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All sourcesNASA NTRSDOE OSTI
DOE OSTI2023

Building an EPA Class VI Permit Application

Summary To accelerate the commercialization of carbon capture and storage (CCS), the US Department of Energy (US DOE) is building on decades of characterization efforts and pilot-scale projects through their CarbonSAFE program. Administered through their National Energy Technology Laboratory, this program seeks to bring fully integrated projects to the sector that can store more than 50 million tonnes of CO2 over a 30-year period. The program, which was enacted before the enhancement of Internal Revenue Code Section 45Q, is in the capture assessment, characterization, and permitting phase. The objectives of this paper are to discuss (a) the injection permitting requirements of the CarbonSAFE projects; (b) information gathering in support of the permit; (c) the timelines of field development and permit-related activities; (d) the major technical components of the field development plan; and (e) early feedback from the regulators toward acceptance of the permit. In Mississippi, more than 30,000 acres have been characterized by six deep characterization wells, a deep groundwater well, and 92 line miles of 2D seismic as part of the CarbonSAFE Project ECO2S. During the acquisition of seismic data, all receiver lines were live, which resulted in the generation of a pseudo-3D seismic design. The incorporation of a 3D seismic survey was not included as part of this project due to logistical difficulties presented by the undulating, wooded surface terrain. A suite of openhole geophysical logs was taken from each well, allowing for a detailed interpretation of prospective storage reservoirs and confining intervals to complement the analysis carried out on the 290 ft of a whole core that was cut through the prospective confining zone and storage reservoir. The detailed geologic and reservoir data were assembled and entered into a 3D model to assess the injection capacity and the area of review (AoR). This information fed into the detailed corrective action, monitoring, testing, and postinjection site care (PISC) modeling. The results have been exceptional. The geologic assessment has revealed three primary storage targets, ranging in depth from 3,500 ft to 6,000 ft. These storage reservoirs net 1,300 ft of sandstone, with mean porosity and permeability of 29% and 3.6 darcies, respectively. Together, these reservoirs have storage capacities that may exceed 20 million tonnes per square mile, making this a gigatonne prospect. Forward modeling of the project resulted in an AoR of 16 sq miles, injecting about 8000 t/d, for 30 years, via two deep injection wells. The excellent confining characteristics of the caprock, relatively simple geologic structure, and lack of historical well drilling activity in this area provide excellent containment of the injected CO2. Based on this work, the project has proposed 20 years of PISC. To date, only two US CO2 injection permits have been granted. These projects relied on a singular capture point feeding a singular sequestration point (source to sink), and considerations have not been made to garner CO2 emissions from other industrial sources. The Kemper County Storage Complex is a first-of-its-kind storage hub concept that looks to develop an area capable of storing significant quantities of CO2 from the region. Also, this work will show how characterization efforts, geological and numerical modeling efforts, and plan development were constructed in support of permit and incentives acceptance.

Energy & Fuels↗
DOE OSTI2023

Literature Review and Experimental Observations of the Effects of Salinity, Hardness, Lithology, and ATBS Content on HPAM Polymer Retention for the Milne Point Polymer Flood

Summary At the Milne Point polymer flood (North Slope of Alaska), polymer retention is dominated by the clay, illite. Illite, and kaolinite cause no delay in polymer propagation in Milne Point core material, but they reduce the effective polymer concentration and viscosity by a significant amount (e.g., 30%), thus reducing the efficiency of oil displacement until the full injected polymer concentration is regained [which requires several pore volumes (PVs) of throughput]. This work demonstrates that polymer retention on illite is not sensitive to monovalent ion concentration, but it increases significantly with increased divalent cation concentration. The incorporation of a small percentage of acrylamido tertiary butyl sulfonic acid (ATBS) monomers into hydrolyzed polyacrylamide (HPAM) polymers is shown to dramatically reduce retention. The results are discussed in context with previous literature reports. Bridging adsorption was proposed as a viable mechanism to explain our results. Interestingly, an extensive literature review reveals that polymer retention (on sands and sandstones) is typically only modestly sensitive to the presence of oil. Extensive examination of the literature on inaccessible pore volume (IAPV) suggests the parameter was commonly substantially overestimated, especially in rock/sand more permeable than 500 md (which comprises the vast majority of existing field polymer floods).

