Bell Creek oil field CO2 storage volumes reported monthly to DOE

The data includes a geospatial and spreadsheet representation of a resource analysis for closed loop pumped storage systems across the Continental United States, Alaska, Hawaii, and Puerto Rico. The data includes energy storage potential, water volume, distance from source to storage, hydraulic head, dollars per kilowatt of storage, and transmission spurline cost for each pumped storage hydropower (PHS) reservoir. Each reservoir represented in this dataset is represented on potential 10 hour storage duration PSH system comprised of two reservoirs. Units of measure are laid out in the dataset. Pumped storage hydropower (PSH) represents the bulk of the United States' current energy storage capacity: 23 gigawatts (GW) of the 24 GW national total (Denholm et al. 2021). This capacity was largely built between 1960 and 1990. PSH is a mature and proven method of energy storage with competitive round-trip efficiency and long life spans. These qualities make PSH a very attractive potential solution to energy storage needs, particularly for longer-duration storage (8 hours or more); such storage will be crucial to bridge gaps in electricity production as variable wind and solar production continue to comprise an ever-larger portion of the United States' energy portfolio. This study seeks to better understand the technical potential for PSH development in the United States by developing a national-scale resource assessment for closed-loop PSH. For more information, please refer to the Closed Loop Pumped Storage Hydropower Resource Assessment for the United States linked in the resources.

Final report for the DOE GTO funded research on geologic thermal energy storage (GeoTES), or commonly known as reservoir thermal energy storage (RTES). The results described in this report shed light on various aspects of RTES including project siting, operational performance, mitigation of both subsurface and surface infrastructure issues, and system longevity. Additionally, the reviews of international projects provide valuable lessons associated with exploration, initiation, operation, and sustainable maintenance of RTES. Overall site characterization, THM modeling, risk evaluation, and flexible operations are key aspects to a suitable RTES project. Geochemical modeling supported by laboratory experiments show that understanding the intricacies in brine chemistry and fluid evolution within changing thermal and pressure environments is important because resultant diagenetic reactions and subsequent scaling exist even in unexpected scenarios. Thermo-hydro-chemical (THC) and THM modeling with MOOSE and TOUGH also inform the potential for hydrogeological and geochemical changes within the reservoir and best operational parameters over the life of an RTES system. The results of this study help define future RTES research projects that will facilitate successful future deployment of such systems and make RTES a more viable option for energy storage in the U.S.

FSIS’ FoodKeeper application educates users about food and beverages storage to help them maximize the freshness and quality of these items. By helping users understand food storage, the application empowers consumers to choose storage methods that extend the shelf life of their items. By doing so users will be able to keep items fresh longer than if they were not stored properly.

A feasibility study of carbon capture and storage at Fort Nelson. PHILOSOPHY OF THE BEST PRACTICES MANUAL DOE has established a process whereby information is conveyed to CCS stakeholders through the use of BPMs. These documents serve to provide specific information and lessons learned regarding key aspects of the characterization, development, and implementation phases of large-scale CCS projects. The information compiled here is intended to increase awareness of the steps required to use an iterative, adaptive management approach to determine the technical viability of commercially implementing a CCS project. Specifically, this BPM is a technical guide to conducting a feasibility study for storing CO2 in a deep carbonate saline formation. The target audience for this BPM includes project developers; regulatory officials; national, state/provincial, and local policymakers; and the CCS scientific and engineering community. The information in this BPM is intended to serve as a guide to other regions where deep carbonate formations may serve as targets for geological storage of CO2. The approach of this BPM is to present and describe the critical steps that must be taken prior to undertaking a large-scale CCS project, specifically, site characterization, modeling and simulation, risk assessment (RA), and planning for monitoring, verification, and accounting (MVA). The approach and results of the work that was conducted by SET and the PCOR Partnership for the Fort Nelson project are presented as an example of the application of this iterative, adaptive management approach.

GoNM is a web map that shows locations of active and former petroleum storage tank (PST) facilities and sites of active and closed releases. The web map contains links to relevant documents (if available electronically) pertaining to individual sites when they are clicked on the map, such as inspection reports including tank closure information and monitoring reports for release sites. Water quality and depth to groundwater information is included in monitoring reports.

KY Energy Infrastructure

This dataset contains the number of connections per primary and low carbon technology from April 2017

This dataset contains the number of enquiries per primary and low carbon technology from April 2017.

Resources for MHKDR data submitters and curators, including training videos, step-by-step guides on data submission, and detailed documentation of the MHKDR. The Data Management and Submission Best Practices document also contains API access and metadata schema information for developers interested in harvesting MHKDR metadata for federation or inclusion in their local catalogs.

Resources for OEDI data submitters and curators, including training videos, step-by-step guides on data submission, and detailed documentation of OEDI. The Data Management and Submission Best Practices document also contains API access and metadata schema information for developers interested in harvesting OEDI metadata for federation or inclusion in their local catalogs.

