Sample records for initiates co2 injection

  1. Coupled reservoir-geomechanical analysis of CO2 injection and ground deformations at In Salah, Algeria

    E-Print Network [OSTI]

    Rutqvist, J.

    2010-01-01T23:59:59.000Z

    CO 2 sequestration; In Salah; geomechanics; ground surfaceCO 2 injection, geomechanics, and ground surface

  2. DOE Partner Begins Injecting 50,000 Tons of CO2 in Michigan Basin

    Broader source: Energy.gov [DOE]

    Building on an initial injection project of 10,000 metric tons of carbon dioxide into a Michigan geologic formation, a U.S. Department of Energy team of regional partners has begun injecting 50,000 additional tons into the formation, which is believed capable of storing hundreds of years worth of CO2, a greenhouse gas that contributes to climate change.

  3. Continuous active-source seismic monitoring of CO2 injection in a brine aquifer

    E-Print Network [OSTI]

    Daley, Thomas M.; Solbau, Ray D.; Ajo-Franklin, Jonathan B.; Benson, Sally M.

    2008-01-01T23:59:59.000Z

    INTERPRETATION The injection of CO 2 causes a decrease in seismicseismic monitoring during injection. Although quantitative interpretation

  4. USING TIME-LAPSE SEISMIC MEASUREMENTS TO IMPROVE FLOW MODELING OF CO2 INJECTION

    E-Print Network [OSTI]

    Marly. The EOR process in the RCP section of the Weyburn Field uses CO2 and water injection to displaceUSING TIME-LAPSE SEISMIC MEASUREMENTS TO IMPROVE FLOW MODELING OF CO2 INJECTION IN THE WEYBURN, particularly CO2. Time lapse seismic monitoring has motivated changes to the reservoir description in a flow

  5. 9,997,638 Metric Tons of CO2 Injected as of April 9, 2015 | Department...

    Broader source: Energy.gov (indexed) [DOE]

    This carbon dioxide (CO2) has been injected in the United States as part of DOE's Clean Coal Research, Development, and Demonstration Programs. One million metric tons of CO2 is...

  6. 9,805,742 Metric Tons of CO2 Injected as of February 27, 2015...

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    This carbon dioxide (CO2) has been injected in the United States as part of DOE's Clean Coal Research, Development, and Demonstration Programs. One million metric tons of CO2 is...

  7. 9,981,117 Metric Tons of CO2 Injected as of April 2, 2015 | Department...

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    This carbon dioxide (CO2) has been injected in the United States as part of DOE's Clean Coal Research, Development, and Demonstration Programs. One million metric tons of CO2 is...

  8. 9,355,469 Metric Tons of CO2 Injected as of January 29, 2015...

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    This carbon dioxide (CO2) has been injected in the United States as part of DOE's Clean Coal Research, Development, and Demonstration Programs. One million metric tons of CO2 is...

  9. 9,449,421 Metric Tons of CO2 Injected as of February 12, 2015...

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    This carbon dioxide (CO2) has been injected in the United States as part of DOE's Clean Coal Research, Development, and Demonstration Programs. One million metric tons of CO2 is...

  10. 10,045,885 Metric Tons of CO2 Injected as of April 16, 2015

    Broader source: Energy.gov [DOE]

    This carbon dioxide (CO2) has been injected in the United States as part of DOE’s Clean Coal Research, Development, and Demonstration Programs. One million metric tons of CO2 is equivalent to the...

  11. 10,180,047 Metric Tons of CO2 Injected as of May 28, 2015 | Department...

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    This carbon dioxide (CO2) has been injected in the United States as part of DOE's Clean Coal Research, Development, and Demonstration Programs. One million metric tons of CO2 is...

  12. Area 2: Inexpensive Monitoring and Uncertainty Assessment of CO2 Plume Migration using Injection Data

    SciTech Connect (OSTI)

    Srinivasan, Sanjay

    2014-09-30T23:59:59.000Z

    In-depth understanding of the long-term fate of CO2 in the subsurface requires study and analysis of the reservoir formation, the overlaying caprock formation, and adjacent faults. Because there is significant uncertainty in predicting the location and extent of geologic heterogeneity that can impact the future migration of CO2 in the subsurface, there is a need to develop algorithms that can reliably quantify this uncertainty in plume migration. This project is focused on the development of a model selection algorithm that refines an initial suite of subsurface models representing the prior uncertainty to create a posterior set of subsurface models that reflect injection performance consistent with that observed. Such posterior models can be used to represent uncertainty in the future migration of the CO2 plume. Because only injection data is required, the method provides a very inexpensive method to map the migration of the plume and the associated uncertainty in migration paths. The model selection method developed as part of this project mainly consists of assessing the connectivity/dynamic characteristics of a large prior ensemble of models, grouping the models on the basis of their expected dynamic response, selecting the subgroup of models that most closely yield dynamic response closest to the observed dynamic data, and finally quantifying the uncertainty in plume migration using the selected subset of models. The main accomplishment of the project is the development of a software module within the SGEMS earth modeling software package that implements the model selection methodology. This software module was subsequently applied to analyze CO2 plume migration in two field projects – the In Salah CO2 Injection project in Algeria and CO2 injection into the Utsira formation in Norway. These applications of the software revealed that the proxies developed in this project for quickly assessing the dynamic characteristics of the reservoir were highly efficient and yielded accurate grouping of reservoir models. The plume migration paths probabilistically assessed by the method were confirmed by field observations and auxiliary data. The report also documents the application of the software to answer practical questions such as the optimum location of monitoring wells to reliably assess the migration of CO2 plume, the effect of CO2-rock interactions on plume migration and the ability to detect the plume under those conditions and the effect of a slow, unresolved leak on the predictions of plume migration.

  13. CO2 Injection in the Subsurface Kjetil Haugen

    E-Print Network [OSTI]

    Firoozabadi, Abbas

    fuel. Nevertheless, natural gas combustion results in sub- stantial quantities of CO2. Instead Warming Fossil fuels produce CO2 upon combustion. CO2 is a greenhouse gas and contributes to global warm. Thus, replacing oil and coal with less carbon-intensive natural gas, is probably the fastest way

  14. 9,959,066 Metric Tons of CO2 Injected as of March 26, 2015 |...

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    210,526 passenger vehicles. The projects currently injecting CO2 within DOE's Regional Carbon Sequestration Partnership Program and the Major Demonstration Program are detailed...

  15. 9,932,381 Metric Tons of CO2 Injected as of March 18, 2015 |...

    Office of Environmental Management (EM)

    210,526 passenger vehicles. The projects currently injecting CO2 within DOE's Regional Carbon Sequestration Partnership Program and the Major Demonstration Program are detailed...

  16. 9,894,105 Metric Tons of CO2 Injected as of March 12, 2015 |...

    Broader source: Energy.gov (indexed) [DOE]

    210,526 passenger vehicles. The projects currently injecting CO2 within DOE's Regional Carbon Sequestration Partnership Program and the Major Demonstration Program are detailed...

  17. Numerical simulations of the thermal impact of supercritical CO2 injection on chemical

    E-Print Network [OSTI]

    Boyer, Edmond

    in a carbonate saline reservoir Laurent André, Mohamed Azaroual, André Menjoz BRGM ­ Water Division - 3 Avenue 64 37 19 Email : l.andre@brgm.fr www.brgm.fr Abstract Geological sequestration of CO2 offers, investigates thermal effects during CO2 injection into a deep carbonate formation. Different thermal processes

  18. Estimating maximum sustainable injection pressure during geological sequestration of CO2 using coupled fluid flow and

    E-Print Network [OSTI]

    Vallée, Martin

    coupled fluid flow and geomechanical fault-slip analysis J. Rutqvist *, J. Birkholzer, F. Cappa, C demonstrates the use of coupled fluid flow and geomechanical fault slip (fault reactivation) analysis: Geological CO2 sequestration; geomechanics; Fault slip; Stress; Caprock integrity; CO2 injection 1

  19. Modeling of coulpled deformation and permeability evolution during fault reactivation induced by deep underground injection of CO2

    E-Print Network [OSTI]

    Cappa, F.