Engineering↗
DOE OSTI2023

A Comparative Study of Deep Learning Models for Fracture and Pore Space Segmentation in Synthetic Fractured Digital Rocks

This study focuses on the comparative study of deep learning (DL) models for pore space and discrete fracture networks (DFNs) segmentation in synthetic fractured digital rocks, specifically targeting low-permeability rock formations, such as shale and tight sandstones. Accurate characterization of pore space and DFNs is critical for subsequent property analysis and fluid flow modeling. Four DL models, SegNet, U-Net, U-Net-wide, and nested U-Net (i.e., U-Net++), were trained, validated, and tested using synthetic datasets, including input and label image pairs with varying properties. The model performance was assessed regarding pixel-wise metrics, including the F1 score and pixel-wise difference maps. In addition, the physics-based metrics were considered for further analysis, including sample porosity and absolute permeability. Particularly, We first simulated the permeability of porous media containing only pore space and then simulated the permeability of porous media with DFNs added. The difference between these two values is used to quantify the connectivity of segmented DFNs, which is an important parameter for low-permeability rocks. The pixel-wise metrics showed that the nested U-Net model outperformed the rest of the DL models in pore space and DFNs segmentation, with the SegNet model exhibiting the second-best performance. Particularly, nested U-Net enhanced segmentation accuracy for challenging boundary pixels affected by partial volume effects. The U-Net-wide model achieved improved accuracy compared to the U-Net model, which indicated the influence of parameter numbers. Similarly, nested U-Net has the closest match to the ground truth of physics-based metrics, including the porosity of pore space and DFNs, and the permeability difference quantifying the connectivity of DFNs. The findings highlight the effectiveness of DL models, especially the U-Net++ model with nested architecture and redesigned skip connections, in accurately segmenting pore spaces and DFNs, which are crucial for pore-scale fluid flow and transport simulation in low-permeability rocks.

Wang, Hongsheng↗
DOE OSTI2024

Comparative Assessment of U-Net-Based Deep Learning Models for Segmenting Microfractures and Pore Spaces in Digital Rocks

Segmentation of high-resolution X-ray microcomputed tomography (µCT) images is crucial in digital rock physics (DRP), affecting the characterization and analysis of microscale phenomena in the porous media. The complexity of geological structures and nonideal scanning conditions pose significant challenges to conventional image segmentation approaches. Motivated by the recent increasing popularity of deep learning (DL) techniques in image processing, this work undertakes a comparative study of DL models, specifically U-Net and its variants, for segmenting multiple targets with distinguished features in digital rocks, including discrete fracture networks (DFNs), pore spaces, and solid rock. Particularly, DFNs have a smaller volumetric fraction over others, bringing in a substantial challenge of imbalanced segmentation. The primary focus is to evaluate the architecture and feature enhancement strategies of various DL models, including U-Net, attention U-Net, residual U-Net, U-Net++, and residual U-Net++. The models were designed as 2.5D, utilizing a central 2D image and its two adjacent upper and lower 2D images as input to provide a pseudo-3D context. In addition, because the ground truth of segmentation was unknown for real-world digital rocks, we created a benchmark data set following the inverse operations of segmentation. The data synthesis started from the label images (i.e., solid rock, pore spaces, and DFNs), followed by simulating partial volume blurring, adding random background noise, and introducing ring artifacts to mimic real raw X-ray µCT images. The data set, which included various rock types (i.e., sandstone and artificial data), scanning resolution, and magnitudes of noise and artifacts, was divided into training and testing data sets with a 90% and 10% ratio, respectively. Moreover, in addition to the conventional pixel-wise evaluation metrics, the physics-based metric of the lattice-Boltzmann method (LBM) simulated permeability provided more comprehensive assessments. The results demonstrated that the residual connections, nested architectures, and redesigned skip connections contribute to the model performance and give the residual U-Net++ the highest accuracy. The improvements were mainly on the boundaries and small targets, especially the DFNs, which dominate the interconnectivity and therefore affect the permeability greatly. This study also rigorously evaluated the efficiency and generalization of each model, demonstrating that the sophisticated architectures achieved excellent practicability and maintained robust performance on completely unseen data, ensuring their suitability for diverse and challenging DRP applications.

