Report on geologic carbon sequestration opportunities in the Mount Simon Sandstone with information on geology and stratigraphy, core analyses and geophysical logs, variation in the reservoir, porosity, permability, and storage capacity.

Raw ADCP (Acoustic Doppler Current Profiler) datasets from acoustic interference surveys with a TRDI Workhorse 300, a Nortek Signature500 and two Signature1000 instruments from August 2020. One Signature 1000 ADCP was deployed for 13 days on a bottom lander in Sequim Bay Inlet, WA. Data from the other three instruments were taken from a survey vessel running transects above the deployed lander.

The TidGen Power System generates emission-free electricity from tidal currents and connects directly into existing grids using smart grid technology. The power system consists of three major subsystems: shore-side power electronics, mooring system, and turbine generator unit (TGU) device. This submission includes the test report on the characterization program composite testing and the selected composite structure. ORPC arranged coupon testing of candidate material sets as part of a larger characterization program. The goal of this testing was to down select the candidate material sets and determine failure mechanisms. This was done by testing both dry and saturated material sets and examining the effects of moisture uptake of the coupons mechanical properties. Due to the limitations of this program we were limited to static tensile testing is longitudinal and transverse directions as well as limited tensile fatigue testing with a loading of R=0.1 (tension - tension). This program did however, allow for a larger spread of material sets including a novel hydrophobic resin that was promoted to resist water uptake, optimized for subsea applications. Also included is a technical report on the characterization program, including composite test data, design FMEA for composite structure, material selection, composite design, PFMEA for the composite production process, reliability models, production process control plan and development plan. Materials for Marine Hydrokinetic (MHK) devices need to be evaluated before being utilized on a device with a service life of 20 years. For this reason, and the fact that ORPCs turbines are a complex manufacturing challenge, a composite optimization program is conducted. This program looked at novel material sets, production processes and developed tools to evaluate manufacturing defects and characterize their effect on structural performance over an extended operating time. This report will cover the work done during Budget Period 1 for Task 2 of the Advanced TidGen Power System Project.

The TidGen Power System generates emission-free electricity from tidal currents and connects directly into existing grids using smart grid technology. The power system consists of three major subsystems: shore-side power electronics, mooring system, and turbine generator unit (TGU) device. This submission includes the technical report on the composite trade study for chosen material sets.

The Plains CO2 Reduction (PCOR) Partnership, led by the Energy & Environmental Research Center (EERC), is working with Denbury Onshore (Denbury) to evaluate the effectiveness of large-scale injection of carbon dioxide (CO2) into the Bell Creek oil field for CO2 enhanced oil recovery (EOR) and to study long-term incidental CO2 storage. A technical team that includes Denbury, the EERC, and others are conducting activities to determine the baseline reservoir characteristics for development of a geologic model for predictive simulations and to serve as a comparison to time-lapse data as they are acquired. One of the activities was the acquisition and interpretation of a baseline three-dimensional (3-D) surface seismic survey acquired over a major portion of the field which is the subject of this report. The interpretation will be used to advance the field characterization effort. The geophysical data will be integrated with the EERC’s geologic model to improve its accuracy. In the future, when paired with at least one subsequent 3-D surface seismic survey, the data difference will provide a direct indication of where the CO2 has migrated within the reservoir and aid in monitoring, verification, and accounting goals. A brief overview of the source testing, data acquisition, and processing is given. A seismic source configuration consisting of two heavy vibrators operated in tandem was chosen after a series of tests conducted in August and December of 2011. The data acquisition for the main survey occurred in August and September 2012. The data were processed by a contractor in Houston and delivered to Denbury early in 2013. The EERC received a stacked data set in April with redactions where Denbury did not have mineral rights or leases. Seismic interpretation efforts began with making well ties to the data and identifying the Bell Creek reservoir reflector. The polarity of the dataset was established to be such that an increase in acoustic impedance (AI) would cause a negative deflection on the data. The reservoir is thin and of higher AI than the encasing shale layers, so with this polarity, it presents on the seismic data as a trough–peak combination representing the entering and exiting reflections at a two-way time of ~1150 msec at the 05-06 OW monitoring well location. The origin of the reservoir reflection is due to a large increase in AI at the top of the Springen Ranch and a similar decrease in AI at the top of the Skull Creek. The measured thickness of the Springen Ranch-to-Skull Creek interval in the field varies from about 50 to 75 feet. Spectral analysis of data in the zone of interest reveals a bandwidth of 10–48 Hz, which together with the average interval velocity mathematically limits the vertical resolution of the seismic data at reservoir depth to just under 60 feet. Therefore, the reservoir is a thin-bed reflector with thickness near or below the limit of resolution. A reflector of this type would be expected to exhibit possible tuning effects, but they are not evident. Tuning is an effect that occurs on thin beds when the top and bottom reflections interact to partially add in phase resulting in high reflection amplitudes. An important assumption is that the ix interval is lithologically homogeneous. The tuning thickness for this data’s bandwidth is 76 feet, so high amplitudes would be expected in thicker Springen Ranch-to-Skull Creek sections and lower amplitudes expected where the interval is thinner. The data exhibit the opposite character. This implies a nonhomogeneous interval where internal interactions due to lithology affect the composite reflection amplitude. The character of the Bell Creek sand meaningfully contributes to this effect. The Bell Creek reservoir sand is a subset of the reflection interval. Typically 20 to 30 feet thick, its top and bottom cannot be directly resolved on the seismic data set as delivered. When the sand is thick and clean and juxtaposed against the harder, fine-grained components of the Springen Ranch at the top and the Rozet below, these impedance contrasts internal to the overall composite reflection appear to cause interference effects which result in a low-amplitude reflection. When the sand is thinner or fines upward with less AI contrast, less internal interference results, and the composite reflection maintains a higher amplitude. Because of this, a map of seismic amplitudes generated from the reservoir reflection differentiates between areas of 1) thick clean sand and 2) thinner clean sand or sand with a fine-grained component or shaley matrix. The effect is illustrated in cross sections paired with well logs and also by overlaying the map on existing isopach maps of sand, with good agreement. Several geologic features are visible on the amplitude map and are briefly examined in cross section with the seismic data and well logs. These features include: 1. A fluvial channel feature in the northern part of the field, trending roughly north–south, has a higher amplitude than surrounding areas and is shown to be shale-filled and acts as a flow boundary. 2. A flow boundary between Phases 1 and 2 is also shown to be shale-filled and is a possible extension of the fluvial channel feature to the north. 3. A linear erosional valley trending northwest–southeast which predates the fluvial channel feature and serves as a flow boundary between Phases 1 and 3 and between Phases 2 and 4. The fill at the erosional surface is characterized by coal and bentonitic shales. 4. An erosional valley on the south end of the field which exhibits a dendritic outline. The fill at the erosional surface is characterized by coal and bentonitic shales. Three structural aspects of the field are briefly explored: 1. Thinning of the Bell Creek sand which forms the updip boundary and trap to the southeast is not directly discernible on the seismic data. 2. Polygonal faulting is shown to be prevalent within the overlying Belle Fourche Formation. The faults are thought to originate from dewatering of thick bentonite layers at the bottom of the Belle Fourche and top of the Mowry. Faults do not extend below the top of the Mowry or above the Belle Fourche and likely do not impact the containment integrity of the reservoir. 3. A possible basement faulting system thought to control the southwest to northeast trend of the reservoir paleo-high was identified and is shown on a section. Future work will include integrating the 3-D data and interpretation with the geocellular model and 3-D VSP data acquired in 2013 and 2014. Geomechanical properties will be computed across the field guided by the seismic data. Future time-lapse surface seismic data will use the baseline survey to generate difference displays to image and verify the progress of CO2 that has been injected into the reservoir. Modeling performed by Denbury has shown that injected CO2 will induce a detectable amplitude reduction on the reservoir reflection at the current bandwidth.