    2010-01-01T23:59:59.000Z

    L.K,  2000.   Fully  Coupled  Geomechanics  and  Fluid?Flow CO 2   injection,  geomechanics,  and  ground?surface 

  20. CO2 Injection Begins in Illinois | Department of Energy

    Broader source: Energy.gov (indexed) [DOE]

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative1 First Use of Energy for All Purposes (Fuel and Nonfuel), 2002; Level: National5Sales for4,645 3,625 1,006 492 742Energy China U.S. Department ofJune 2,The BigSidingState6Report, March003MEAM,ofCO2 Heat

  1. CO2 Injection in Kansas Oilfield Could Greatly Increase Production,

    Broader source: Energy.gov (indexed) [DOE]

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative1 First Use of Energy for All Purposes (Fuel and Nonfuel), 2002; Level: National5Sales for4,645 3,625 1,006 492 742Energy China U.S. Department ofJune 2,The BigSidingState6Report, March003MEAM,ofCO2

  2. MathematicalModelingofCarbonDioxide(CO2)Injection intheSubsurfaceforImprovedHydrocarbonRecoveryand

    E-Print Network [OSTI]

    Firoozabadi, Abbas

    MathematicalModelingofCarbonDioxide(CO2)Injection intheSubsurfaceforImprovedHydrocarbonRecoveryand Sequestration Philip C. Myint, Laurence Rongy, Kjetil B. Haugen, Abbas Firoozabadi Department of Chemical injection for two applications: 1) improved recovery from hydrocarbon reservoirs and 2) sequestration

  3. Impact of porous medium desiccation during anhydrous CO2 injection in deep saline aquifers: up scaling from experimental

    E-Print Network [OSTI]

    Boyer, Edmond

    flow rate and capillary properties on the desiccation mechanisms. Keywords: supercritical CO2, dryingImpact of porous medium desiccation during anhydrous CO2 injection in deep saline aquifers: up - France Abstract Injection of CO2 in geological reservoirs or deep aquifers is nowadays studied

  4. Geologic Carbon Sequestration: Mitigating Climate Change by Injecting CO2 Underground

    SciTech Connect (OSTI)

    Oldenburg

    2009-07-30T23:59:59.000Z

    July 21, 2009 Berkeley Lab summer lecture: Climate change provides strong motivation to reduce CO2 emissions from the burning of fossil fuels. Carbon dioxide capture and storage involves the capture, compression, and transport of CO2 to geologically favorable areas, where its injected into porous rock more than one kilometer underground for permanent storage. Oldenburg, who heads Berkeley Labs Geologic Carbon Sequestration Program, will focus on the challenges, opportunities, and research needs of this innovative technology.

  5. Geologic Carbon Sequestration: Mitigating Climate Change by Injecting CO2 Underground (LBNL Summer Lecture Series)

    SciTech Connect (OSTI)

    Oldenburg, Curtis M. (LBNL Earth Sciences Division) [LBNL Earth Sciences Division

    2009-07-21T23:59:59.000Z

    Summer Lecture Series 2009: Climate change provides strong motivation to reduce CO2 emissions from the burning of fossil fuels. Carbon dioxide capture and storage involves the capture, compression, and transport of CO2 to geologically favorable areas, where its injected into porous rock more than one kilometer underground for permanent storage. Oldenburg, who heads Berkeley Labs Geologic Carbon Sequestration Program, will focus on the challenges, opportunities, and research needs of this innovative technology.

  6. Geologic Carbon Sequestration: Mitigating Climate Change by Injecting CO2 Underground (LBNL Summer Lecture Series)

    ScienceCinema (OSTI)

    Oldenburg, Curtis M [LBNL Earth Sciences Division

    2011-04-28T23:59:59.000Z

    Summer Lecture Series 2009: Climate change provides strong motivation to reduce CO2 emissions from the burning of fossil fuels. Carbon dioxide capture and storage involves the capture, compression, and transport of CO2 to geologically favorable areas, where its injected into porous rock more than one kilometer underground for permanent storage. Oldenburg, who heads Berkeley Labs Geologic Carbon Sequestration Program, will focus on the challenges, opportunities, and research needs of this innovative technology.

  7. 3. FIELD DEMONSTRATION STATUS We are currently in the final stages of preparation in the pilot area prior to CO2 injection.

    E-Print Network [OSTI]

    Schechter, David S.

    of these tests to characterize further the reservoir and develop proper reservoir management strategy has been-well interference test. Stable water injection was initiated in October of 1999 in order to increase the reservoir of a waterflood baseline decline so that all produced oil as a result of CO2 injection can be quantified

  8. Modeling the resolution of inexpensive, novel non-seismic geophysical monitoring tools to monitor CO2 injection into coal beds

    E-Print Network [OSTI]

    Gasperikova, E.

    2010-01-01T23:59:59.000Z

    Plasynski, S. , 2008, Advancing Coal-Based Power Generationto monitor CO 2 injection into Coal Beds as a part of theanalysis for CO 2 movement in coal beds was based on the

  9. Groundwater Chemistry Changes as a Result of CO2 Injection at the ZERT Field Site in Bozeman, Montana

    E-Print Network [OSTI]

    Apps, J.A.

    2010-01-01T23:59:59.000Z

    Groundwater Chemistry Changes as a Result of CO 2 Injection9 Test Configuration and Groundwater1994) Geochemistry, groundwater and pollution. A.A.Balkema,

  10. DOE Partnership Completes Successful CO2 Injection Test in the Mount Simon Sandstone

    Broader source: Energy.gov [DOE]

    The Midwest Regional Carbon Sequestration Partnership, one of seven partnerships in the U.S. Department of Energy's Regional Carbon Sequestration Partnerships program, has successfully injected 1,000 metric tons of carbon dioxide (CO2) into the Mount Simon Sandstone, a deep saline formation that is widespread across much of the Midwest.

  11. 2. INVESTIGATION OF CO2 GRAVITY DRAINAGE AFTER WATER INJECTION IN FRACTURED SYSTEMS

    E-Print Network [OSTI]

    Schechter, David S.

    on whole diameter Berea cores and Spraberry cores under the conditions of reservoir temperature fractured cores, five experiments had been performed on Berea and Spraberry reservoir cores. The properties investigations was designed to model the actual field experience of waterflooding followed by CO2 injection

  12. Novel CO2 Foam Concepts and Injection Schemes for Improving CO2 Sweep Efficiency in Sandstone and Carbonate Hydrocarbon Formations

    SciTech Connect (OSTI)

    Nguyen, Quoc; Hirasaki, George; Johnston, Keith

    2014-12-31T23:59:59.000Z

    We explored cationic, nonionic and zwitterionic surfactants to identify candidates that have the potential to satisfy all the key requirements for CO2 foams in EOR. We have examined the formation, texture, rheology and stability of CO2 foams as a function of the surfactant structure and formulation variables including temperature, pressure, water/CO2 ratio, surfactant concentration, salinity and concentration of oil. Furthermore, the partitioning of surfactants between oil and water as well as CO2 and water was examined in conjunction with adsorption measurements on limestone by the Hirasaki lab to develop strategies to optimize the transport of surfactants in reservoirs.

  13. Changes in the chemistry of shallow groundwater related to the 2008 injection of CO2 at the ZERT Field Site, Bozeman, Montana

    E-Print Network [OSTI]

    Kharaka, Y.K.

    2010-01-01T23:59:59.000Z

    and as observed in enhanced oil recovery (EOR) operations (CO 2 -injection enhanced oil recovery site, Saskatchewan,

  14. Changes in the chemistry of shallow groundwater related to the 2008 injection of CO2 at the ZERT field site, Bozeman, Montana

    E-Print Network [OSTI]

    2010-01-01T23:59:59.000Z

    and as observed in enhanced oil recovery (EOR) operations (CO 2 -injection enhanced oil recovery site, Saskatchewan,

  15. A Comparative Review of Hydrologic Issues Involved in Geologic Storage of CO2 and Injection Disposal of Liquid Waste

    E-Print Network [OSTI]

    Tsang, C.-F.

    2009-01-01T23:59:59.000Z

    J. , and Jammes, L. , Well integrity in CO 2 environments:nine areas: Injection well integrity Abandoned well problemswastes. A number of well-integrity failures in the 1960s and

  16. Benefits and costs of brine extraction for increasing injection efficiency in geologic CO2 sequestration

    SciTech Connect (OSTI)

    Davidson, Casie L.; Watson, David J.; Dooley, James J.; Dahowski, Robert T.