58 GEOSCIENCES↗
DOE OSTI2018

Results of CO2 Storage Efficiency in Deep Saline Formations – Stage 2

Conference paper presented at 14th International Conference on Greenhouse Gas Control Technologies (GHGT-14), Melbourne, Australia, October 12–25, 2018. Previous dynamic simulations indicate that it may take hundreds of years and an unrealistic number of wells to approach a static volumetrically derived estimate of storage capacity and efficiency for an actual large-scale CO 2 storage development. This study shows how efficiency factors may be influenced by key parameters of practical project development, such as a 50-year injection period, number of wells and drilling sequence, onshore vs. offshore conditions, and increasing unit storage cost as development intensifies. Two potential storage formations were investigated: the Minnelusa Formation of the Powder River Basin and the Bunter Sandstone of the North Sea Basin.

58 GEOSCIENCES↗
DOE OSTI2018

Integrated Geologic Storage Prefeasibility Study Proximal to Dry Fork Power Station, Powder River Basin, Wyoming

The pre-feasibility study—funded by the Department of Energy CarbonSAFE program (DE-FE0029375)—is centred around Basin Electric’s Dry Fork Station (DFS) in Wyoming’s Powder River Basin. Dry Fork Station, completed in 2011, is a high efficient coal-fired power plant that emits 3.3 million tons of CO2 per annum. The DFS site also host’s the Wyoming Integrated Test Center (ITC) funded by a $15 million investment by the State of Wyoming. The ITC is a public-private partnership test bed for CCS technologies. Geologic storage sites are in immediate vicinity of the DFS providing significant opportunities for co-located source and saline storage. The Powder River Basin (PRB) of Wyoming and Montana, was identified by NETL (2010) as having a “high potential” for commercial-scale carbon sequestration. The basin contains as much as 17,000 feet of sedimentary rock and covers an area of approximately 24,000 square miles. The PRB has a long history of hydrocarbon production and remaining undiscovered reserves. Accumulations and production of hydrocarbons in the basin indicate the presence of reservoir formations with significant pore volumes and impermeable sealing formations. This attribute alone suggests the reservoir and seal characteristics of the formations provide significant opportunities for CO₂ storage in saline reservoirs. Four high quality potential reservoir and sealing complexes have been identified for geologic storage. These formations range in depth from 6,500-9,500 feet underneath DFS including: (1) the Pennsylvanian Minnelusa Formation reservoir and Permian Goose Egg Formation (Opeche Shale) seal; (2) the Jurassic Hulett and Canyon Springs Sandstones of the Sundance Formation sealed by the Late Jurassic Upper Sundance Member and Morrison Formation and (3) the Early Cretaceous Lakota and Dakota, and Muddy Formation reservoirs sealed by the Mowry Shale. The preliminary reservoir characterization results integrate data from petrophysical well logs, core measurements, faults/fractures analysis, artificial penetrations, and published literature to evaluate geologic storage capacity and potential risk, for the Powder River Basin. These reservoir and seal combinations reside within ideal depth constraints and show suitable reservoir and seal characteristics conducive to commercial-scale storage. Specifically, this paper presents 1) high level description of the geologic storage complex 2) a first order risk analysis associated with pre-existing oil and gas wells, and 3) preliminary storage capacity and Area of Review estimates.

