The information given in this file pertains to Argonne life-cycle analyses (LCAs) of the plant cycle stage for a set of ten new geothermal scenario pairs, each comprised of a reference and improved case. These analyses were conducted to compare environmental performances among the scenarios and cases. The types of plants evaluated are hydrothermal binary and flash and Enhanced Geothermal Systems (EGS) binary and flash plants. Each scenario pair was developed by the levelized cost of energy (LCOE) group using the Geothermal Electricity Evaluation Model (GETEM) as a way to identify plant operational and resource combinations that could reduce geothermal power plant LCOE values. Based on the specified plant and well field characteristics (plant type, capacity, capacity factor and lifetime, and well numbers and depths) for each case of each pair, Argonne generated a corresponding set of material to power ratios (MPRs) and greenhouse gas and fossil energy ratios.
An Evaluation of the Bell Creek Field Micellar-Polymer Pilot, Report, October 1982
An evaluation of the CO2 pilot Maljamar Field Lea County, New Mexico DOE/BC/10830-12
Der Beratungsbericht zum ÖKS15 Factsheet – Land Salzburg bezieht sich auf Ergebnisse zu den OeKS15 Klimawandelszenarien bis 2100. Dieses umfasst 9 Seiten und enthält sehr umfangreiche Informationen zur Entstehung des Factsheets, verwendeter Methodik, Definitionen, sowie detaillierte Werte zur Lufttemperatur und Jahresniederschlägen. Dieses Informationsblatt wird nun aus psychologischer Perspektive betrachtet um die zu Grunde liegenden psychologischen Prozesse und Theorien präsentieren zu können. Ziel ist es ein für Entscheidungsträger (Bürgermeister, Ärztekammer, Forstvorstand) anschauliches, verständliches Informationsblatt zu kreieren und im Besten Falle einen umweltfreundlichen, verhaltensfördernden Anstoß zu geben.
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).
Evaluation of Nuclear Magnetic Resonance Imaging for Three-Phase Permeability Measurements, Status Report; October 1986
Evaluation of the Bodcau (Bellevue) In Situ Combustion Project, Topical Report, October 1982
Evaluation of the Coalinga Polymer Demonstration Project DOE/SAN/1556-4
Final Report describing data collection, evaluation, modeling and analysis. Ranking of Cascade and Aleutian volcanic centers for geothermal potential.
A binational effort between the United States and Canada is under way to characterize the lowermost aquifer 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, begun in 2011, is being conducted with the goal of determining the potential for geologic storage of carbon dioxide (CO2) in rock formations of the 1.34 million-km2 Cambro-Ordovician saline system (COSS). The focus of this report is to evaluate and discuss geochemical modeling and laboratory studies performed by the Energy & Environmental Research Center to determine potential chemical reactions between CO2, brine, and rock on the portion of the COSS that occurs in North Dakota, Montana, and South Dakota. Although the modeling and laboratory activities were conducted independently, the results of the two different activities were compared to each other to establish a greater understanding of the validity and applicability of the modeling and laboratory approaches. The geochemical modeling study was performed using publicly available PHREEQC software and databases. Rock samples, mineralogy, and water analysis data for both the sandstone injection target and the shale cap rock were also obtained from publicly available sources. The laboratory-based exposure tests entailed exposure of various COSS rock samples to CO2 for 28 days at formation pressure and temperature. The results of the geochemical modeling were consistent with existing literature, and suggested that because most of the COSS comprises quartz-rich sandstone, much of the rock matrix will be nonreactive. Reactions can, however, occur with secondary components (clays, carbonates, micas, K-feldspar) that can be contained within the sandstone and the heterogeneous mixed lithology zones between the primary sand layers. The geochemical modeling study predicted that a geochemical effect from the interaction of CO2 with the COSS minerals and formation water was the dissolution of calcite and concurrent formation of dolomite. The source of Mg2+ for this reaction was either from Mg2+ contained within secondary formation minerals, such as illite, phlogopite, celadonite, and clinochlore, or from Mg2+ in the formation water. The modeling calculations also indicated a potential reaction of the CO2 with illite and K-feldspar in the formation. The K-feldspar was predicted to decompose into quartz, clay, and carbonates, thus trapping the CO2 in a mineral form. vi The results of the laboratory experiments generally compared favorably with the modeling portion of the study. The analytical data generated from the exposed samples show a variable mix of concentrations of K-feldspar and a general trend of decreases in illite. Illite and Kfeldspar behaviors were generally in agreement with the geochemical modeling results. The most significant reactions occurred between CO2 and dolomite/calcite and glauconite in the sandstone. Glauconite contained within samples completely dissolved and decomposed during the exposure experiments. The decomposition of glauconite will form siderite and