    2014-01-01T23:59:59.000Z

    Pressure increases attendant with CO2 injection into the subsurface drive many of the risk factors associated with commercial-scale CCS projects, impacting project costs and liabilities in a number of ways. The area of elevated pressure defines the area that must be characterized and monitored; pressure drives fluid flow out of the storage reservoir along higher-permeability pathways that might exist through the caprock into overlying aquifers or hydrocarbon reservoirs; and pressure drives geomechanical changes that could potentially impact subsurface infrastructure or the integrity of the storage system itself. Pressure also limits injectivity, which can increase capital costs associated with installing additional wells to meet a given target injection rate. The ability to mitigate pressure increases in storage reservoirs could have significant value to a CCS project, but these benefits are offset by the costs of the pressure mitigation technique itself. Of particular interest for CO2 storage operators is the lifetime cost of implementing brine extraction at a CCS project site, and the relative value of benefits derived from the extraction process. This is expected to vary from site to site and from one implementation scenario to the next. Indeed, quantifying benefits against costs could allow operators to optimize their return on project investment by calculating the most effective scenario for pressure mitigation. This work builds on research recently submitted for publication by the authors examining the costs and benefits of brine extraction across operational scenarios to evaluate the effects of fluid extraction on injection rate to assess the cost effectiveness of several options for reducing the number of injection wells required. Modeling suggests that extracting at 90% of the volumetric equivalent of injection rate resulted in a 1.8% improvement in rate over a non-extraction base case; a four-fold increase in extraction rate results in a 7.6% increase in injection rate over the no-extraction base case. However, the practical impacts on capital costs suggest that this strategy is fiscally ineffective when evaluated solely on this metric, with extraction reducing injection well needs by only one per 56 (1x case) or one per 13 (4x case).

  17. Evaluating the impact of caprock and reservoir properties on potential risk of CO2 leakage after injection

    SciTech Connect (OSTI)

    Hou, Zhangshuan; Rockhold, Mark L.; Murray, Christopher J.

    2012-01-05T23:59:59.000Z

    Numerical models are essential tools for CO2 sequestration projects and should be included in the life cycle of a project. Common practice involves modeling the behavior of CO2 during and after injection using site-specific reservoir and caprock properties. Little has been done to systematically evaluate and compare the effects of a broad but realistic range of reservoir and caprock properties on potential CO2 leakage through caprock. Broad-based research addressing the impacts of caprock properties and their heterogeneity on seal permeation is absent. Efforts along this direction require obtaining information about the physically reasonable range of caprock and reservoir properties, effectively sampling the parameter space to fully explore the range of these properties, and performing flow and transport calculations using reliable numerical simulators. In this study, we identify the most important factors affecting CO2 leakage through intact caprock and try to understand the underlying mechanisms. We use caprock and reservoir properties from various field sites and literature data to identify the range of caprock thickness, permeability, and porosity that might occur. We use a quasi Monte Carlo sampling approach to ensure that the full range of caprock and seal properties is evaluated without bias. For each set of sampled properties, the migration of injected CO2 is simulated for up to 200 years using the water-salt-CO2 operational mode of the STOMP simulator. Preliminary results show that critical factors determining CO2 leakage rate through intact caprock are, in decreasing order of significance, the caprock thickness, caprock permeability, reservoir permeability, caprock porosity, and reservoir porosity. This study provides a function for prediction of potential CO2 leakage risk due to permeation of intact caprock, and identifies a range of acceptable seal thicknesses and permeability for sequestration projects. As a byproduct, the dependence of CO2 injectivity on reservoir properties is also evaluated.

  18. Method and apparatus for efficient injection of CO2 in oceans

    DOE Patents [OSTI]

    West, Olivia R.; Tsouris, Constantinos; Liang, Liyuan

    2003-07-29T23:59:59.000Z

    A liquid CO.sub.2 injection system produces a negatively buoyant consolidated stream of liquid CO.sub.2, CO.sub.2 hydrate, and water that sinks upon release at ocean depths in the range of 700-1500 m. In this approach, seawater at a predetermined ocean depth is mixed with the liquid CO.sub.2 stream before release into the ocean. Because mixing is conducted at depths where pressures and temperatures are suitable for CO.sub.2 hydrate formation, the consolidated stream issuing from the injector is negatively buoyant, and comprises mixed CO.sub.2 -hydrate/CO.sub.2 -liquid/water phases. The "sinking" characteristic of the produced stream will prolong the metastability of CO.sub.2 ocean sequestration by reducing the CO.sub.2 dissolution rate into water. Furthermore, the deeper the CO.sub.2 hydrate stream sinks after injection, the more stable it becomes internally, the deeper it is dissolved, and the more dispersed is the resulting CO.sub.2 plume. These factors increase efficiency, increase the residence time of CO2 in the ocean, and decrease the cost of CO.sub.2 sequestration while reducing deleterious impacts of free CO.sub.2 gas in ocean water.

  19. Comparison of the Wymark CO2 Reservoir with the Midale Beds at the Weyburn CO2 Injection Project

    SciTech Connect (OSTI)

    Ryerson, F; Johnson, J

    2010-11-22T23:59:59.000Z

    The Devonian carbonates of the Duperow Formation on the western flank of the Williston Basin in southwest Saskatchewan contain natural accumulations of CO{sub 2}, and may have done so for as long as 50 m.y. in the views of some investigations. These carbonate sediments are characterized by a succession of carbonate cycles capped by anhydrite-rich evaporites that are thought to act as seals to fluid migration. The Weyburn CO{sub 2} injection site lies 400 km to the east in a series of Mississippian carbonates that were deposited in a similar depositional environment. That natural CO{sub 2} can be stored long-term within carbonate strata has motivated the investigation of the Duperow rocks as a potential natural analogue to storage of anthropogenic CO{sub 2} that may ultimately provide additional confidence for CO{sub 2} sequestration in carbonate lithologies. For the Duperow strata to represent a legitimate analog for Midale injection and storage, the similarity in lithofacies, whole rock compositions, mineral compositions and porosity with the Midale Beds must be established. Previous workers have demonstrated the similarity of the lithofacies at both sites. Here we compare the whole rock compositions, mineralogy and mineral compositions. The major mineral phases at both locales are calcite, dolomite and anhydrite. In addition, accessory pyrite, fluorite and celestine are also observed. The distribution of porosity in the Midale Vuggy units is virtually identical to that of the Duperow Formation, but the Marly units of the Midale have significantly higher porosity. The Duperow Formation is topped by the Dinesmore evaporite that is particularly rich in anhydrite, and often contains authigenic K-feldspar. The chemistry of dolomite and calcite from the two localities also overlaps. Silicate minerals are in low abundance within the analyzed Duperow samples, < 3 wt% on a normative basis, with quartz the only phase identifiable in x-ray diffraction patterns. The Midale Beds contain significantly higher silica/silicate concentrations, but the silicate minerals observed, K-feldspar and quartz, are unlikely to participate in carbonate mineral precipitation due to the absence of alkaline earths. Hence, physical and solution trapping are likely to be the primary trapping mechanisms at both sites. Given the similarity of mineral constituents, whole rock and mineral chemistry, reactive transport models developed for the Weyburn site should also be applicable to the Duperow lithologies.

  20. Rcupration assiste d'hydrocarbures, conventionnels ou non, par injection de CO2.

    E-Print Network [OSTI]

    Canet, Léonie

    -combustion (gas processing) 5 (+ 3.5 in construction) EOR 2010 Air Products Steam Methane Reformer EOR United · Récupération d' hydrocarbures conventionnels - CO2 ­ EOR enhanced oil recovery - CO2 ­ EGR enhanced gas recovery · Récupération d' hydrocarbures non conventionnels - veines de charbon non exploitables - hydrates

  1. CO2 Injection in Vertical and Horizontal Cores: Measurements and Numerical

    E-Print Network [OSTI]

    Firoozabadi, Abbas

    - covery in both new reservoirs, and reservoirs that have been pre- viously depleted and/or water flooded high-pressure and low-temperature reservoirs, the den- sity of CO2 may be substantially higher than the oil density. Upon mixing of CO2 and oil, a gas phase with a high content of methane (C1) may also

  2. Complex Flow and Composition Path in CO2 Injection Schemes from Density Effects

    E-Print Network [OSTI]

    Firoozabadi, Abbas

    causes for acceleration in global warming. Because fossil fuels will be a critical component of the world (1) allows for reduction of the CO2 concentration in the atmosphere to reduce global warming and (2) has become more attractive from the standpoint of global warming concerns. The increase in the CO2

  3. Well injectivity during CO2storage operations in deep saline aquifers 6 Part 2: Numerical simulations of drying, salt deposit mechanisms and role of7

    E-Print Network [OSTI]

    Paris-Sud XI, Université de

    1 1 2 3 4 5 Well injectivity during CO2storage operations in deep saline aquifers ­6 Part 2 or industrial units and stored in underground geological reservoirs.30 Return on experience withCO2 injection-well field scale is proposed. This approach is of major40 importance because it makes it possible

  4. Geomechanical effects on CO2 leakage through fault zones during large-scale underground injection

    E-Print Network [OSTI]

    Rinaldi, A.P.