Quillinan, Scott↗
DOE OSTI2011

LLNL Input to SNL L2 MS: Report on the Basis for Selection of Disposal Options

This mid-year deliverable has two parts. The first part is a synopsis of J. Blink's interview of the former Nevada Attorney General, Frankie Sue Del Papa, which was done in preparation for the May 18-19, 2010 Legal and Regulatory Framework Workshop held in Albuquerque. The second part is a series of sections written as input for the SNL L2 Milestone M21UF033701, due March 31, 2011. Disposal of high-level radioactive waste is categorized in this review into several categories. Section II discusses alternatives to geologic disposal: space, ice-sheets, and an engineered mountain or mausoleum. Section III discusses alternative locations for mined geologic disposal: islands, coastlines, mid-continent, and saturated versus unsaturated zone. Section IV discusses geologic disposal alternatives other than emplacement in a mine: well injection, rock melt, sub-seabed, and deep boreholes in igneous or metamorphic basement rock. Finally, Secton V discusses alternative media for mined geologic disposal: basalt, tuff, granite and other igneous/metamorphic rock, alluvium, sandstone, carbonates and chalk, shale and clay, and salt.

11 NUCLEAR FUEL CYCLE AND FUEL MATERIALS↗
DOE OSTI2011

The Natural Enrichment of Stable Cesium in Weathered Micaceous Materials and Its Implications for 137Cs Sorption.

In this exploratory project, we are testing two interrelated hypotheses about the sorption of Cs within weathered micaceous materials in subsurface regolith materials from the Savannah River Site (SRS) located on the Atlantic Coastal Plain: 1) that stable cesium has become significantly enriched relative to potassium in subsurface micaceous particles as a result of chemical weathering processes; and 2) that the Cs so present is sufficient to be a major factor determining the ability of the subsurface materials to take up and hold 137 Cs. To test these hypotheses, we collected by hand augur soil samples corresponding to soils representative at the SRS: upland regolith (Fuquay series); soils formed on Tobacco Road Sandstone; and, soils formed on Quaternary Alluvium. From our data, the quantification of the amounts of stable cesium concentrated in various sites within 2:1 phyllosilicates by natural processes is highly relevant toward understanding the future sorption of 137 Cs by the mica, illite, vermiculite, and hydroxyl interstratified vermiculite (HIV) phases present in the subsurface at and in proximity to SRS. Studying sorption and fixation of Cs in these micaceous phases interlayers potentially leads to increased knowledge to the extent that stable Cs resists exchange with ion exchange cations (Mg, NH4, or even alkyl ammonium compounds) and to the extent that Cs can become fixed over the long term. Such knowledge will help in the development of 137 Cs remediation strategies for the long-term, which is a critical aspect of the SBR goals. We characterized the mineralogy, K-Ar ages of the soil and soil clay fractions (before and after acid treatment), and alkali element chemistry (K, Rb, Cs) of the clay fractions of soils collected from these three different types of soils. The clay fractions of the Fuquay soils are composed of kaolinite, and hydroxy interstratified vermiculite (HIV). Kaolinite, HIV, quartz, gibbsite and illite are found in the quaternary soils. Leach experiments using 10% nitric acid and 50% nitric acid were performed on 62 mesh fractions to show the amounts of Cs and Rb relative to K (Cs/K, Rb/K) that are exchangeable in these soils compared to Coastal Plain micas and upper continental crust. The Cs/K and Rb/K of the leachates are considerably higher relative to both upper continental crust and relative to weathered micas found in Georgia Coast Plain sediments. The K-Ar ages of the clay fractions of five different SRS soil series were ca. 320 Ma. After leaching with nitric acid, the ages of the soil clay fractions were approximately the same as the unleached soil clays. Based on the similarity of these ages to the ages of Coastal Plain micas, the K and Ar remaining after treatment is believed to be enclosed in a relect mica in the HIV phases in the soils. The HIV is likely a mica-HIV intergrade. Based on these data, stable cesium has become significantly enriched relative to potassium in subsurface micaceous particles as a result of chemical weathering processes in the SRS Fuquay soils studied thus far. Our data permit the interpretation describing the sorption of Cs and Rb in an apex site or in a hard to reach hard-to-exchange sorption site during pedogenesis. In terms of testing the second hypothesis, our work is ongoing and we report some preliminary data on Cs-137 and Rb-85 exchange experiments on select SRS Fuquay soils (-2 mm). Our isotopic equilibration experiments using Cs and Rb isotopes in separate exchange experiments show only small amounts of Cs and Rb in the original sample is exchangeable isotopically for a period of a few weeks in acidified conditions. The isotope exchange experiments provide support for our interpretation that pedogenically accumulated Cs (and Rb) occupy sites that are unavailable to exchange or exchange slowly in acid conditions corresponding to present conditions in SRS soils. In more basic solutions, greater exchange isotopic exchange is noted and suggests an expansion of interlayer sites thereby permitting more isotopic exchange of Cs and Rb.