This dataset includes chemistry of geothermal water samples of the Camas Prairie area in Idaho. The samples included in this dataset were collected over the period of 2016-2019. Collection/analysis of new water samples and compilation of existing water chemistry database were conducted for Snake River Play Fairway Project. All chemical analysis of the samples were conducted in the Analytical Laboratory at the Center of Advanced Energy Studies (unless otherwise indicated) in Idaho Falls, Idaho. Isotope analysis were conducted in analytical/isotope measurement labs at Lawrence Berkeley National Laboratory, Utah State University, and University of Utah.

This data catalog contains information related to the Training Site Analysis for the Geothermica project "DE-risking Exploration of geothermal Plays in magmatic ENvironments (DEEPEN)." The DEEPEN project aims to reduce exploration risk for geothermal fluids in magmatic systems by developing improved an improved framework for interpretation of exploration data using the Play Fairway Analysis (PFA) methodology. The Training Site Analysis performed for DEEPEN leverages existing datasets to develop a customized PFA approach to exploration for multiple geothermal resource types in magmatic systems (conventional hydrothermal resources, supercritical fluid and superheated steam resources, and superhot EGS resources). This data catalog contains links to publicly available data files related to 8 training sites in the United States. US training sites are: the Cascades/Aleutians PFA project; the Hawaii PFA project, the Oregon Cascades PFA project, the Snake River Plain, Idaho PFA project, the Washington State PFA project, Newberry Volcano, Coso Geothermal Field, and the Geysers Geothermal field. This database contains an overview of these training sites, data sources, and links to publicly available exploration datasets. For the five PFA projects, details on exploration data related to PFA components (heat, fluid, permeability, sometimes seal) are provided, including a summary of data weighting methodologies.

DE-AC22-90-BC14666

Distributed fiber optic sensing was an important part of the monitoring system for EGS Collab Experiment #2. A single loop of custom fiber package was grouted into the four monitoring boreholes that bracketed the experiment volume. This fiber package contained two multi-mode fibers and four single-mode fibers. These fibers were connected to an array of fiber optic interrogator units, each targeting a different measurement. The distributed temperature system (DTS) consisted of a Silixa XT-DTS unit, connected to both ends of one of the two multi-mode fibers. This system measured absolute temperature along the entire length of fiber for the duration of the experiment at a sampling rate of approximately 10 minutes. This dataset includes both raw data in XML format from the XT-DTS, as well as a processed dataset with the sections of data pertaining only to the boreholes are extracted. We have also included a report that provides all of the relevant details necessary for users to process and interpret the data for themselves. Please read this accompanying report. If, after reading it, there are still outstanding questions, please do not hesitate to contact us. Happy processing.

This data was compiled for the 'Early Market Opportunity Hot Spot Identification' project. The data and scripts included were used in the 'MHK Energy Site Identification and Ranking Methodology' Reports (see resources below). The Python scripts will generate a set of results--based on the Excel data files--some of which were described in the reports. The scripts depend on the 'score_site' package, and the score site package depends on a number of standard Python libraries (see the score_site install instructions).