    2014-01-01T23:59:59.000Z

    Rutqvist, J. , 2012. The Geomechanics of CO 2 Storage in2001. Fully coupled geomechanics and fluid-flow analysis ofUS Rock Mechanics, Geomechanics Symposium. San Francisco, 23

  5. Imaging of CO2 injection during an enhanced-oil-recovery experiment

    E-Print Network [OSTI]

    Gritto, Roland; Daley, Thomas M.; Myer, Larry R.

    2003-01-01T23:59:59.000Z

    Injection during an Enhanced-Oil-Recovery Experiment RolandEnergy (DOE) as an enhanced oil recovery (EOR) project, was

  6. Toward Verifying Fossil Fuel CO2 Emissions with the CMAQ Model: Motivation, Model Description and Initial Simulation

    SciTech Connect (OSTI)

    Liu, Zhen; Bambha, Ray P.; Pinto, Joseph P.; Zeng, Tao; Boylan, Jim; Huang, Maoyi; Lei, Huimin; Zhao, Chun; Liu, Shishi; Mao, Jiafu; Schwalm, Christopher R.; Shi, Xiaoying; Wei, Yaxing; Michelsen, Hope A.

    2014-03-14T23:59:59.000Z

    Motivated by the urgent need for emission verification of CO2 and other greenhouse gases, we have developed regional CO2 simulation with CMAQ over the contiguous U.S. Model sensitivity experiments have been performed using three different sets of inputs for net ecosystem exchange (NEE) and two fossil fuel emission inventories, to understand the roles of fossil fuel emissions, atmosphere-biosphere exchange and transport in regulating the spatial and diurnal variability of CO2 near the surface, and to characterize the well-known ‘signal-to-noise’ problem, i.e. the interference from the biosphere on the interpretation of atmospheric CO2 observations. It is found that differences in the meteorological conditions for different urban areas strongly contribute to the contrast in concentrations. The uncertainty of NEE, as measured by the difference among the three different NEE inputs, has notable impact on regional distribution of CO2 simulated by CMAQ. Larger NEE uncertainty and impact are found over eastern U.S. urban areas than along the western coast. A comparison with tower CO2 measurements at Boulder Atmospheric Observatory (BAO) shows that the CMAQ model using hourly varied and high-resolution CO2 emission from the Vulcan inventory and CarbonTracker optimized NEE reasonably reproduce the observed diurnal profile, whereas switching to different NEE inputs significantly degrades the model performance. Spatial distribution of CO2 is found to correlate with NOx, SO2 and CO, due to their similarity in emission sources and transport processes. These initial results from CMAQ demonstrate the power of a state-of-the art CTM in helping interpret CO2 observations and verify fossil fuel emissions. The ability to simulate CO2 in CMAQ will also facilitate investigations of the utility of traditionally regulated pollutants and other species as tracers to CO2 source attribution.

  7. Application of X-ray CT for investigating fluid flow and conformance control during CO2 injection in highly heterogeneous media

    E-Print Network [OSTI]

    Chakravarthy, Deepak

    2005-08-29T23:59:59.000Z

    . The experimental results indicate that injection rates play a very important role in affecting the recovery process, more so in the presence of fractures. At high injection rates, faster breakthrough of CO2 and higher oil bypass were observed than at low injection...

  8. Investigation of Efficiency Improvements During CO2 Injection in Hydraulically and Naturally Fractured Reservoirs

    SciTech Connect (OSTI)

    Schechter, David S.; Vance, Harold

    2003-03-10T23:59:59.000Z

    The objective of this project was to perform unique laboratory experiments with artificial fractured cores (AFCs) and X-ray CT to examine the physical mechanisms of bypassing in HFR and NFR that eventually result in less efficient CO2 flooding in heterogeneous or fracture-dominated reservoirs. This report provided results of the second semi-annual technical progress report that consists of three different topics.

  9. Experimental and Simulation Studies to Evaluate the Improvement of Oil Recovery by Different Modes of CO2 Injection in Carbonate Reservoirs

    E-Print Network [OSTI]

    Aleidan, Ahmed Abdulaziz S.

    2011-02-22T23:59:59.000Z

    Experimental and numerical simulation studies were conducted to investigate the improvement of light oil recovery in carbonate cores during CO2 injection. The main steps in the study are as follows. First, the minimum miscibility pressure of 31º...

  10. Changes in the chemistry of shallow groundwater related to the 2008 injection of CO2 at the ZERT Field Site, Bozeman, Montana

    SciTech Connect (OSTI)

    Kharaka, Y.K.; Thordsen, T.T.; Kakouros, E.; Ambats, G.; Herkelrath, W.N.; Birkholzer, J.T.; Apps, J.A.; Spycher, N.F.; Zheng, L.; Trautz, R.C.; Rauch, H.W.; Gullickson, K.; Beers, S.R.

    2009-09-01T23:59:59.000Z

    Approximately 300 kg/day of food-grade CO2 was injected through a perforated pipe placed horizontally 2-2.3 m deep during July 9-August 7, 2008 at the MSU-ZERT field test to evaluate atmospheric and near-surface monitoring and detection techniques applicable to the subsurface storage and potential leakage of CO2. As part of this multidisciplinary research project, 80 samples of water were collected from 10 shallow monitoring wells (1.5 or 3.0 m deep) installed 1-6 m from the injection pipe, at the southwestern end of the slotted section (zone VI), and from two distant monitoring wells. The samples were collected before, during and following CO2 injection. The main objective of study was to investigate changes in the concentrations of major, minor and trace inorganic and organic compounds during and following CO2 injection.

  11. Modeling Density Effects in CO2 Injection in Oil Reservoirs and A Case Study of CO2 Sequestration in a Qatari Saline Aquifer

    E-Print Network [OSTI]

    Ahmed, Tausif

    2012-10-19T23:59:59.000Z

    in southwest Qatar is used as a case study for CO2 sequestration. A compositional simulation model is prepared for the Aruma aquifer using the available log data and flow test data. It was found that the grid size is a key parameter in modeling CO2...

  12. Seismic Evaluation of the Fruitland Formation with Implications on Leakage Potential of Injected CO2

    E-Print Network [OSTI]

    Wilson, Thomas H.

    on the analysis of 3D seismic from the area. 3D seismic interpretation reveals that the Late Cretaceous FruitlandSeismic Evaluation of the Fruitland Formation with Implications on Leakage Potential of Injected CO Basin pilot test include acquisition of geophysical logs, time lapse VSP and analysis of 3D seismic data

  13. INVESTIGATION OF EFFICIENCY IMPROVEMENTS DURING CO2 INJECTION IN HYDRAULICALLY AND NATURALLY FRACTURED RESERVOIRS

    SciTech Connect (OSTI)

    David S. Schechter

    2004-04-26T23:59:59.000Z

    This report describes the work performed during the second year of the project, ''Investigating of Efficiency Improvements during CO{sub 2} Injection in Hydraulically and Naturally Fractured Reservoirs.'' The objective of this project is to perform unique laboratory experiments with artificial fractured cores (AFCs) and X-ray CT to examine the physical mechanisms of bypassing in HFR and NFR that eventually result in less efficient CO{sub 2} flooding in heterogeneous or fracture-dominated reservoirs. To achieve this objective, in this period we concentrated our effort on investigating the effect of CO{sub 2} injection rates in homogeneous and fractured cores on oil recovery and a strategy to mitigate CO{sub 2} bypassing in a fractured core.

  14. Injection, flow, and mixing of CO2 in porous media with residual gas.

    SciTech Connect (OSTI)

    Oldenburg, C.M.; Doughty, C.A.

