This dataset contains compositional data on 17 produced water samples from hydraulically fractured unconventional oil wells completed in the Middle Bakken and Three Forks Formations. The oil wells are located in five different wellfields across the Williston Basin. Specific gravity, conductivity, temperature, pH and oxidation-reduction potential for each sample was measured in the field. Ions (B, Li, Cl, Na, Br), biomarkers (Pristane /n-C17 and Phytane /n-C18), glycol ether compounds, major ions, as well as radium (Ra-228/Ra-226), boron (δ11B), oxygen (δ18O) and hydrogen (δ2H) isotopic ratios were analyzed in the lab. Well profiles are provided to increase understanding of the produced waters compositions in the context of the depth of the well, age of the well, the time since hydraulic fracturing, the amounts of water injected and produced since hydraulic fracturing, the hydraulic fracturing treatment fluid types injected.

The input form provides a record of the complete input values required for the quantitative assessment of water and proppant associated with oil and gas production for the continuous oil and gas resource in a geologically defined Assessment Unit, and the same form template is used for all such assessments. Each USGS water and proppant assessment builds from a USGS petroleum assessment that provides the geologic foundation for the water and proppant assessment. Assessment units are defined in the course of conducting the petroleum assessment.

The organic composition of produced waters (flowback and formation waters) from the Bakken Formation and the Three Forks Formation in the Williston Basin, North Dakota were examined in this study in order to aid in the remediation of surface contamination due to spills during transport and help develop treatment methods for recycling. Twelve produced water samples were collected from wells in the Bakken and Three Forks Formations at the well head and analyzed for non-purgable dissolved organic carbon (NPDOC), acetate, and extractable hydrocarbons. NPDOC and acetate concentrations from sampled wells from ranged from 33-190 milligrams per liter (mg/L) and 16-40 mg/L, respectively. Concentrations of individual extractable hydrocarbon compounds ranged from less than 1 to greater than 450 micrograms per liter (µg/L), and included polycyclic aromatic hydrocarbons (PAHs), phenolic compounds, glycol ethers, and cyclic ketones.

Water used for hydraulic fracturing treatments in and near the Williston Basin during 2000-2015, was estimated using data reported in IHS Markit (TM) (2016). Hydraulic fracturing treatment data from IHS Markit (TM) (2016) may include volumes in a variety of measurement units, and they may include multiple treatments per well. All listed treatments within the study area were converted to gallons and summed on a per-well basis, discounting any treatments for which the specified measurement units were unclear (for example, “sacks”, or “feet”), which were minor. Of 3,734,380 treatments listed within the study area during the timeframe of interest, 0.7% (26,373 records) were not included. For each well, the date listed as the well completion date (typically the date of final preparation of the well for petroleum production) was considered to be the date of the water consumption. Listings for the actual treatment date are incomplete in the IHS Markit (TM) (2016) database, but generally the completion date is within a few days, or at most months, of the actual treatment date. The per-well treatment volumes were then aggregated via summation to a 1-mile grid using ArcGIS functions. The annual aggregated hydraulic fracturing treatment data were exported as annual GeoTIFF images with a resolution of 1 square mile per pixel and bundled into a TAR archive file. This data is not part of the USGS Aggregated Water Use Database (AWUDS) or the National Water Information System (NWIS).

These data tables describe observations made on borehole geophysical logs from 16,200 wells in the Williston Basin. It includes detailed surface hole locations, true vertical depths of formation tops, and true vertical thickness values between formation tops. The data contained in the “Williston_Basin_well_data.csv” table was used in generating the formation top shapefiles (“Formation top shapefile points for the 3D petroleum systems model of the Williston Basin, USA” child item) and the true vertical thickness shapefiles (“True vertical thickness shapefile points for the 3D petroleum systems model of the Williston Basin, USA” child item). A data glossary that describes the columns in the “Williston_Basin_well_data.csv” table is also included. This is a child item of a larger data release titled "Data release for the 3D petroleum systems model of the Williston Basin, USA".