The submission contains a .xls files consisting of 10 excel sheets, which contain combined list of pressure, saturation, salinity, temperature profiles from the simulation of CO2 push-pull using Brady reservoir model and the corresponding effective compressional and shear velocity, bulk density, and fluid and time-lapse neutron capture cross section profiles of rock at times 0 day (baseline) through 14 days. First 9 sheets (each named after the corresponding CO2 push-pull simulation time) contains simulated pressure, saturation, temperature, salinity profiles and the corresponding effective elastic and neutron capture cross section profiles of rock matrix at the time of CO2 injection. Each sheet contains two sets of effective compressional velocity profiles of the rock, one based on Gassmann and the other based on Patchy saturation model. Effective neutron capture cross section calculations are done using a proprietary neutron cross-section simulator (SNUPAR) whereas for the thermodynamic properties of CO2 and bulk density of rock matrix filled with fluid, a standalone fluid substitution tool by Schlumberger is used. Last sheet in the file contains the bulk modulus of solid rock, which is inverted from the rock properties (porosity, sound speed etc) based on Gassmann model. Bulk modulus of solid rock in turn is used in the fluid substitution.

Report on oil and gas reservoirs, EOR operations, assessment of oil fields, considerations, and limitations in the MRCSP region.

Report on the R.E. Burger Plant addressing geologic assessment, seismic surveying, test well drilling and characterization, underground injection control permitting, CO2 supply and delivery system design, tests results and analysis, site closure, and stakeholder outreach.

This data set is associated with the Nevada Play Fairway project. Excel file 5-Area Chem contains all the major chemistry for the areas sampled in the project. New analyses are in lines 2-30, while older analyses appear below that. Field Data excel file contains both field notes and data with ninety entries showing sixty areas not sampled either because they were to dry, cold, or unable to locate. Thirty sites were sampled and their sample numbers appear in this file corresponding to those in the 5-Area Chemistry file. Excel file 5-Area Geothermometer contains a summary of geothermometers calculated for the new and historical data sets. Scanned field sheets are attached as a pdf.

The geocellular model of the Mt. Simon Sandstone was constructed for the University of Illinois at Urbana-Champaign DDU feasibility study. Starting with the initial area of review (18.0 km by 18.1 km [11.2 miles by 11.3 miles]) the boundaries of the model were trimmed down to 9.7 km by 9.7 km (6 miles by 6 miles) to ensure that the model enclosed a large enough volume so that the cones of depression of both the production and injection wells would not interact with each other, while at the same time minimizing the number of cells to model to reduce computational time. The grid-cell size was set to 61.0 m by 61.0 m (200 feet by 200 feet) for 160 nodes in the X and Y directions. Within the model, 67 layers are represented that are parameterized with their sediment/rock properties and petrophysical data. The top surface of the Mt. Simon Sandstone was provided by geologists working on the project, and the average thickness of the formation was taken from the geologic prospectus they provided. An average thickness of 762 m (2500 feet) was used for the Mt. Simon Sandstone, resulting in 60 layers for the model. Petrophysical data was taken from available rotary sidewall core data (Morrow et al., 2017). As geothermal properties (thermal conductivity, specific heat capacity) are closely related to mineralogy, specifically the percentage of quartz, available mineralogical data was assembled and used with published data of geothermal values to determine these properties (Waples and Waples, 2004; Robertson, 1988). The Mt. Simon Sandstone was divided into three separate units (lower, middle, upper) according to similar geothermal and petrophysical properties, and distributed according to available geophysical log data and prevailing interpretations of the depositional/diagenetic history (Freiburg et al. 2016). Petrophysical and geothermal properties were distributed through geostatistical means according to the associated distributions for each lithofacies. The formation temperature was calculated, based on data from continuous temperature geophysical log from a deep well drilled into the Precambrian basement at the nearby Illinois Basin Decatur Project (IBDP) where CO2 is currently being sequestered (Schlumberger, 2012). Salinity values used in the model were taken from regional studies of brine chemistry in the Mt. Simon Sandstone, including for the IBDP (e.g., Panno et al. 2018). After being reviewed by the project's geologists, the model was then passed onto the geological engineers to begin simulations of the geothermal reservoir and wellbores.

The geocellular model of the St. Peter Sandstone was constructed for the University of Illinois at Urbana-Champaign DDU feasibility study. Starting with the initial area of review (18.0 km by 18.1 km [11.2 miles by 11.3 miles]) the boundaries of the model were trimmed down to 9.7 km by 9.7 km (6 miles by 6 miles) to ensure that the model enclosed a large enough volume so that the cones of depression of both the production and injection wells would not interact with each other, while at the same time minimizing the number of cells to model to reduce computational time. The grid-cell size was set to 61.0 m by 61.0 m (200 feet by 200 feet) for 160 nodes in the X and Y directions. The top surface of the St. Peter Sandstone was provided by geologists working on the project, and the average thickness of the formation was taken from the geologic prospectus they provided. An average thickness of 68.6 m (225 feet) was used for the St. Peter Sandstone, resulting in 45 layers for the model. Petrophysical data was taken from available rotary sidewall core data (Morrow et al., 2017). As geothermal properties (thermal conductivity, specific heat capacity) are closely related to mineralogy, specifically the percentage of quartz, available mineralogical data was assembled and used with published data of geothermal values to determine these properties (Waples and Waples, 2004; Robertson, 1988). The St. Peter Sandstone was divided into facies according to similar geothermal and petrophysical properties, and distributed according to available geophysical log data and prevailing interpretations of the depositional/diagenetic history (Will et al. 2014). Petrophysical and geothermal properties were distributed through geostatistical means according to the associated distributions for each lithofacies. The formation temperature was calculated, based on data from continuous temperature geophysical log from a deep well drilled into the Precambrian basement at the nearby Illinois Basin Decatur Project (IBDP) where CO2 is currently being sequestered (Schlumberger, 2012). Salinity values used in the model were taken from regional studies of brine chemistry in the St. Peter Sandstone, including for the IBDP (e.g., Panno et al. 2018). After being reviewed by the project's geologists, the model was then passed onto the geological engineers to begin simulations of the geothermal reservoir and wellbores.