    2010-09-01T23:59:59.000Z

    Geologic structures associated with depleted natural gas reservoirs are desirable targets for geologic carbon sequestration (GCS) as evidenced by numerous pilot and industrial-scale GCS projects in these environments world-wide. One feature of these GCS targets that may affect injection is the presence of residual CH{sub 4}. It is well known that CH{sub 4} drastically alters supercritical CO{sub 2} density and viscosity. Furthermore, residual gas of any kind affects the relative permeability of the liquid and gas phases, with relative permeability of the gas phase strongly dependent on the time-history of imbibition or drainage, i.e., dependent on hysteretic relative permeability. In this study, the effects of residual CH{sub 4} on supercritical CO{sub 2} injection were investigated by numerical simulation in an idealized one-dimensional system under three scenarios: (1) with no residual gas; (2) with residual supercritical CO{sub 2}; and (3) with residual CH{sub 4}. We further compare results of simulations that use non-hysteretic and hysteretic relative permeability functions. The primary effect of residual gas is to decrease injectivity by decreasing liquid-phase relative permeability. Secondary effects arise from injected gas effectively incorporating residual gas and thereby extending the mobile gas plume relative to cases with no residual gas. Third-order effects arise from gas mixing and associated compositional effects on density that effectively create a larger plume per unit mass. Non-hysteretic models of relative permeability can be used to approximate some parts of the behavior of the system, but fully hysteretic formulations are needed to accurately model the entire system.

  15. Flow Instabilities During Injection of CO2 into SalineAquifers

    SciTech Connect (OSTI)

    Garcia, Julio E.; Pruess, Karsten

    2003-04-15T23:59:59.000Z

    Injection of carbon dioxide (CO{sub 2}) into saline aquifers has been proposed as a means to reduce greenhouse gas emissions (geological carbon sequestration). The injection process can be classified as immiscible displacement of an aqueous phase by a less dense and less viscous gas phase. Under disposal conditions (supercritical CO{sub 2}) the viscosity of carbon dioxide can be less than the viscosity of the aqueous phase by a factor of 15. Because of the lower viscosity, the CO{sub 2} displacement front will have a tendency towards instability so that waves or rounded lobes of saturation may appear and grow into fingers that lead to enhanced dissolution, bypassing, and possibly poor sweep efficiency. This paper presents an analysis, through high-resolution numerical simulations, of the onset of instabilities (viscous fingering) during injection of CO{sub 2} into saline aquifers. We explore the influence of viscosity ratio, relative permeability functions, and capillary pressure on finger growth and spacing. In addition, we address the issues of finger triggering, convergence under grid refinement and boundary condition effects. Simulations were carried out on scalar machines, and on an IBM RS/6000 SP (a distributed-memory parallel computer with 6080 processors) with a parallelized version of TOUGH2.

  16. Pore-scale study of capillary trapping mechanism during CO2 injection in geological formations

    SciTech Connect (OSTI)

    Bandara, Uditha C.; Tartakovsky, Alexandre M.; Palmer, Bruce J.

    2011-11-01T23:59:59.000Z

    Geological sequestration of CO{sub 2} gas emerged as a promising solution for reducing amount of green house gases in atmosphere. A number of continuum scale models are available to describe the transport phenomena of CO{sub 2} sequestration. These models rely heavily on a phenomenological description of subsurface transport phenomena and the predictions can be highly uncertain. Pore-scale models provide a better understanding of fluid displacement processes, nonetheless such models are rare. In this work we use a Smoothed Particle Hydrodynamics (SPH) model to study pore-scale displacement and capillary trapping mechanisms of super-critical CO{sub 2} in the subsurface. Simulations are carried out to investigate the effects of gravitational, viscous, and capillary forces in terms of Gravity, Capillary, and Bond numbers. Contrary to the other published continuum scale investigations, we found that not only Gravity number but also Capillary number plays an important role on the fate of injected CO{sub 2}. For large Gravity numbers (on the order of 10), most of the injected CO{sub 2} reaches the cap-rock due to gravity segregation. A significant portion of CO{sub 2} gets trapped by capillary forces when Gravity number is small (on the order of 0.1). When Gravity number is moderately high (on the order of 1), trapping patterns are heavily dependent on Capillary number. If Capillary number is very small (less than 0.001), then capillary forces dominate the buoyancy forces and a significant fraction of injected CO{sub 2} is trapped by the capillary forces. Conversely, if Capillary number is high (higher than 0.001), capillary trapping is relatively small since buoyancy dominates the capillary forces. In addition, our simulations reveal different types of capillary trapping and flow displacement mechanisms during and after injection. In gravity dominated cases leave behind was the widespread trapping mechanism. Division was the primary trapping mechanism in viscous dominated cases. In capillary dominated cases, snap-off of the CO{sub 2} plume is the most commonly observed displacement mechanism. Large CO{sub 2} blobs are created due to coalescence mechanism.

  17. INVESTIGATION OF EFFICIENCY IMPROVEMENTS DURING CO2 INJECTION IN HYDRAULICALLY AND NATURALLY FRACTURED RESERVOIRS

    SciTech Connect (OSTI)

    David S. Schechter

    2004-10-10T23:59:59.000Z

    This report describes the work performed during the third year of the project, ''Investigating of Efficiency Improvements during CO{sub 2} Injection in Hydraulically and Naturally Fractured Reservoirs.'' The objective of this project is to perform unique laboratory experiments with artificial fractured cores (AFCs) and X-ray CT to examine the physical mechanisms of bypassing in HFR and NFR that eventually result in more efficient CO{sub 2} flooding in heterogeneous or fracture-dominated reservoirs. To achieve this objective, in this period we concentrated our effort on modeling fluid flow through rough fractures and investigating the grid orientation effect in rectangular grid blocks particularly at high mobility ratio as our precursor to use a compositional simulator. We are developing a robust simulator using Voronoi grids to accurately represent natural and induced fractures. We are also verifying the accuracy of the simulation using scaled laboratory experiments to provide a benchmark for our simulation technique. No such simulator currently exists so this capability will represent a major breakthrough in simulation of gas injection in fractured systems. The following sections outline the results that appear in this report.

  18. Groundwater Chemistry Changes as a Result of CO2 Injection at the ZERT Field Site in Bozeman, Montana

    E-Print Network [OSTI]

    Apps, J.A.

    2010-01-01T23:59:59.000Z

    field program to evaluate phenomena associated with the atmospheric leakage of CO 2 from underground storage

  19. INVESTIGATION OF EFFICIENCY IMPROVEMENTS DURING CO2 INJECTION IN HYDRAULICALLY AND NATURALLY FRACTURED RESERVOIRS

    SciTech Connect (OSTI)

    David S. Schechter

    2003-10-01T23:59:59.000Z

    This report describes the work performed during the second year of the project, ''Investigating of Efficiency Improvements during CO{sub 2} Injection in Hydraulically and Naturally Fractured Reservoirs.'' The objective of this project is to perform unique laboratory experiments with artificial fractured cores (AFCs) and X-ray CT to examine the physical mechanisms of bypassing in HFR and NFR that eventually result in less efficient CO{sub 2} flooding in heterogeneous or fracture-dominated reservoirs. To achieve this objective, in this period we concentrated our effort on modeling the fluid flow in fracture surface, examining the fluid transfer mechanisms and describing the fracture aperture distribution under different overburden pressure using X-ray CT scanner.

  20. INVESTIGATION OF EFFICIENCY IMPROVEMENTS DURING CO2 INJECTION IN HYDRAULICALLY AND NATURALLY FRACTURED RESERVOIRS

    SciTech Connect (OSTI)

    David S. Schechter

    2005-04-27T23:59:59.000Z

    This report describes the work performed during the fourth year of the project, ''Investigating of Efficiency Improvements during CO{sub 2} Injection in Hydraulically and Naturally Fractured Reservoirs.'' The objective of this project is to perform unique laboratory experiments with artificially fractured cores (AFCs) and X-ray CT scanner to examine the physical mechanisms of bypassing in hydraulically fractured reservoirs (HFR) and naturally fractured reservoirs (NFR) that eventually result in more efficient CO{sub 2} flooding in heterogeneous or fracture-dominated reservoirs. In Chapter 1, we worked with DOE-RMOTC to investigate fracture properties in the Tensleep Formation at Teapot Dome Naval Reserve as part of their CO{sub 2} sequestration project. In Chapter 2, we continue our investigation to determine the primary oil recovery mechanism in a short vertically fractured core. Finally in Chapter 3, we report our numerical modeling efforts to develop compositional simulator with irregular grid blocks.

  1. Design and Implementation of a CO2 Flood Utilizing Advanced Reservoir Characterization and Horizontal Injection Wells In a Shallow Shelf Carbonate Approaching Waterflood Depletion, Class II

    SciTech Connect (OSTI)

    Wier, Don R. Chimanhusky, John S.; Czirr, Kirk L.; Hallenbeck, Larry; Gerard, Matthew G.; Dollens, Kim B.; Owen, Rex; Gaddis, Maurice; Moshell, M.K.