12 MANAGEMENT OF RADIOACTIVE AND NON-RADIOACTIVE W↗
DOE OSTI2012

Reduction of Non-CO2 Gas Emissions Through The In Situ Bioconversion of Methane

The primary objectives of this research were to seek previously unidentified anaerobic methanotrophs and other microorganisms to be collected from methane seeps associated with coal outcrops. Subsurface application of these microbes into anaerobic environments has the potential to reduce methane seepage along coal outcrop belts and in coal mines, thereby preventing hazardous explosions. Depending upon the types and characteristics of the methanotrophs identified, it may be possible to apply the microbes to other sources of methane emissions, which include landfills, rice cultivation, and industrial sources where methane can accumulate under buildings. Finally, the microbes collected and identified during this research also had the potential for useful applications in the chemical industry, as well as in a variety of microbial processes. Sample collection focused on the South Fork of Texas Creek located approximately 15 miles east of Durango, Colorado. The creek is located near the subsurface contact between the coal-bearing Fruitland Formation and the underlying Pictured Cliffs Sandstone. The methane seeps occur within the creek and in areas adjacent to the creek where faulting may allow fluids and gases to migrate to the surface. These seeps appear to have been there prior to coalbed methane development as extensive microbial soils have developed. Our investigations screened more than 500 enrichments but were unable to convince us that anaerobic methane oxidation (AMO) was occurring and that anaerobic methanotrophs may not have been present in the samples collected. In all cases, visual and microscopic observations noted that the early stage enrichments contained viable microbial cells. However, as the levels of the readily substrates that were present in the environmental samples were progressively lowered through serial transfers, the numbers of cells in the enrichments sharply dropped and were eliminated. While the results were disappointing we acknowledge that anaerobic methane oxidizing (AOM) microorganisms are predominantly found in marine habitats and grow poorly under most laboratory conditions. One path for future research would be to use a small rotary rig to collect samples from deeper soil horizons, possibly adjacent to the coal-bearing horizons that may be more anaerobic.

01 COAL, LIGNITE, AND PEAT↗
DOE OSTI2012

Bridging the Gap between Chemical Flooding and Independent Oil Producers

Ten Kanas oil reservoirs/leases were studied through geological and engineering analysis to assess the potential performance of chemical flooding to recover oil. Reservoirs/leases that have been efficiently waterflooded have the highest performance potential for chemical flooding. Laboratory work to identify efficient chemical systems and to test the oil recovery performance of the systems was the major effort of the project. Efficient chemical systems were identified for crude oils from nine of the reservoirs/leases. Oil recovery performance of the identified chemical systems in Berea sandstone rocks showed 90 + % recoveries of waterflood residual oil for seven crude oils. Oil recoveries increased with the amount of chemical injected. Recoveries were less in Indiana limestone cores. One formulation recovered 80% of the tertiary oil in the limestone rock. Geological studies for nine of the oil reservoirs are presented. Pleasant Prairie, Trembley, Vinland and Stewart Oilfields in Kansas were the most favorable of the studied reservoirs for a pilot chemical flood from geological considerations. Computer simulations of the performance of a laboratory coreflood were used to predict a field application of chemical flooding for the Trembley Oilfield. Estimates of field applications indicated chemical flooding is an economically viable technology for oil recovery.