A binational effort between the United States and Canada is under way to characterize the lowermost saline system in the Williston and Alberta Basins of the northern Great Plains–Prairie region of North America in the United States and Canada. This 3-year project is being conducted with the goal of determining the potential for geologic storage of CO2 in rock formations of the 1.34-million-km2 Cambro-Ordovician Saline System (COSS). To our knowledge, no other studies have attempted to characterize the storage potential of large, deep saline systems that span the U.S.–Canada international border. This multiprovince/multistate, multiorganizational, and multidisciplinary project is led on the U.S. side by the Energy & Environmental Research Center (EERC) through the Plains CO2 Reduction (PCOR) Partnership and on the Canadian side by Alberta Innovates Technology Futures (AITF). The project objectives are to characterize this basal system in the northern Great Plains–Prairie region of North America and to evaluate its potential for, and effects of, CO2 storage in this system. At the base of the sedimentary succession in the Williston and Alberta Basins of the northern Great Plains–Prairie region of North America is a saline system composed of variable lithology which includes a variety of clastic and carbonate facies deposited across a range of environments. This system lies directly on top of igneous and metamorphic basement rocks and is largely contained beneath sealing formations that include shales and tight carbonates. These Middle Cambrian- to Lower Silurian-aged rocks extend from west-central Alberta into Saskatchewan, southwestern Manitoba, and then south into Montana, North Dakota, and South Dakota and form an extensive saline system generally devoid of hydrocarbon resources. In the area underlain by the COSS, there are 43 large CO2 sources that each emit more than 0.75 Mt CO2/year. Assuming that all of these emissions from each of these sources will be stored in the COSS, the main questions to be addressed by this study are 1) what is the storage resource of the system?, 2) how many years of CO2 emissions will it be capable of storing?, and 3) what will the fate and effects of the stored CO2 be? The project started on October 1, 2010, and is structured in three 1-year phases. Phase I focused on delineating and characterizing separately the Canadian and U.S. portions of the COSS. These were subsequently brought together into a single model during Phase II. The completed 2-D model incorporates the geologic data collected in the baseline characterization effort and distributes the various rock properties throughout the study region through geostatistical methods. Data on depth, thickness, and porosity were distilled v to produce components needed to compute the CO2 storage resource of this saline system following the Esaline formula detailed by the U.S. Department of Energy (DOE) methodology. A significant part of the effort was to match the work done on the U.S. side of the study region with the data sets generated by AITF for the Canadian side. All necessary gridded interpolations on the U.S. side were combined with the Canadian grids by a diffusive aggregation method near the U.S.–Canadian border to form a seamless CO2 storage volume for the entire COSS international study region. This aggregation method involved feathering the Canadian data near the border and joining it to the data on the U.S. side, thus allowing the geostatistical processing functions to interpolate across the border and avoid the development of edge effect at the border. Once the calculation on the U.S. side was completed, it was clipped out and joined to the existing Canadian portion to form a seamless map. This novel approach worked well for joining the two data sets, and the resulting 2-D model indicated a storage resource of 113 Gt. This work also provides the groundwork for the development of a massive 3-D geologic model encompassing the entire study area. In addition to the leading organizations of the EERC and AITF, other partners in the project are DOE, Lawrence Berkeley National Laboratory, and Princeton University in the United States and Saskatchewan Industry and Resources, Manitoba Water Stewardship, Manitoba Innovation – Energy and Mines, CanmetENERGY, Natural Resources Canada, TOTAL E&P Ltd., and the University of Regina Petroleum Technology Research Centre in Canada.

The objective of this project is to develop a comprehensive, interdisciplinary, and quantitative characterization of a fluvial-deltaic reservoir which will allow realistic inter-well and reservoir-scale modeling to be constructed for improved oil-field development in similar reservoirs world-wide. The geological and petrophysical properties of the Cretaceous Ferron Sandstone in east-central Utah will be quantitatively determined. Both new and existing data will be integrated into a three-dimensional representation of spatial variations in porosity, storativity, and tensorial rock permeability at a scale appropriate for inter-well to regional-scale reservoir simulation. Results could improve reservoir management through proper infill and extension drilling strategies, reduction of economic risks, increased recovery from existing oil fields, and more reliable reserve calculations. Transfer of the project results to the petroleum industry is an integral component of the project.