    2002-11-18T23:59:59.000Z

    The purpose of this project was to economically design an optimum carbon dioxide (CO2) flood for a mature waterflood nearing its economic abandonment. The original project utilized advanced reservoir characterization and CO2 horizontal injection wells as the primary methods to redevelop the South Cowden Unit (SCU). The development plans; project implementation and reservoir management techniques were to be transferred to the public domain to assist in preventing premature abandonment of similar fields.

  2. OIL RESERVOIR CHARACTERIZATION AND CO2 INJECTION MONITORING IN THE PERMIAN BASIN WITH CROSSWELL ELECTROMAGNETIC IMAGING

    SciTech Connect (OSTI)

    Michael Wilt

    2004-02-01T23:59:59.000Z

    Substantial petroleum reserves exist in US oil fields that cannot be produced economically, at current prices, unless improvements in technology are forthcoming. Recovery of these reserves is vital to US economic and security interests as it lessens our dependence on foreign sources and keeps our domestic petroleum industry vital. Several new technologies have emerged that may improve the situation. The first is a series of new flooding techniques to re-pressurize reservoirs and improve the recovery. Of these the most promising is miscible CO{sub 2} flooding, which has been used in several US petroleum basins. The second is the emergence of new monitoring technologies to track and help manage this injection. One of the major players in here is crosswell electromagnetics, which has a proven sensitivity to reservoir fluids. In this project, we are applying the crosswell EM technology to a CO{sub 2} flood in the Permian Basin oil fields of New Mexico. With our partner ChevronTexaco, we are testing the suitability of using EM for tracking the flow of injected CO{sub 2} through the San Andreas reservoir in the Vacuum field in New Mexico. The project consisted of three phases, the first of which was a preliminary field test at Vacuum, where a prototype system was tested in oil field conditions including widely spaced wells with steel casing. The results, although useful, demonstrated that the older technology was not suitable for practical deployment. In the second phase of the project, we developed a much more powerful and robust field system capable of collecting and interpreting field data through steel-cased wells. The final phase of the project involved applying this system in field tests in the US and overseas. Results for tests in steam and water floods showed remarkable capability to image between steel wells and provided images that helped understand the geology and ongoing flood and helped better manage the field. The future of this technology is indeed bright with development ongoing and a commercialization plan in place. We expect that this DOE sponsored technology will be a major technical and commercial success story in the coming years.

  3. Well injectivity during CO2 storage operations in deep saline aquifers6 1: Experimental investigation of drying effects, salt precipitation and7

    E-Print Network [OSTI]

    Boyer, Edmond

    Carbon Capture and Storage (CCS) is a technique than can potentially limit the accumulation29-17Jan2014 #12;3 1. Introduction51 52 Geological sequestration of CO2 into deep saline aquifers studied54 much less than mature oil & gas reservoirs. Injection of carbon dioxide into saline aquifers55

  4. Effect of Oxygen Co-Injected with Carbon Dioxide on Gothic Shale Caprock-CO2-Brine Interaction during Geologic Carbon Sequestration

    SciTech Connect (OSTI)

    Jung, Hun Bok; Um, Wooyong; Cantrell, Kirk J.

    2013-09-16T23:59:59.000Z

    Co-injection of oxygen, a significant component in CO2 streams produced by the oxyfuel combustion process, can cause a significant alteration of the redox state in deep geologic formations during geologic carbon sequestration. The potential impact of co-injected oxygen on the interaction between synthetic CO2-brine (0.1 M NaCl) and shale caprock (Gothic shale from the Aneth Unit in Utah) and mobilization of trace metals was investigated at ~10 MPa and ~75 °C. A range of relative volume percentages of O2 to CO2 (0, 1, 4 and 8%) were used in these experiments to address the effect of oxygen on shale-CO2-brine interaction under various conditions. Major mineral phases in Gothic shale are quartz, calcite, dolomite, montmorillonite, and pyrite. During Gothic shale-CO2-brine interaction in the presence of oxygen, pyrite oxidation occurred extensively and caused enhanced dissolution of calcite and dolomite. Pyrite oxidation and calcite dissolution subsequently resulted in the precipitation of Fe(III) oxides and gypsum (CaSO4•2H2O). In the presence of oxygen, dissolved Mn and Ni were elevated because of oxidative dissolution of pyrite. The mobility of dissolved Ba was controlled by barite (BaSO4) precipitation in the presence of oxygen. Dissolved U in the experimental brines increased to ~8–14 ?g/L, with concentrations being slightly higher in the absence of oxygen than in the presence of oxygen. Experimental and modeling results indicate the interaction between shale caprock and oxygen co-injected with CO2 during geologic carbon sequestration can exert significant impacts on brine pH, solubility of carbonate minerals, stability of sulfide minerals, and mobility of trace metals. The major impact of oxygen is most likely to occur in the zone near CO2 injection wells where impurity gases can accumulate. Oxygen in CO2-brine migrating away from the injection well will be continually consumed through the reactions with sulfide minerals in deep geologic formations.

  5. Groundwater Chemistry Changes as a Result of CO2 Injection at the ZERT Field Site in Bozeman, Montana

    E-Print Network [OSTI]

    Apps, J.A.

    2010-01-01T23:59:59.000Z

    according to the reaction MCO 3 + CO 2 (aq) + H 2 O ? M +2 +according to the reaction MCO 3 + H + ? M +2 + HCO 3- is

  6. Modeling of coulpled deformation and permeability evolution during fault reactivation induced by deep underground injection of CO2

    SciTech Connect (OSTI)

    Cappa, F.; Rutqvist, J.

    2010-06-01T23:59:59.000Z

    The interaction between mechanical deformation and fluid flow in fault zones gives rise to a host of coupled hydromechanical processes fundamental to fault instability, induced seismicity, and associated fluid migration. In this paper, we discuss these coupled processes in general and describe three modeling approaches that have been considered to analyze fluid flow and stress coupling in fault-instability processes. First, fault hydromechanical models were tested to investigate fault behavior using different mechanical modeling approaches, including slip interface and finite-thickness elements with isotropic or anisotropic elasto-plastic constitutive models. The results of this investigation showed that fault hydromechanical behavior can be appropriately represented with the least complex alternative, using a finite-thickness element and isotropic plasticity. We utilized this pragmatic approach coupled with a strain-permeability model to study hydromechanical effects on fault instability during deep underground injection of CO{sub 2}. We demonstrated how such a modeling approach can be applied to determine the likelihood of fault reactivation and to estimate the associated loss of CO{sub 2} from the injection zone. It is shown that shear-enhanced permeability initiated where the fault intersects the injection zone plays an important role in propagating fault instability and permeability enhancement through the overlying caprock.

  7. Three-phase compositional modeling of CO2 injection by higher-order finite element methods with CPA equation

    E-Print Network [OSTI]

    Firoozabadi, Abbas

    and gravitational fingering that can negatively affect hydrocarbon (HC) recovery, or aid carbon sequestration and other simulators. The examples consider gravitational fingering during CO2 sequestration in aquifers could have a significant impact on CO2 sequestration and IOR. Accurate simulation of compositional

  8. Constraining the reservoir model of an injected CO2 plume with crosswell CASSM at the Frio-II brine plot

    SciTech Connect (OSTI)

    Daley, T.M.; Ajo-Franklin, J.; Doughty, C.A.

    2011-02-15T23:59:59.000Z

    Crosswell CASSM (continuous active-source seismic monitoring) data was acquired as part of the Frio-II brine pilot CO{sub 2} injection experiment. To gain insight into the CO{sub 2} plume evolution, we have integrated the 3D multiphase flow modeling code TOUGH2 with seismic simulation codes via a petrophysical model that predicts seismic velocity for a given CO{sub 2} saturation. Results of forward seismic modeling based on the CO{sub 2} saturation distribution produced by an initial TOUGH2 model compare poorly with the CASSM data, indicating that the initial flow model did not capture the actual CO{sub 2} plume dynamics. Updates to the TOUGH2 model required to better match the CASSM field data indicate vertical flow near the injection well, with increased horizontal plume growth occurring at the top of the reservoir sand. The CASSM continuous delay time data are ideal for constraining the modeled spatiotemporal evolution of the CO{sub 2} plume and allow improvement in reservoir model and estimation of CO{sub 2} plume properties.