A range of data for the Orange-Senqu basin, including narrative and numerical data covering rainfall, evaporation, radiation, soil type, groundwater recharge, yield, groundwater quality, dam infrastructure, surface water flows, surface water quality, flood, irrigation, urban water supply. The database can be searched by category or keywork, and will produce particular studies, with coverage of particular regions or the whole basin. Where data is available, it will be linked within the study pages, and provided either in pdf, xls, or GIS-compatable formats.

Vertical Seismic Profile data collected in 2009 and 2010 as part of SECARB Phase III Early Test at Cranfield oilfield in Mississippi to determine CO2 induced change from seismic response. Data divided into 3D VSP and Offset VSP folders. Associated Publications: Daley, T. M., Hendrickson, J., & Queen, J. H. (2014). Monitoring CO2 Storage at Cranfield, Mississippi with Time-Lapse Offset VSP – Using Integration and Modeling to Reduce Uncertainty. Energy Procedia, 63, 4240-4248. doi:10.1016/j.egypro.2014.11.459

Soil-Gas monitoring data collected at the P-site and DAS study locations during SECARB project at Cranfield oil site in Mississippi. Data was used to study influence of gravel pad, pit, plants, and plugged and abandoned (P&A) oil well on near-surface soil-gas compositions. Associated Publications: Anderson, J. S., Romanak, K. D., Yang, C., Lu, J., Hovorka, S. D., and Young, M. H., 2017, Gas source attribution techniques for assessing leakage at geologic CO2 storage sites: Evaluating a CO2 and CH4 soil gas anomaly at the Cranfield CO2-EOR site: Chemical Geology, v. 454, p. 93-104, doi:10.1016/j.chemgeo.2017.02.024 Hingst, M. C., 2013. Geochemical effects of elevated methane and carbon dioxide in near-surface sediments above an EOR/CCUS site, The University of Texas at Austin, Master’s thesis. http://hdl.handle.net/2152/21836 Lu, J., Kharaka, Y. K., Thordsen, J. J., Horita, J., Karamalidis, A., Griffith, C., Hakala, J. A., Ambats, G., Cole, D. R., Phelps, T. J., Manning, M. A., Cook, P. J., and Hovorka, S. D., 2012, CO2‒rock‒brine interactions in Lower Tuscaloosa Formation at Cranfield CO2 sequestration site, Mississippi, U.S.A.: Chemical Geology, v. 291, p. 269‒277. Yang, C., Jamison, K., Xue, L., Dai, Z., Hovorka, S. D., Fredin, L., and Treviño, R. H., 2017, Quantitative assessment of soil CO2 concentration and stable carbon isotope for leakage detection at geological carbon sequestration sites: Greenhouse Gases: Science and Technology, v. 7, no. 4, p. 680-691, doi:10.1002/ghg.1679. Yang, C., Romanak, K. D., Reedy, R. C., Hovorka, S. D., and Treviño, R. H., 2017, Soil gas dynamics monitoring at a CO2-EOR site for leakage detection: Geomechanics and Geophysics for Geo-Energy and Geo-Resources, v. 3, p. 351-364, doi:10.1007/s40948-017-0053-7