DOE/BC/14896-22

A comprehensive monitoring, mitigation and verification (MMV) plan is critical to the success of any geological carbon sequestration project utilized as a method of reducing CO2 emissions to the atmosphere. Beginning in October, 2005 and running through September, 2009 the Zama Oil Field in northwestern Alberta, Canada has been the site of acid gas (approximately 70% CO2 and 30% H2S) injection for the simultaneous purpose of enhanced oil recovery (EOR), H2S disposal, and sequestration of CO2. The Plains CO2 Reduction (PCOR) Partnership has conducted MMV activities at the site throughout this period while Apache Canada Ltd. has undertaken the injection and hydrocarbon recovery processes. This project has been conducted as part of the US Department of Energy (USDOE) and National Energy Technology Laboratory (NETL) Regional Partnership Program and includes the participation of Natural Resources Canada, the Alberta Department of Energy, the Alberta Energy & Utilities Board and the Alberta Geological Survey. In an effort to research caprock integrity and the risk of leakage during these field operations a first order geomechanical characterization has been undertaken of the injection reservoir, comprising the Keg River Formation and its Zama Member, and the overlying Muskeg Formation caprock. This poster will summarize key data obtained from a laboratory and wireline log-based analysis of the petrophysical and mechanical properties, and the in-situ stress state in this setting. Vertical stress estimates were determined by integrating bulk density logs in the area, while accounting for the unlogged portion above the surface casing shoe. Horizontal stress magnitudes in the caprock and reservoir were estimated from regional and local stress data for this part of Alberta. Dedicated stress tests such as a mini-frac, a microfrac profile, or an extended leak-off test have not been conducted in the caprock to date in this field. Minimum and maximum in-situ horizontal principal stress orientations in the Zama field and surrounding area, measured within and above the injection interval, were determined from borehole breakouts. Vertical and horizontal in-situ stress changes have occurred within the reservoir and surrounding caprock due to initial production in the pinnacle reef, subsequent water flooding, and most recently acid gas injection. The prediction of these stress changes is a complex function of the reef geometry, the poro-elastic response of the reservoir, pore pressure changes over time in the reef and reservoir, and possibly temperature changes. For this poster, only the horizontal stress changes due to poro-elastic effects have been considered. 3D geomechanical modelling will be used to simulate the more complex problem once the mechanical properties and in-situ stresses are adequately constrained. Basic porosity and unstressed permeability distributions from two cored intervals through the Zama Member and Keg River Formation in two pinnacle reefs in the setting are summarized. Ultrasonic shear and compressional wave velocity measurements have been made under unconfined and confined stress conditions on anhydrite and dolomite from the Muskeg Formation caprock. Triaxial rock strength and unconfined compressive strength (UCS) tests are summarized using Mohr Coulomb and Hoek Brown failure criteria. Static and dynamic elastic properties measured under anisotropic stress conditions are compared. A Schmidt rebound hammer was used to develop a profile of pseudo-static Young’s moduli and UCS though the Muskeg Formation caprock and portions of the Keg River Formation in two wells. Dynamic log-derived elastic properties and their static equivalents were determined for the Muskeg and Keg River Formations in two wells. In order to do this a synthetic shear velocity relationship was developed using recent data from an offset well in the region. These log-derived properties are compared to the static laboratory and Schmidt hammer derived data. Pore volume compressibility tests were also made on a select number of core plugs of the Keg River Formation under relevant reservoir pore pressure and stress conditions, along with stress-dependent permeability and elastic properties. Statistical relationships describing the petrophysical and mechanical properties of the rocks investigated in this study are presented. Key learnings with regard to the heterogeneity of the vuggy dolomitic reservoir versus the evaporitic caprock are highlighted. The data presented in this poster have a variety of applications to EOR and CO2 sequestration in pinnacle reefs of the type being investigated in the Zama field. In addition to caprock integrity, the data can be used to assess optimal injection strategies, design well drilling, completion and stimulation programs, develop and interpret reservoir monitoring data, and conduct coupled geomechanical-reservoir simulation studies of acid gas injection.

This submission contains geotiffs, supporting shapefiles and readmes for the inputs and output models of algorithms explored in the Nevada Geothermal Machine Learning project, meant to accompany the final report. Layers include: Artificial Neural Network (ANN), Extreme Learning Machine (ELM), Bayesian Neural Network (BNN), Principal Component Analysis (PCA/PCAk), Non-negative Matrix Factorization (NMF/NMFk), input rasters of feature sets, and positive/negative training sites. See readme .txt files and final report for additional metadata. A submission linking the full codebase for generating machine learning output models is available under "related resources" on this page.

This data set includes the numerical modeling input files and output files used to synthesize data, and the reduced-order machine learning models trained from the synthesized data for reservoir thermal energy storage site identification. In this study, a machine-learning-assisted computational framework is presented to identify High-Temperature Reservoir Thermal Energy Storage (HT-RTES) site with optimal performance metrics by combining physics-based simulation with stochastic hydrogeologic formation and thermal energy storage operation parameters, artificial neural network regression of the simulation data, and genetic algorithm-enabled multi-objective optimization. A doublet well configuration with a layered (aquitard-aquifer-aquitard) generic reservoir is simulated for cases of continuous operation and seasonal-cycle operation scenarios. Neural network-based surrogate models are developed for the two scenarios and applied to generate the Pareto fronts of the HT-RTES performance for four potential HT-RTES sites. The developed Pareto optimal solutions indicate the performance of HT-RTES is operation-scenario (i.e., fluid cycle) and reservoir-site dependent, and the performance metrics have competing effects for a given site and a given fluid cycle. The developed neural network models can be applied to identify suitable sites for HT-RTES, and the proposed framework sheds light on the design of resilient HT-RTES systems. All the simulations and the neural network model were done by Idaho National Laboratory. A detailed description of the work was reported in publication linked below.