  9. Uncertainty quantification for CO2 sequestration and enhanced oil recovery

    E-Print Network [OSTI]

    Dai, Zhenxue; Fessenden-Rahn, Julianna; Middleton, Richard; Pan, Feng; Jia, Wei; Lee, Si-Yong; McPherson, Brian; Ampomah, William; Grigg, Reid

    2014-01-01T23:59:59.000Z

    This study develops a statistical method to perform uncertainty quantification for understanding CO2 storage potential within an enhanced oil recovery (EOR) environment at the Farnsworth Unit of the Anadarko Basin in northern Texas. A set of geostatistical-based Monte Carlo simulations of CO2-oil-water flow and reactive transport in the Morrow formation are conducted for global sensitivity and statistical analysis of the major uncertainty metrics: net CO2 injection, cumulative oil production, cumulative gas (CH4) production, and net water injection. A global sensitivity and response surface analysis indicates that reservoir permeability, porosity, and thickness are the major intrinsic reservoir parameters that control net CO2 injection/storage and oil/gas recovery rates. The well spacing and the initial water saturation also have large impact on the oil/gas recovery rates. Further, this study has revealed key insights into the potential behavior and the operational parameters of CO2 sequestration at CO2-EOR s...

  10. Carbon Sequestration Partner Initiates Drilling of CO2 Injection Well in

    Broader source: Energy.gov (indexed) [DOE]

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative1 First Use of Energy for All Purposes (Fuel and Nonfuel), 2002; Level: National5Sales for4,645 3,625 1,006 492 742Energy China U.S. Department ofJuneWaste To Wisdom:Energy Joshua DeLung What does this

  11. DOE Regional Partner Initiates CO2 Injection Study in Virginia | Department

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Home Page on Google Bookmark EERE: Alternative Fuels DataDepartment of Energy Your Density Isn't Your Destiny: Theof"WaveInteractions and Policy (2009)|PublishesDOEWasherMarch 21, 2011of

  12. DOE Regional Partnership Initiates CO2 Injection in Lignite Coal Seam |

    Energy Savers [EERE]

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Home Page onYou are now leaving Energy.gov You are now leaving Energy.gov You are being directed offOCHCO OverviewAttachments4 ChairsEnergy DOEHeat Pump Models |Publishes NewDOEDOEofDepartment

  13. Groundwater Chemistry Changes as a Result of CO2 Injection at the ZERT Field Site in Bozeman, Montana

    E-Print Network [OSTI]

    Apps, J.A.

    2010-01-01T23:59:59.000Z

    Co +2 Cu + Cd +2 PbSe CrO + AsSe(OH)(SeH) - FeSe MoO 4-2 UOCo +2 Cu + Cd +2 PbSe CrO + AsSe(OH)(SeH) - FeSe MoO 4-2 UO

  14. The effects of gas-fluid-rock interactions on CO2 injection and storage: Insights from reactive transport modeling

    SciTech Connect (OSTI)

    Xiao, Y.; Xu, T.; Pruess, K.

    2008-10-15T23:59:59.000Z

    Possible means of reducing atmospheric CO{sub 2} emissions include injecting CO{sub 2} in petroleum reservoirs for Enhanced Oil Recovery or storing CO{sub 2} in deep saline aquifers. Large-scale injection of CO{sub 2} into subsurface reservoirs would induce a complex interplay of multiphase flow, capillary trapping, dissolution, diffusion, convection, and chemical reactions that may have significant impacts on both short-term injection performance and long-term fate of CO{sub 2} storage. Reactive Transport Modeling is a promising approach that can be used to predict the spatial and temporal evolution of injected CO{sub 2} and associated gas-fluid-rock interactions. This presentation will summarize recent advances in reactive transport modeling of CO{sub 2} storage and review key technical issues on (1) the short- and long-term behavior of injected CO{sub 2} in geological formations; (2) the role of reservoir mineral heterogeneity on injection performance and storage security; (3) the effect of gas mixtures (e.g., H{sub 2}S and SO{sub 2}) on CO{sub 2} storage; and (4) the physical and chemical processes during potential leakage of CO{sub 2} from the primary storage reservoir. Simulation results suggest that CO{sub 2} trapping capacity, rate, and impact on reservoir rocks depend on primary mineral composition and injecting gas mixtures. For example, models predict that the injection of CO{sub 2} alone or co-injection with H{sub 2}S in both sandstone and carbonate reservoirs lead to acidified zones and mineral dissolution adjacent to the injection well, and carbonate precipitation and mineral trapping away from the well. Co-injection of CO{sub 2} with H{sub 2}S and in particular with SO{sub 2} causes greater formation alteration and complex sulfur mineral (alunite, anhydrite, and pyrite) trapping, sometimes at a much faster rate than previously thought. The results from Reactive Transport Modeling provide valuable insights for analyzing and assessing the dynamic behaviors of injected CO{sub 2}, identifying and characterizing potential storage sites, and managing injection performance and reducing costs.

  15. Analysis of Field Development Strategies of CO2 EOR/Capture Projects Using a Reservoir Simulation Economic Model

    E-Print Network [OSTI]

    Saint-Felix, Martin

    2013-05-03T23:59:59.000Z

    ............................................................................................................ 69 xii Figure 33: Evolution of the field pressure for a given injection trigger (4000 psi) and several CO2 import rates. The imported CO2 plateau lasts until the initial field pressure is reached... ....................................................... 71 Figure 35: Evolution of the oil production rate for a CO2 import rate of 300 Mscf/day and an injection trigger at 3500 psi ............................................... 74 Figure 36: Oil production plateau duration for the two injection...

  16. Injection of CO2 with H2S and SO2 and Subsequent Mineral Trapping in Sandstone-Shale Formation

    SciTech Connect (OSTI)

    Xu, Tianfu; Apps, John A.; Pruess, Karsten; Yamamoto, Hajime

    2004-09-07T23:59:59.000Z

    Carbon dioxide (CO{sub 2}) injection into deep geologic formations can potentially reduce atmospheric emissions of greenhouse gases. Sequestering less-pure CO{sub 2} waste streams (containing H{sub 2}S and/or SO{sub 2}) would be less expensive or would require less energy than separating CO{sub 2} from flue gas or a coal gasification process. The long-term interaction of these injected acid gases with shale-confining layers of a sandstone injection zone has not been well investigated. We therefore have developed a conceptual model of injection of CO{sub 2} with H{sub 2}S and/or SO{sub 2} into a sandstone-shale sequence, using hydrogeologic properties and mineral compositions commonly encountered in Gulf Coast sediments of the United States. We have performed numerical simulations of a 1-D radial well region considering sandstone alone and a 2-D model using a sandstone-shale sequence under acid-gas injection conditions. Results indicate that shale plays a limited role in mineral alteration and sequestration of gases within a sandstone horizon for short time periods (10,000 years in present simulations). The co-injection of SO{sub 2} results in different pH distribution, mineral alteration patterns, and CO{sub 2} mineral sequestration than the co-injection of H{sub 2}S or injection of CO{sub 2} alone. Simulations generate a zonal distribution of mineral alteration and formation of carbon and sulfur trapping minerals that depends on the pH distribution. The co-injection of SO{sub 2} results in a larger and stronger acidified zone close to the well. Precipitation of carbon trapping minerals occurs within the higher pH regions beyond the acidified zones. In contrast, sulfur trapping minerals are stable at low pH ranges (below 5) within the front of the acidified zone. Corrosion and well abandonment due to the co-injection of SO{sub 2} could be important issues. Significant CO{sub 2} is sequestered in ankerite and dawsonite, and some in siderite. The CO{sub 2} mineral-trapping capability can reach 80 kg per cubic meter of medium. Most sulfur is trapped through alunite precipitation, although some is trapped by anhydrite precipitation and minor amount of pyrite. The addition of the acid gases and induced mineral alteration result in changes in porosity. The limited information currently available on the mineralogy of natural high-pressure acid-gas reservoirs is generally consistent with our simulations.

