![]() However, EPA does have authority to regulate hydraulic fracturing hydraulic fracturingThe process of using high pressure to pump sand along with water and other fluids into subsurface rock formations in order to improve flow of oil and gas into a wellbore. The UIC program does not regulate wells that are solely used for production. In a typical configuration, a single injection well is surrounded by multiple production wells that bring oil and gas to the surface. Oil and gas is then available for recovery. The injected fluids thin (decrease the viscosity) or displace small amounts of extractable oil and gas. Enhanced recovery wellsįluids consisting of brine, freshwater, steam, polymers, or carbon dioxide are injected into oil-bearing formations to recover residual oil and in limited applications, natural gas. Wastewater from hydraulic fracturing activities can also be injected into Class II wells.Ĭlass II disposal wells make up about 20 percent of the total number of Class II wells. Brines are separated from hydrocarbons at the surface and reinjected into the same or similar underground formations for disposal. Approximately 180,000 Class II wells are in operation in the United States.Ĭlass II wells fall into one of three categories.ĭuring oil and gas extraction, brines are also brought to the surface. The number of Class II wells varies from year to year based on fluctuations in oil and gas demand and production. It is estimated that over 2 billion gallons of fluids are injected in the United States every day. Most oil and gas injection wells are in Texas, California, Oklahoma, and Kansas. ![]() Class II fluids are primarily brines (salt water) that are brought to the surface while producing oil and gas. Class II direct implementation permitting, transparency, and efficiencyĬlass II wells are used only to inject fluids associated with oil and natural gas production.March 2020 Supplement: Base production accounts for a material share of total U.S. August 2020 Supplement: Rig counts fall but new-well production per rig rise as new-well production persists. September 2020 Supplement: With low rig counts, the inventory of drilled but uncompleted (DUC) wells provides short-term reserve for completions of new wells. January 2021 Supplement: Base production in North Dakota has fully recovered after a significant reduction. ![]() ![]() September 2021 Supplement: Gas-to-oil ratios in U.S. The DPR methodology involves applying smoothing techniques to most of the data series because of inherent noise in the data. This effect has been observed during winter weather freeze-offs, extreme flooding events, and the 2020 global oil demand contraction. The DPR metric legacy oil/natural gas production change can become unstable during periods of rapid decreases or increases in the volume of well production curtailments or shut-ins. The metric does not represent new-well oil/natural gas production per newly completed well. The metric uses a fixed ratio of estimated total production from new wells divided by the region's monthly rig count, lagged by two months. The Drilling Productivity Report (DPR) rig productivity metric new-well oil/natural gas production per rig can become unstable during periods of rapid decreases or increases in the number of active rigs and well completions.
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