This dataset includes modeled tidal current velocities, direction and depth at two locations in East and North Forelands (60.716, -151.434 and 61.024, -151.157) near Nikiski and Tyonek, respectively, in Cook Inlet, Alaska. Data from two grid cells were provided by the Pacific Northwest National Laboratory based on a tidal hydrodynamic model that characterized the tidal stream resources in Cook Inlet for a period from May 1 to September 1, 2005 (Wang and Yang 2020). The model grid size had a horizontal spatial resolution of 100 m at East Forelands and 200 m at Tyonek; mean sea level (MSL) depth was 47.9 m and 23.7 m at each respective site, and there were 10 depth bins that ranged in size with the tide from 4.3-5.2 m and 1.9-2.8 m, respectively (Wang and Yang 2020).

This submission has wave resource assessments which were conducted for six locations based on IEC requirements using the DOE WPTO Hindcast data and MHKiT. The locations are chosen to provide varying wave climates and include PacWave South, OR; Wave Energy Testing Site (WETS), HI; Molokai, HI; St. Paul, AK; Yakutat, Ak; and Sebastion, FL. It includes the data gathered and the resulting report. This submission also includes a link to Hindcast dataset and some relevant software.

Field measurements of mean flow and turbulence parameters at the Kvichak river prior to and after the deployment of ORPC's RivGen hydrokinetic turbine. Data description and turbine wake analysis are presented in the attached manuscript "Wake measurements from a hydrokinetic river turbine" by Guerra and Thomson (recently submitted to Renewable Energy). There are three data sets: NoTurbine (prior to deployment), Not_Operational_Turbine (turbine underwater, but not operational), and Operational_Turbine. The data has been quality controlled and organized into a three-dimensional grid using a local coordinate system described in the paper. All data sets are in Matlab format (.mat). Variables available in the data sets are: qx: X coordinate matrix (m) qy: Y coordinate matrix (m) z : z coordinate vector (m) lat : grid cell latitude (degrees) lon: grid cell longitude (degrees) U : velocity magnitude (m/s) Ux: x velocity (m/s) Vy: y velocity (m/s) W: vertical velocity (m/s) Pseudo_beam.b_i: pseudo-along beam velocities (i = 1 to 4) (m/s) (structure with raw data within each grid cell) beam5.b5: 5th-beam velocity (m/s) (structure with raw data within each grid cell) tke: turbulent kinetic energy (m2/s2) epsilon: TKE dissipation rate (m2/s3) Reynolds stresses: uu, vv, ww, uw, vw (m2/s2) Variables from the Not Operational Turbine data set are identified with _T Variables from the Operational Turbine data set are identified with _TO

As part of the characterization efforts for the Bell Creek oil field, 81 core samples of the Muddy and Mowry Formations from 21 wells were selected from the U.S. Geological Survey Core Research Center in Denver, Colorado, and analyzed by the EERC's Applied Geology Laboratory. The samples were characterized in detail for several rock properties, such as compositional mineralogy, bulk mineralogy, grain size, porosity, permeability, pore volume, clay type, bulk chemistry, diagenetic features, and biological characteristics. The goal of this characterization activity is to obtain a better understanding of the petrographic and petrophysical properties of the Mowry and Muddy Formations in and around Bell Creek oil field.

Report on the characterization of carbon capture and storage beneath the New Jersey coastal plain, beneath the continental shelf and slope offshore, and in the Stockton Formation in the Newark Basin.

These methods result from about four years of study of shales and recent fine-grained muds. Characterization of shales has been a topic of intensive research under the Eastern Gas Shales Project through a contract study to West Virginia Geological and Economic Survey funded by United States Department of Energy.

Report on the reassesment of storage capacity and EOR potential of Devonian shales in the Appalachian Basin discussing the method of capacity estimation (area, thickness, concentration and density of CO2, storage efficiency factor) and towards demonstration of CO2 sequestration and EOR in shale in the Burk Branch Project wells (Pike County, Kentucky).

NIPER-484 topical report

In December 2016, 1301 vertical-component seismic instruments were deployed at the San Emidio Geothermal field in Nevada. The first record starts at 2016-12-05T02:00:00.000000Z (UTC) and the last record ends at 2016-12-11T14:00:59.998000Z (UTC). Data are stored in individual files in one-minute increments in SEGD and MSEED formats. See the metadata in GDR submission (linked below as "Seismic Survey 2016 Metadata at San Emidio Nevada") for details about the seismic station locations, seismic data logger specifications, instrumentation specifications, descriptions of data, a fracture finding summary, and the final report for the 2016 seismic survey done in San Emidio, Nevada.

Input and output files used for fault characterization through numerical simulation using iTOUGH2. The synthetic data for the push period are generated by running a forward simulation (input parameters are provided in iTOUGH2 Brady GF6 Input Parameters.txt [InvExt6i.txt]). In general, the permeability of the fault gouge, damage zone, and matrix are assumed to be unknown. The input and output files are for the inversion scenario where only pressure transients are available at the monitoring well located 200 m above the injection well and only the fault gouge permeability is estimated. The input files are named InvExt6i, INPUT.tpl, FOFT.ins, CO2TAB, and the output files are InvExt6i.out, pest.fof, and pest.sav (names below are display names). The table graphic in the data files below summarizes the inversion results, and indicates the fault gouge permeability can be estimated even if imperfect guesses are used for matrix and damage zone permeabilities, and permeability anisotropy is not taken into account.