A binational effort, between the United States and Canada, characterized 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 was conducted with the goal of determining the potential for geologic storage of carbon dioxide (CO2) in rock formations of the 517,000 sq mi Cambro-Ordovician Saline System (COSS). This project was 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 characterized the COSS using well log and core data from three states and three provinces and determined its storage potential by creating a heterogeneous 3-D model and determined the effects of CO2 storage in this system using dynamic simulation. The area underlain by the COSS includes several large CO2 sources that each emits more than 1 Mt CO2/year. Assuming that each of these sources will target the COSS for the storage of their CO2, the primary questions addressed by this study are 1) what is the CO2 storage resource of the COSS, 2) how many years of current CO2 emissions will it be capable of storing, and 3) what will be required and what will be the effect of injecting 104 Mt/yr of CO2 into the COSS? A 3-D geocellular model was created and used to determine the static CO2 storage resource and the dynamic storage capacity. The complexity of the reservoir was characterized from numerous sources of data, including the online databases of North Dakota, South Dakota, and Montana and a wealth of data provided by project partners in Canada. Multimineral petrophysical analysis was conducted to determine the system’s gross lithology and key petrophysical characteristics. Information derived from these analyses was used to create a facies model that captures the heterogeneity of the COSS at this broad scale. The completed geocellular model contains information on temperature, pressure, porosity, permeability, and salinity. These variables were distilled to produce components needed to compute the CO2 storage resource of the COSS following the Esaline formula detailed by the U.S. Department of Energy (DOE) Office of Fossil Energy Atlas III and IV (2010, 2012). The resulting effective static CO2 storage resource is 218, 412, and 706 Gt at the P10, P50, and P90 percentiles, respectively. This resource potential represents more than 2100 years of storage for the current 104 Mt/yr point source emissions. To further evaluate this extensive system and thus its viability as a potential sink, the geocellular model was used as the framework for an assessment of the system’s dynamic CO2 storage capacity. In the area above the COSS, there are 25 large stationary sources that were viii grouped into 16 geographic areas that have a combined annual emission of 104 Mt. With this in mind, the first injection scenario considered seven cases where the target was to inject this total mass of CO2 for 36 or 50 years in the 16 injection areas using a total of 210 wells. Results from these cases show a total mass of CO2 injected ranging from 82 to 1412 Mt across the injection period of 36 and 50 years. These values represent between 2.2% and 27.2% of the available CO2 emitted from the 16 source locations. In the second scenario, eight new cases where the original 16 injection locations were disaggregated and moved (pipelined) to areas defined by the model as having good reservoir volume connection (geobodies) based on permeabilities greater than 50 mD. Injection amounts in the second scenario range from 1949 to 3112 Mt of CO2. These values represent 37.5% to 59.8% of the CO2 emitted from the source locations. Based on the results of both scenarios, the selection of areas with better permeability and connected volume had a large impact on increasing the total amount of CO2 stored and the per well injection rates. However, even in the better area, the COSS was not able to support 211 injection wells with an average injection rate of 0.5 Mt/yr. In the second scenario, the average annual per well injection rate was between 185,000 and 275,000 tons/yr. At these injection rates, a total of 378 to 563 wells would have been required to meet the injection target. Pressure differences monitored in the second scenario show small changes in the 50-year injection time period. These minimal pressure differences indicate small risks of leakage from the reservoir and integrity of the sealing cap rock due to CO2 injection in the COSS. The results of the static CO2 storage resource estimate indicate that the COSS has thousands of years of storage potential at the current point source CO2 emission levels. However, the actual task of injecting the annual emissions is more difficult. Results from simulation indicate that injecting all the point source CO2 in an area directly beneath the sources using 210 wells did not result in meeting the storage target. With that in mind, the COSS model and simulations were run on limited data, and just because these simulation cases indicated that the injection volumes, as a whole, could not be reached does not mean that the geology around a particular CO2 source is poor. These results indicate that there is sufficient storage potential in the COSS to store all of the current point source CO2 emissions for at least the next 50 years; however, more wells will likely be needed and spread out over more of the COSS to achieve this goal.

The Bureau of Mines investigated the contribution of selected components and additives of high-temperature aircraft fuels to thermally induced deposits before and after 52 weeks of storage at 130/sup 0/F. Of particular concern was the influence of fuel constituents on thermal stability quality of jet fuels during storage. A microfuel coker test apparatus was used to measure the thermal stability of test fuels and blends. The contribution of selected fuel components, labeled with carbon-14, to deposit-forming mechanisms was determined by radioactive-counting techniques. Twenty-eight blends of the five test fuels with carbon-14-labeled fuel additives or components reached the final stage of storage at 130/sup 0/F and received final analyses for deposit forming tendency. These additives included an amine-type antioxidant, a metal deactivator, and a corrosion inhibitor. Also included in this study group were oleic acid and 1,5-hexadiene. All three additives showed a marked tendency to degrade and react during storage and thermal stress. Oleic acid was found to interact with cadmium present in aircraft fuel systems and produce deleterious effects upon the thermal stability quality of the fuel. Sixteen blends of the five test fuels with nonradioactive components were prepared as part of a special study. Six of these blends contained 1% of selected aromatic compounds, five blends contained an anti-icing additive, and five blends contained an organic sulfur compound. Results showed changes in thermal stability quality of many of the blends containing sulfur compounds. Four additional special studies were performed as preliminary investigations to continued research of jet fuel stability characteristics. Both were designed to improve producers or develop new, improved procedures for thermal stability tests.

WRRI's Statewide Water Assessment is an effort that will complement existing state agency water resource assessments. It will provide new, dynamic (updated frequently), spatially representative assessments of water budgets for the entire state of New Mexico. Projects included in the Statewide Water Assessment bring new technologies that expand existing studies and are applicable statewide. Of particular interest are water budget components for which state agencies require improved information, such as evapotranspiration (ET), crop consumptive use, groundwater recharge, and streamflow.

This app is based on data from NASA’s Global Land Data Assimilation System (GLDAS-2.1), which uses weather observations like temperature, humidity, and rainfall to run the Noah land surface model. This model estimates how much of the rain becomes runoff, how much evaporates, and how much infiltrates into the soil. These output variables, calculated every three hours, are aggregated into monthly averages, giving us a record of the hydrologic cycle going all the way back to January 2000. Soil moisture plus snowpack is the water storage at any given place. Every month that storage volume changes according to the water flux - recharge occurs when precipitation is high, depletion occurs when evapotranspiration and runoff are higher. Click anywhere on the map to see how a chosen variable has changed over time, and click anywhere on the graph to switch the map to that month of interest. The water balance panel (on the left) shows how much recharge or depletion occurred during your chosen month, and how this compares to what’s normal. The trend analyzer panel (on the right) shows how your chosen variable was different in the same month during other years. Because the model is run with 0.25 degree spatial resolution (~30 km), these data should only be used for regional analysis. A specific farm or other small area might experience very different conditions than the region around it, especially because human influences like irrigation are not included.