quartz as well as some ions that will remain in solution. This phenomenon in glauconite-rich areas may increase local permeability as well as provide a mineral-trapping mechanism for CO2. Samples of shale that were exposed to CO2 showed no change in morphology or chemistry, with the exception of halite precipitation. The formation of halite that was seen is most likely an artifact of the samples being dried (not rinsed) after exposure to CO2 and brine solutions. The modeling calculations and laboratory experiments both suggest that CO2 interactions with the COSS mineral phases (reservoir and cap rock) are not detrimental to CO2 storage. Large areal changes in porosity and permeability are not anticipated from the interactions of CO2 with the COSS. Minerals within the COSS that did react with CO2 are typically found in lower concentrations in the quartz-dominated sandstone or within the low-porosity cap rock. Any reactions with the cap rock are not likely to penetrate past the CO2–cap rock interface because of low porosity/permeability. Variations in formation water chemistry, mineral content, and porosity in the COSS can result in large variations in the amount of CO2 that can be trapped. These variations occur both geographically between different areas of the COSS and vertically at each location. Additional focused efforts are needed on both the modeling and rock–CO2 exposure fronts to better understand the potential effects of CO2 storage in the COSS. With respect to future modeling efforts, additional data are necessary for more robust calculations to address the effects of pressure, kinetics, and concentrated brines in the COSS. Laboratory-based CO2 exposure experiments could be improved by implementing more advanced sampling methodologies for highly heterogeneous rocks to ensure that observed differences in chemistry are accurate. Heterogeneity in the rock samples provides for challenging interpretation of results when minute changes in chemistry are observed. Improvements to the CO2 exposure methodology to allow for better detection of minute mineralogical changes within the rock fabric will greatly aid in the refinement of this experimental process.
Plans for Northwest National Marine Renewable Energy Center (NNMREC) Project. Mobile Ocean Test Berth (MOTB) plans PMEC-SETS Plans
Automated auditing tool that allows staff to create and store assignments, workpapers, findings and related audit work. (SORN - 50)
This report describes the current status of the Vertical Electromagnetic Profiling, or VEMP tool, that is on loan to Lawrence Berkeley National Lab (LBNL) from Geothermal Energy Research and Development Co., Ltd. (GERD), Japan. The report describes the initial inspection of the tool by LBNL scientists and engineers, and presents a path forward for it to be used at Utah FORGE.
The Plains CO2 Reduction (PCOR) Partnership performed a wellbore integrity assessment to evaluate the relative leakage potential of 826 wells penetrating the basal Cambrian system in the United States, drilled between 1921 and 2010. The basal Cambrian system is a deep saline reservoir that has been identified by the U.S. Department of Energy as a potential carbon dioxide (CO2) storage site. The ability of the basal Cambrian system to retain injected CO2 over an extended period of time is, in part, dependent on the integrity of wellbores that penetrate the target reservoir. Wellbore integrity is the ability of a well to maintain hydraulic isolation of geologic formations and prevent the vertical migration of fluids (Zhang and Bachu, 2011; Crow and others, 2010). This study’s evaluation of wellbore integrity involves analyzing wellbore characteristics (i.e., cement types, cement additives, completion techniques, well depths, and well casing) to derive a relative leakage potential score using methods similar to Bachu and others (2012). Wells were assigned a classification of minimal, lower, moderate, or higher based on their relative leakage potential. This study provides a screening-level evaluation to compare and rank wells for further detailed evaluation. Site-specific risk analysis within these target areas would trigger a more detailed assessment of those wells identified for further investigation. Potentially leaking or high-risk wells could be addressed using established remediation programs employing current well mitigation technologies or appropriate monitoring during CO2 injection. The results of this regional screening-level evaluation determined that 15% of the wells assessed were classified as moderate or higher potential for deep well leakage, and 6.0% of the wells were classified moderate or higher for shallow well leakage. Of the wells assessed, 3.4% exhibited moderate or higher potential for both shallow and deep leakage. The majority of the moderate- or higher-potential wells are located in western North Dakota and eastern Montana in areas of intensive oil and gas exploration and production. The practice of producing oil and gas from these wells has increased the relative well leakage potential (based on the available data and methods utilized). The ranking of the relative leakage potential provides a mechanism to screen wells for detailed evaluation in areas targeted for CO2 injection.
Geologic and Engineering Analyses and Evaluation of Factors Affecting Widespread Development of Devonian DOE/MC/22140-2651