North Slope and Cook Inlet regions of Alaska and the barriers that stand in the way of this potential. The report then discusses how a concerted set of ?basin-oriented strategies? could help Alaska's oil production industry overcome these barriers.

This dataset represents the cradle-to-gate inventory of a product. The dataset includes multi-technology involving waterflooding and gas injection, with waterflooding accounting for 80% and gas injection 20% in petroleum production technology in China. Therefore, this dataset can represent the average production mix in China. Waterflooding technology: As an important means to increase oilfield recovery, waterflooding increases formation pressure and pushes petroleum towards the wellhead by injecting water or other fluids into the oil layer. Gas Injection technology: A process of Enhanced Oil Recovery (EOR) that improves petroleum recovery by injecting gas into the reservoir. A series of injection wells are used to inject working fluids (natural gas or air) into the reservoir to drive the residual petroleum into the surrounding production wells. Low-permeability oil fields refer to those with low permeability, low abundance, and low single-well production capacity in the oil stratum reservoir. The net calorific value of petroleum is 43.4 MJ/kg, and the average calorific value of natural gas is 36 MJ/Sm3.

This dataset provides comprehensive and up-to-date information on futures related to oil, gas, and other fuels. Futures are financial contracts obligating the buyer to purchase and the seller to sell a specified amount of a particular fuel at a predetermined price and future date.

Use Cases: 1. Trend Analysis: Scrutinize patterns and price fluctuations to anticipate future market directions in the energy sector. 2. Academic Research: Delve into the historical behavior of oil and gas prices and understand the influence of global events on these commodities. 3. Trading Strategies: Develop and test trading tactics based on the dynamics of oil, gas, and other fuel futures. 4. Risk Management: Utilize the dataset for hedging and risk management for corporations involved in the extraction, refining, or trading of fuels.

Dataset Image Source: Photo by Pixabay: https://www.pexels.com/photo/industrial-machine-during-golden-hour-162568/

Column Descriptions: 1. Date: The date when the data was documented. Format: YYYY-MM-DD. 2. Open: Market's opening price for the day. 3. High: Peak price during the trading window. 4. Low: Lowest traded price during the day. 5. Close: Price at which the market closed. 6. Volume: Number of contracts exchanged during the trading period. 7. Ticker: The unique market quotation symbol for the future. 8. Commodity: Specifies the type of fuel the future contract pertains to (e.g., crude oil, natural gas).

Crude Oil Production in Pakistan decreased to 64 BBL/D/1K in July from 67 BBL/D/1K in June of 2025. This dataset provides - Pakistan Crude Oil Production - actual values, historical data, forecast, chart, statistics, economic calendar and news.

Supply and disposition characteristics such as production (fuels include heavy crude, synthetic crude, etc.), input to refineries, exports and others. The data are available at the national and provincial levels. Not all combinations necessarily have data for all years.

This dataset represents the cradle-to-gate inventory of the product. The dataset includes multi-technology featuring both waterflooding and gas injection. Natural gas production technology in China is characterized by 80% waterflooding and 20% gas injection, thus this dataset can be representative of the average production mix in China. Waterflooding technology: A critical technique to enhance oil recovery, waterflooding is conducted by injecting water or other fluids into the reservoir to increase formation pressure and push petroleum towards the wellhead. Gas injection technology: A process of Enhanced Oil Recovery (EOR) which involves injecting gas into the reservoir to improve petroleum recovery. A series of injection wells are used to inject the working fluid (natural gas or air) into the reservoir to displace the residual petroleum into the surrounding production wells. Low-permeability oil fields refer to those with low permeability, low abundance, and low single-well capacity in the oil layer reservoir. The net heating value of petroleum is 43.4 MJ/kg, and the average calorific value of natural gas is 36 MJ/Sm3.

Net-Income Time Series for Core Laboratories NV. Core Laboratories Inc. provides reservoir description and production enhancement services and products to the oil and gas industry in the United States, and internationally. It operates through Reservoir Description and Production Enhancement segments. The Reservoir Description segment includes the characterization of petroleum reservoir rock and reservoir fluid samples to enhance production and improve recovery of crude oil and gas from its clients' reservoirs. It offers laboratory-based analytical and field services to characterize properties of crude oil and oil delivered products; and proprietary and joint industry studies, as well as services that support carbon capture, utilization and storage, geothermal projects, and the evaluation and appraisal of mining activities. The Production Enhancement segment provides services and products relating to reservoir well completions, perforations, stimulations, production, and well abandonment. It offers integrated diagnostic services to evaluate and monitor the effectiveness of well completions and to develop solutions to improve the effectiveness of enhanced oil recovery projects. The company markets and sells its products through a combination of sales representatives, technical seminars, trade shows, and print advertising, as well as through distributors. Core Laboratories Inc. was founded in 1936 and is based in Houston, Texas.

This quantification protocol is written for the oil and gas industry where CO2 is injected into an enhanced oil recovery scheme and emissions offset project. The opportunity for generating emission offsets arises from the direct and indirect reduction in greenhouse gases resulting from the capture, transportation and injection and ultimate sequestration of CO2.