This presents the results of Phase 1 of the Snake River Plain Play Fairway Analysis project, along with a proposed work for Phase 2. No new data were collected, but we list data sources for our compilation. The Snake River volcanic province (SRP) overlies a thermal anomaly that extends deep into the mantle; it represents one of the highest heat flow provinces in North America. The Yellowstone hotspot continues to feed a magma system that underlies southern Idaho and has produced basaltic volcanism as young as 2000 years old. It has been estimated to host up to 855 MW of potential geothermal power production, most of which is associated with the Snake River Plain volcanic province. Our goals for this Phase 1 study were to: (1) adapt the methodology of Play Fairway Analysis for geothermal exploration to create a formal basis for its application to geothermal systems, (2) assemble relevant data for the SRP from publicly available and private sources, and (3) build a geothermal play fairway model for the SRP and identify the most promising plays, using software tools that are standard in the petroleum industry. Our ultimate goals are to lower the risk and cost of geothermal exploration throughout geothermal industry, and to stimulate the development of new geothermal power resources in Idaho.

Rheology data obtained from flow loop tests, performed using different lost circulation materials (LCM) to study their effect on fluid rheology and wellbore hydraulics. The sealing performance of different LCM was tested using different fracture sizes. Five academic papers / reports derived from this research are also presented.

Third International Reservoir Characterization Technical Conference 1991

During the summer field season in 2012, Benthic GeoScience Inc. (Benthic) mobilized under contract with Ocean Renewable Power Company (ORPC) in order to conduct precise geospatial measurements of the seafloor accomplishing a preliminary Site Characterization Study for the ORPC East Forelands Tidal Energy Power Project. This study included a high-density bathymetric survey, acoustic reflective intensity imagery, and an assessment of the physical character of the ORPC East Forelands Tidal Energy Power Project environment. The Multibeam Echosounder (MBES) survey included a large area surrounding the East Forelands of Cook Inlet in the vicinity of Nikiski, Alaska. Included in this submission are the report for the East Forelands Site Characterization Study and the accompanying data from the survey as described below. The digital deliverables from this effort include: - Comprehensive Site Characterization Report (Format: PDF, Ver. 1.1, March 2013) - Comprehensive 3D Fledermaus Presentation (Format: SCENE, Ver. 1.1, March 2013) - Bathymetric Surface (Format: ASCVer. 1, March 2013) - Slope Gradient Surface (Format: ASCVer. 1, March 2013) - Comprehensive Acoustic Intensity Image (Format: TIF/TWFVer. 1, March 2013) - Geologic Seafloor Interpretation Surface (Format: ASCVer. 1.0, March 2013) - Comprehensive Google Earth Presentation (Format: KMZVer. 1.1, March 2013)

This package contains USGS data contributions to the DOE-funded Nevada Geothermal Machine Learning Project, with the objective of developing a machine learning approach to identifying new geothermal systems in the Great Basin. This package contains three major data products (geophysics, heat flow, and fault dilation and slip tendencies) that cover a large portion of northern Nevada. The geophysics data include map surfaces related to gravity and magnetic data, and line and point data derived from those surfaces. Heat flow data include an interpolated map of heat flow in mW/m^2, an error surface, and well data used to construct them. The dilation and slip tendency information exist as attributes assigned to each line segment of mapped faults and geophysical lineaments. GDR submission contains link to official USGS data release. Additional metadata available on source DOI page.

This submission contains documents that describe the USU Camas-1 test well, drilled in Camas Prairie, Idaho, in Fall 2018 and Fall 2019. The purpose of this well is to validate exploration methodologies of the Snake River Plain (SRP) Play Fairway Analysis (PFA) project.

The compressed (.zip) file contains Datawell MK-III Directional Waverider binary and unpacked data files as well as a description of the data and manuals for the instrumentation. The data files are contained in the two directories within the zip file, "Apr_July_2012" and "Jun_Sept_2013". Time series and summary data were recorded in the buoy to binary files with extensions '.RDT' and '.SDT', respectively. These are located in the subdirectories 'Data_Raw' in each of the top-level deployment directories. '.RDT' files contain 3 days of time series (at 1.28 Hz) in 30 minute "bursts". Each '.SDT' file contains summary statistics for the month indicated computed at half-hour intervals for each burst. Each deployment directory also contains a description (in 'File.list') of the Datawell binary data files, and a figure ('Hs_vs_yearday') showing the significant wave height associated with each .RDT file (decoded from the filename). The corresponding unpacked Matlab .mat files are contained in the subdirectories 'Data_Mat'. These files have the extension '.mat' but use the root filename of the source .RDT and .SDT files.

This link leads to a webpage with spreadsheets containing seismic borehole sensor locations and well trajectories for wells 56-32, 58-32, 78-32, 78B-32. Each of the files at the provided link include meta data on relevant information.

This report describes the development of a preliminary 3D seismic velocity model at the Utah FORGE site and first results from estimating seismic resolution in the generated fracture volume during Stage 3 of the April 2022 stimulation. A preliminary 3D velocity model for the larger FORGE area was developed using RMS velocities of the seismic reflection survey and seismic velocity logs from borehole measurements as an input model. To improve the accuracy of the model in the shallow subsurface, travel times phase arrivals of the direct propagating P-waves were determined from the seismic reflection data, using PhaseNet, a deep-neural-network-based seismic arrival time picking method. The travel times were subsequently inverted using the input velocity model. The results showed that the input velocity model needs improvement as the resulting model appears too fast in the easter region of the FORGE area. During the next phase of this work, we will update the input velocity model and generate P-wave arrival times for additional seismic source locations, to improve the horizontal resolution in the sedimentary layer and to obtain a model that better matches the sedimentary layer and the travel time observations.