This data release summarizes 126 borehole geophysical logs collected in fractured rock aquifers within the state of West Virginia. Data includes site information for the wells logged, in addition to all fractures identified as part of processing of borehole logs collected for the study. A machine learning algorithm was used to identify values in logs characteristic of specific lithologic formations, and to then use those range of values to identify the lithology for each interval in the various boreholes. The lithologic identifications were then assessed visually to assure the algorithm worked properly and did not misidentify certain lithologies. Overall the algorithm worked effectively, but did have some issues differentiating limestone from sandstone, so some manual adjustments of identified lithologies was necessary for a small percentage of the wells assessed.There are three data files that contain information for each of the 126 logged wells. Appendix 1 is found in LoggedWellInformation.csv describes the location and specific site characteristics for each of the 126 logged wells. Appendix 2 is found in AllBoreholeFractures.csv contains all fractures identified as a part of the analysis of the raw borehole geophysical logs collected for this study. This data includes both high transmissive water-bearing fractures, and low transmissive fractures.And Appendix 3 is found in WaterBearingFractures.csv contains only those fractures with sufficient transmissivity to be identified as water-bearing fractures, and includes transmissivity estimated for each of the water-bearing fractures.

This data release contains oil well annular cement and casing damage data from parts of the South Belridge and Lost Hills Oil Fields in western Kern County, California. The study area coincides with where groundwater with less than 10,000 milligrams per liter total dissolved solids and outside an exempt aquifer are located overlying oil-producing zones in these fields. In the study areas, hydraulic fracturing is occurring in mature oil fields where oil and gas development has occurred for approximately a century. The data were compiled from records of the California Department of Conservation, Geologic Energy Management Division (CalGEM). The data compiled include construction information for oil wells, drilling and plugging dates, cementing details, noted casing damage, and elevations of lithologic-layer tops intersected by the wells. These data were compiled to help evaluate potential fluid migration pathways between oil-bearing and groundwater zones described in a larger work.

This data release contains data associated with the Lewis Shale-Fox Hills Sandstone-Lance Formation depositional system (also referred to as the Lewis Shale system) in the eastern part of the Southwestern Wyoming Province of Wyoming and Colorado. Specifically, the data cover the Great Divide, Washakie, and Sand Wash Basins, the Wamsutter and Cherokee arches, and the Rock Springs Uplift. The Lewis Shale is underlain by the Almond Formation, overlain by the Fox Hills Sandstone, and interfingers with both formations on a regional scale. The Lewis Shale is divided into a lower, informal member, a middle, formal Dad Sandstone Member, and an upper, informal member. At the top of the lower Lewis member, there is a maximum flooding surface informally known as the Asquith marker. Additionally, within the Lewis Shale, there are 15 regional flooding surfaces (F01-F15) that bound and define 15 clinothems (C01-C15). Collectively, the data release includes 18 gross isopach grids, 15 net sand isopach grids, 2 structure grids, 1 data table, and 1 type log image of the Lewis Shale and associated strata. See the associated metadata files for the child data elements and the larger work of Hearon (in review) for detailed descriptions of the geology and additional methods.

This data set contains specific conductance and chloride concentration data in HUC-8 watersheds that intersect with areas with unconventional oil and gas plays. The data was originally used in the publication by Bowen et al. (2015. Assessment of surface water chloride and conductivity trends in areas of unconventional oil and gas development - Why existing national data sets cannot tell us what we would like to know. Water Resources Research 51: 704-715. A subset of this data was used by Cade (2017. Quantile regression applications in ecology and the environmental sciences. R. Koenker et al., eds. Handbooks of Modern Statistical Methods: Handbook of Quantile Regression. Chapman & Hall/CRC for example quantile regression analyses. The data were obtained from U. S. Geological Survey, National Water Information System (NWIS).