02 PETROLEUM↗
DOE OSTI2011

Conceptual Model Summary Report Simulation Framework for Regional Geologic CO 2 Storage Along Arches Province of Midwestern United States

A conceptual model was developed for the Arches Province that integrates geologic and hydrologic information on the Eau Claire and Mt. Simon formations into a geocellular model. The conceptual model describes the geologic setting, stratigraphy, geologic structures, hydrologic features, and distribution of key hydraulic parameters. The conceptual model is focused on the Mt. Simon sandstone and Eau Claire formations. The geocellular model depicts the parameters and conditions in a numerical array that may be imported into the numerical simulations of carbon dioxide (CO 2 ) storage. Geophysical well logs, rock samples, drilling logs, geotechnical test results, and reservoir tests were evaluated for a 500,000 km2 study area centered on the Arches Province. The geologic and hydraulic data were integrated into a three-dimensional (3D) grid of porosity and permeability, which are key parameters regarding fluid flow and pressure buildup due to CO 2 injection. Permeability data were corrected in locations where reservoir tests have been performed in Mt. Simon injection wells. The final geocellular model covers an area of 600 km by 600 km centered on the Arches Province. The geocellular model includes a total of 24,500,000 cells representing estimated porosity and permeability distribution. CO 2 injection scenarios were developed for on-site and regional injection fields at rates of 70 to 140 million metric tons per year.

54 ENVIRONMENTAL SCIENCES↗
DOE OSTI2012

Bridging the Gap between Chemical Flooding and Independent Oil Producers

Ten Kanas oil reservoirs/leases were studied through geological and engineering analysis to assess the potential performance of chemical flooding to recover oil. Reservoirs/leases that have been efficiently waterflooded have the highest performance potential for chemical flooding. Laboratory work to identify efficient chemical systems and to test the oil recovery performance of the systems was the major effort of the project. Efficient chemical systems were identified for crude oils from nine of the reservoirs/leases. Oil recovery performance of the identified chemical systems in Berea sandstone rocks showed 90+ % recoveries of waterflood residual oil for seven crude oils. Oil recoveries increased with the amount of chemical injected. Recoveries were less in Indiana limestone cores. One formulation recovered 80% of the tertiary oil in the limestone rock. Geological studies for nine of the oil reservoirs are presented. Pleasant Prairie, Trembley, Vinland and Stewart Oilfields in Kansas were the most favorable of the studied reservoirs for a pilot chemical flood from geological considerations. Computer simulations of the performance of a laboratory coreflood were used to predict a field application of chemical flooding for the Trembley Oilfield. Estimates of field applications indicated chemical flooding is an economically viable technology for oil recovery.

02 PETROLEUM↗
DOE OSTI2012

Multiscale framework for predicting the coupling between deformation and fluid diffusion in porous rocks

In this project, a predictive multiscale framework will be developed to simulate the strong coupling between solid deformations and fluid diffusion in porous rocks. We intend to improve macroscale modeling by incorporating fundamental physical modeling at the microscale in a computationally efficient way. This is an essential step toward further developments in multiphysics modeling, linking hydraulic, thermal, chemical, and geomechanical processes. This research will focus on areas where severe deformations are observed, such as deformation bands, where classical phenomenology breaks down. Multiscale geometric complexities and key geomechanical and hydraulic attributes of deformation bands (e.g., grain sliding and crushing, and pore collapse, causing interstitial fluid expulsion under saturated conditions), can significantly affect the constitutive response of the skeleton and the intrinsic permeability. Discrete mechanics (DEM) and the lattice Boltzmann method (LBM) will be used to probe the microstructure---under the current state---to extract the evolution of macroscopic constitutive parameters and the permeability tensor. These evolving macroscopic constitutive parameters are then directly used in continuum scale predictions using the finite element method (FEM) accounting for the coupled solid deformation and fluid diffusion. A particularly valuable aspect of this research is the thorough quantitative verification and validation program at different scales. The multiscale homogenization framework will be validated using X-ray computed tomography and 3D digital image correlation in situ at the Advanced Photon Source in Argonne National Laboratories. Also, the hierarchical computations at the specimen level will be validated using the aforementioned techniques in samples of sandstone undergoing deformation bands.