These are revised catalogs, related to the April, 2022 well 16A(78)-32 stimulation (phases 1,2, & 3), provided by Geo Energie Suisse (GES) that include additional events at the start of Stage 1 and some tidying up of some locations. These catalogs also include events for additional events that were auto-located to provide a larger dataset for statistical analyses, like b-value calculations. The actual auto-locations have been removed to prevent spurious location plots being created.

This dataset includes files used to fit planar fractures through the preliminary earthquake catalogs of the three stages of the April 2022 well 16A(78)-32 stimulation which is linked bellow. These planar features have been used to update the FORGE reference Discrete Fracture Network (DFN) model. The files are provided to encourage other modelers to use additional workflows to find additional/alternative features. To this end, the dataset includes the cleaned earthquake catalog data translated to the FORGE reference model global reference frame, the well trajectory of 16A(78)-32 in those same coordinates, the fit 15 planar features in csv format, and a pdf file with slides illustrating the process used to fit the features. A recorded presentation of this material is available from the October 2022 FORGE Modeling and Simulation Forum which is also linked below.

This is a presentaiton from Metarock Laboratories on the thermal properties of Utah FORGE well 58-32 granite core. The presentation includes pictures of core samples, core details for the samples (sample depths and size), sample thermal expansion test results, and radial velocity measurements.

This Excel spreadsheet contains temperature survey results for Utah FORGE wells 58-32, 78-32, 56-32, 16A(78)-32 and 78B-32. It also contains charts and comparisons, along with a "Data Summary" which provides links to previous GDR submissions with temperature data for each well.

This is a GIS point feature shapefile representing wells, and their temperatures, that are located in the general Utah FORGE area near Milford, Utah. There are also fields that represent interpolated temperature values at depths of 200 m, 1000 m, 2000 m, 3000 m, and 4000 m. in degrees Fahrenheit. The temperature values at specific depths as mentioned above were derived as follows. In cases where the well reached a given depth (200 m and 1, 2, 3, or 4 km), the temperature is the measured temperature. For the shallower wells (and at deeper depths in the wells reaching one or more of the target depths), temperatures were extrapolated from the temperature-depth profiles that appeared to have stable (re-equilibrated after drilling) and linear profiles within the conductive regime (i.e. below the water table or other convective influences such as shallow hydrothermal outflow from the Roosevelt Hydrothermal System). Measured temperatures/gradients from deeper wells (when available and reasonably close to a given well) were used to help constrain the extrapolation to greater depths. Most of the field names in the attribute table are intuitive, however HF = heat flow, intercept = the temperature at the surface (x-axis of the temperature-depth plots) based on the linear segment of the plot that was used to extrapolate the temperature profiles to greater depths, and depth_m is the total well depth. This information is also present in the shapefile metadata.

This dataset contains groundwater geochemistry from several wells in North Milford Valley, Utah, in the region of the Utah FORGE project (Phase 2c). Readme file that discusses the data contained in the Excel spreadsheet. Data include GPS coordinates (UTM, Lat-Long), sampling temperature, pH, Li, Na, K, Ca, Mg, SiO2, B, Cl, F, SO4, HCO3, oxygen, and hydrogen isotopes. Analyses were performed at the Utah State Laboratory and the University of Minnesota. The zipped archive includes Excel and csv format spreadsheets, a shapefile map with well locations, and a readme text file with additional information. The zip is updated data from October 2021.

This dataset contains all well logs from Utah FORGE well 16A(78)-32. This includes the mud log, Sanvean Technologies logs, and Schlumberger logs. Please see the file descriptions below for information about each log.

Well 58-32 (previously labeled MU-ESW1) was drilled near Milford Utah during Phase 2B of the FORGE Project to confirm geothermal reservoir characteristics met requirements for the final FORGE site. Well Accord-1 was drilled decades ago for geothermal exploration purposes. While the conditions encountered in the well were not suitable for developing a conventional hydrothermal system, the information obtained suggested the region may be suitable for an enhanced geothermal system. Geophysical well logs were collected in both wells to obtain useful information regarding there nature of the subsurface materials. For the recent testing of 58-32, the Utah FORGE Project contracted with the well services company Schlumberger to collect the well logs.

An investment of $0.7M from the Geothermal Technology Office for Phase 2 of Play Fairway Analysis in Washington State improved existing favorability models and increased model confidence. New 1:24,000-scale geological mapping, 15 detailed geophysical surveys, 2 passive seismic surveys, and geochronology collected during this phase were coupled with updated and detailed structural modeling and have significantly improved the conceptual models of three potential blind geothermal systems/plays in Washington State, the St. Helens Shear Zone, Mount Baker, and Wind River Valley. Results of this analysis reveal the presence of commercially viable undiscovered geothermal resources in all three study areas. The analysis additionally provides a clear definition of the geothermal prospects in terms of the essential elements of a functioning geothermal system, the confidence in these assessments, and associated potential and risk of development. This report also includes a proposal to validate the modeling results in highly favorable areas for two main reasons: (1) to develop confidence in the modeling approach that will encourage future development of geothermal resources in Washington State inside and outside of the Phase 2 study areas, and (2) to provide actionable results to the DOE, existing industry partners, newly identified developers, and other renewable-energy stakeholders. The proposed validation activities aim to collect new data that will further the understanding of geothermal resource potential in Washington, as well as substantiate the favorability, confidence, and risk models developed in Phases 1 and 2.