58 GEOSCIENCES↗
DOE OSTI2012

CO 2 Storage and Enhanced Oil Recovery: Bald Unit Test Site, Mumford Hills Oil Field, Posey County, Indiana

The Midwest Geological Sequestration Consortium (MGSC) carried out a small-scale carbon dioxide (CO 2 ) injection test in a sandstone within the Clore Formation (Mississippian System, Chesterian Series) in order to gauge the large-scale CO 2 storage that might be realized from enhanced oil recovery (EOR) of mature Illinois Basin oil fields via miscible liquid CO 2 flooding.

02 PETROLEUM↗
DOE OSTI2012

Summary of Carbon Storage Project Public Information Meeting and Open House

The Kentucky Geological Survey (KGS) completed a second phase of carbon dioxide (CO 2 ) injection and seismic imaging in the Knox Group, a Cambrian Ordovician dolomite and sandstone sequence in September 2010. This work completed 2 years of activity at the KGS No. 1 Marvin Blan well in Hancock County, Kentucky. The well was drilled in 2009 by a consortium of State and industry partners (Kentucky Consortium for Carbon Storage). An initial phase of CO 2 injection occurred immediately after completion of the well in 2009. The second phase of injection and seismic work was completed in September 2010 as part of a U.S. DOE funded project, after which the Blan well was plugged and abandoned. Following completion of research at the Blan well, a final public meeting and open house was held in Hancock County on October 28, 2010. This meeting followed one public meeting held prior to drilling of the well, and two on site visits during drilling (one for news media, and one for school teachers). The goal of the final public meeting was to present the results of the project to the public, answer questions, and address any concerns. Despite diligent efforts to publicize the final meeting, it was poorly attended by the general public. Several local county officials and members of the news media attended, but only one person from the general public showed up. We attribute the lack of interest in the results of the project to several factors. First, the project went as planned, with no problems or incidents that affected the local residents. The fact that KGS fulfilled the promises it made at the beginning of the project satisfied residents, and they felt no need to attend the meeting. Second, Hancock County is largely rural, and the technical details of carbon sequestration were not of interest to many people. The county officials attending were an exception; they clearly realized the importance of the project in future economic development for the county.

29 ENERGY PLANNING, POLICY, AND ECONOMY↗
DOE OSTI2013

Up-Scaling Geochemical Reaction Rates for Carbon Dioxide (CO2) in Deep Saline Aquifers

Geochemical reactions in deep subsurface environments are complicated by the consolidated nature and mineralogical complexity of sedimentary rocks. Understanding the kinetics of these reactions is critical to our ability to make long-term predictions about subsurface processes such as pH buffering, alteration in rock structure, permeability changes, and formation of secondary precipitates. In this project, we used a combination of experiments and numerical simulation to bridge the gap between our knowledge of these reactions at the lab scale and rates that are meaningful for modeling reactive transport at core scales. The focus is on acid-driven mineral dissolution, which is specifically relevant in the context of CO 2 -water-rock interactions in geological sequestration of carbon dioxide. The project led to major findings in three areas. First, we modeled reactive transport in pore-network systems to investigate scaling effects in geochemical reaction rates. We found significant scaling effects when CO 2 concentrations are high and reaction rates are fast. These findings indicate that the increased acidity associated with geological sequestration can generate conditions for which proper scaling tools are yet to be developed. Second, we used mathematical modeling to investigate the extent to which SO 2 , if co-injected with CO 2 , would acidify formation brines. We found that there exist realistic conditions in which the impact on brine acidity will be limited due to diffusion rate-limited SO 2 dissolution from the CO 2 phase, and the subsequent pH shift may also be limited by the lack of availability of oxidants to produce sulfuric acid. Third, for three Viking sandstones (Alberta sedimentary basin, Canada), we employed backscattered electron microscopy and energy dispersive X-ray spectroscopy to statistically characterize mineral contact with pore space. We determined that for reactive minerals in sedimentary consolidated rocks, abundance alone is not a good predictor of mineral accessible surface area, and should not be used in reactive transport modeling. Our work showed that reaction rates would be overestimated by three to five times.

58 GEOSCIENCES↗
DOE OSTI2013

Seismic Technology Adapted to Analyzing and Developing Geothermal Systems Below Surface-Exposed High-Velocity Rocks Final Report

The objective of our research was to develop and demonstrate seismic data-acquisition and data-processing technologies that allow geothermal prospects below high-velocity rock outcrops to be evaluated. To do this, we acquired a 3-component seismic test line across an area of exposed high-velocity rocks in Brewster County, Texas, where there is high heat flow and surface conditions mimic those found at numerous geothermal prospects. Seismic contractors have not succeeded in creating good-quality seismic data in this area for companies who have acquired data for oil and gas exploitation purposes. Our test profile traversed an area where high-velocity rocks and low-velocity sediment were exposed on the surface in alternating patterns that repeated along the test line. We verified that these surface conditions cause non-ending reverberations of Love waves, Rayleigh waves, and shallow critical refractions to travel across the earth surface between the boundaries of the fast-velocity and slow-velocity material exposed on the surface. These reverberating surface waves form the high level of noise in this area that does not allow reflections from deep interfaces to be seen and utilized. Our data-acquisition method of deploying a box array of closely spaced geophones allowed us to recognize and evaluate these surface-wave noise modes regardless of the azimuth direction to the surface anomaly that backscattered the waves and caused them to return to the test-line profile. With this knowledge of the surface-wave noise, we were able to process these test-line data to create P-P and SH-SH images that were superior to those produced by a skilled seismic data-processing contractor. Compared to the P-P data acquired along the test line, the SH-SH data provided a better detection of faults and could be used to trace these faults upward to the boundaries of exposed surface rocks. We expanded our comparison of the relative value of S-wave and P-wave seismic data for geothermal applications by inserting into this report a small part of the interpretation we have done with 3C3D data across Wister geothermal field in the Imperial Valley of California. This interpretation shows that P-SV data reveal faults (and by inference, also fractures) that cannot be easily, or confidently, seen with P-P data, and that the combination of P-P and P-SV data allows VP/VS velocity ratios to be estimated across a targeted reservoir interval to show where an interval has more sandstone (the preferred reservoir facies). The conclusion reached from this investigation is that S-wave seismic technology can be invaluable to geothermal operators. Thus we developed a strong interest in understanding the direct-S modes produced by vertical-force sources, particularly vertical vibrators, because if it can be demonstrated that direct-S modes produced by vertical-force sources can be used as effectively as the direct-S modes produced by horizontal-force sources, geothermal operators can acquire direct-S data across many more prospect areas than can be done with horizontal-force sources, which presently are limited to horizontal vibrators. We include some of our preliminary work in evaluating direct-S modes produced by vertical-force sources.

15 GEOTHERMAL ENERGY↗
DOE OSTI2013

Generation II Reduced Order Models for Groundwater Impacts due to CO 2 and Brine leakage

This report describes the development of reduced-order models (ROMs) describing time-evolution of shallow groundwater impacts due to CO 2 leaks. These ROMs were designed to be subcomponents of a systems-level model being developed by the National Risk Assessment Project. Our work is meant to represent a particular class of groundwater systems: unconfined carbonate aquifers. While actual response of a particular aquifer to a CO 2 leak would be affected by complex hydrogeologic and geochemical processes, the analyses presented in this report considered complex hydrogeology but only simple geochemistry. Complimentary studies were performed at PNNL, emphasizing complex geochemistry and relatively simple (2-D) hydrogeology. Separation of these tasks was necessary due to the computational burden of simulating all the necessary processes in a single model. Similar studies are being performed at LBNL and LLNL to represent a class of confined, sandstone aquifers.

54 ENVIRONMENTAL SCIENCES↗