  17. Simulation of CO2 Sequestration at Rock Spring Uplift, Wyoming: Heterogeneity and Uncertainties in Storage Capacity, Injectivity and Leakage

    SciTech Connect (OSTI)

    Deng, Hailin [Los Alamos National Laboratory; Dai, Zhenxue [Los Alamos National Laboratory; Jiao, Zunsheng [Wyoming State Geological Survey; Stauffer, Philip H. [Los Alamos National Laboratory; Surdam, Ronald C. [Wyoming State Geological Survey

    2011-01-01T23:59:59.000Z

    Many geological, geochemical, geomechanical and hydrogeological factors control CO{sub 2} storage in subsurface. Among them heterogeneity in saline aquifer can seriously influence design of injection wells, CO{sub 2} injection rate, CO{sub 2} plume migration, storage capacity, and potential leakage and risk assessment. This study applies indicator geostatistics, transition probability and Markov chain model at the Rock Springs Uplift, Wyoming generating facies-based heterogeneous fields for porosity and permeability in target saline aquifer (Pennsylvanian Weber sandstone) and surrounding rocks (Phosphoria, Madison and cap-rock Chugwater). A multiphase flow simulator FEHM is then used to model injection of CO{sub 2} into the target saline aquifer involving field-scale heterogeneity. The results reveal that (1) CO{sub 2} injection rates in different injection wells significantly change with local permeability distributions; (2) brine production rates in different pumping wells are also significantly impacted by the spatial heterogeneity in permeability; (3) liquid pressure evolution during and after CO{sub 2} injection in saline aquifer varies greatly for different realizations of random permeability fields, and this has potential important effects on hydraulic fracturing of the reservoir rock, reactivation of pre-existing faults and the integrity of the cap-rock; (4) CO{sub 2} storage capacity estimate for Rock Springs Uplift is 6614 {+-} 256 Mt at 95% confidence interval, which is about 36% of previous estimate based on homogeneous and isotropic storage formation; (5) density profiles show that the density of injected CO{sub 2} below 3 km is close to that of the ambient brine with given geothermal gradient and brine concentration, which indicates CO{sub 2} plume can sink to the deep before reaching thermal equilibrium with brine. Finally, we present uncertainty analysis of CO{sub 2} leakage into overlying formations due to heterogeneity in both the target saline aquifer and surrounding formations. This uncertainty in leakage will be used to feed into risk assessment modeling.

  18. EGS rock reactions with Supercritical CO2 saturated with water and water saturated with Supercritical CO2

    SciTech Connect (OSTI)

    Earl D. Mattson; Travis L. McLing; William Smith; Carl Palmer

    2013-02-01T23:59:59.000Z

    EGS using CO2 as a working fluid will likely involve hydro-shearing low-permeability hot rock reservoirs with a water solution. After that process, the fractures will be flushed with CO2 that is maintained under supercritical conditions (> 70 bars). Much of the injected water in the main fracture will be flushed out with the initial CO2 injection; however side fractures, micro fractures, and the lower portion of the fracture will contain connate water that will interact with the rock and the injected CO2. Dissolution/precipitation reactions in the resulting scCO2/brine/rock systems have the potential to significantly alter reservoir permeability, so it is important to understand where these precipitates form and how are they related to the evolving ‘free’ connate water in the system. To examine dissolution / precipitation behavior in such systems over time, we have conducted non-stirred batch experiments in the laboratory with pure minerals, sandstone, and basalt coupons with brine solution spiked with MnCl2 and scCO2. The coupons are exposed to liquid water saturated with scCO2 and extend above the water surface allowing the upper portion of the coupons to be exposed to scCO2 saturated with water. The coupons were subsequently analyzed using SEM to determine the location of reactions in both in and out of the liquid water. Results of these will be summarized with regard to significance for EGS with CO2 as a working fluid.

  19. Constraining the reservoir model of an injected CO2 plume with crosswell CASSM at the Frio-II brine plot

    E-Print Network [OSTI]

    Daley, T.M.

    2011-01-01T23:59:59.000Z

    CASSM monitoring data with the reservoir model to obtain anof CASSM data and updating the Reservoir Model Using thedata and, when the match is unsatisfactory, the initial reservoir

  20. Modeling of fate and transport of co-injection of H2S with CO2 in deep saline formations

    SciTech Connect (OSTI)

    Zhang, W.; Xu, T.; Li, Y.

    2010-12-15T23:59:59.000Z

    The geological storage of CO{sub 2} in deep saline formations is increasing seen as a viable strategy to reduce the release of greenhouse gases into the atmosphere. However, costs of capture and compression of CO{sub 2} from industrial waste streams containing small quantities of sulfur and nitrogen compounds such as SO{sub 2}, H{sub 2}S and N{sub 2} are very expensive. Therefore, studies on the co-injection of CO{sub 2} containing other acid gases from industrial emissions are very important. In this paper, numerical simulations were performed to study the co-injection of H{sub 2}S with CO{sub 2} in sandstone and carbonate formations. Results indicate that the preferential dissolution of H{sub 2}S gas (compared with CO{sub 2} gas) into formation water results in the delayed breakthrough of H{sub 2}S gas. Co-injection of H{sub 2}S results in the precipitation of pyrite through interactions between the dissolved H{sub 2}S and Fe{sup 2+} from the dissolution of Fe-bearing minerals. Additional injection of H{sub 2}S reduces the capabilities for solubility and mineral trappings of CO{sub 2} compared to the CO{sub 2} only case. In comparison to the sandstone (siliciclastic) formation, the carbonate formation is less favorable to the mineral sequestration of CO{sub 2}. Different from CO{sub 2} mineral trapping, the presence of Fe-bearing siliciclastic and/or carbonate is more favorable to the H{sub 2}S mineral trapping.

  1. Modeling the resolution of inexpensive, novel non-seismic geophysical monitoring tools to monitor CO2 injection into coal beds

    SciTech Connect (OSTI)

    Gasperikova, E.; Hoversten, G.M.

    2008-09-01T23:59:59.000Z

    A sensitivity study of gravity and electromagnetic (EM) techniques, and amplitude vs. angle (AVA) analysis for CO{sub 2} movement in coal beds was based on the SECARB pilot test planned in the Black Warrior basin in Alabama. In the area of interest, coalbed methane is produced mainly from the Black Creek, Mary Lee, and Pratt coal zones at depths between 400 and 700 m and approximately 3 m thick on average. The permeability of coal in the Black Warrior basin decreases exponentially with depth as overburden stress increases. The permeability of the top layer is 100 mD, while the permeability of the deepest layer is around 1 mD. The pilot field test will include injecting a total of 1000 tons of CO{sub 2} into these three coal zones ({approx}300 tons to each zone). The density, sonic and resistivity well-logs from a deep disposal well a couple of miles from the pilot test site were used to create background (pre-injection) models. Our laboratory measurements of seismic velocity and electrical resistivity as a function of CO{sub 2} saturation on coal core samples were used to provide a link between the coalbed CO{sub 2} flow simulation models and the geophysical models. The sensitivity studies showed that while the response to the 300 tons of CO{sub 2} injected into a single layer wouldn't produce measurable surface response for either gravity or EM, the response due to an industrial-size injection would produce measurable surface signal for both techniques. Gravity inversion results illustrated that, provided we can collect high-quality gravity data in the field and we have some a priori information about the depth of the reservoir, we can recover the spatial location of CO{sub 2} plume correctly, although with the smoothing constraint of the inversion, the area was slightly overestimated, resulting in an underestimated value of density change. AVA analysis showed that by inverting seismic and EM data jointly, much better estimates of CO{sub 2} saturation can be obtained, especially in the third injection zone, where seismic AVA data fail to detect the high CO{sub 2} saturation. Analysis of spatial resolution and detectability limits show that gravity and EM measurements could, under certain circumstances, be used as a lower-cost alternative to seismic measurements.

  2. Modeling Coal Matrix Shrinkage and Differential Swelling with CO2 Injection for Enhanced Coalbed Methane Recovery and Carbon Sequestration Applications

    SciTech Connect (OSTI)

    L. J. Pekot; S. R. Reeves

    2002-03-31T23:59:59.000Z

    Matrix shrinkage and swelling can cause profound changes in porosity and permeability of coalbed methane reservoirs during depletion or when under CO{sub 2} injection processes, with significant implication for primary or enhanced methane recovery. Two models that are used to describe these effects are discussed. The first was developed by Advanced Resources International (ARI) and published in 1990 by Sawyer, et al. The second model was published by Palmer and Mansoori in 1996. This paper shows that the two provide equivalent results for most applications. However, their differences in formulation cause each to have relative advantages and disadvantages under certain circumstances. Specifically, the former appears superior for undersaturated coalbed methane reservoirs while the latter would be better if a case is found where matrix swelling is strongly disproportional to gas concentration. Since its presentation in 1996, the Palmer and Mansoori model has justifiably received much critical praise. However, the model developed by ARI for the COMET reservoir simulation program has been in use since 1990, and has significant advantages in certain settings. A review of data published by Levine in 1996 reveals that carbon dioxide causes a greater degree of coal matrix swelling compared to methane, even when measured on a unit of concentration basis. This effect is described in this report as differential swelling. Differential swelling may have important consequences for enhanced coalbed methane and carbon sequestration projects. To handle the effects of differential swelling, an extension to the matrix shrinkage and swelling model used by the COMET simulator is presented and shown to replicate the data of Levine. Preliminary field results from a carbon dioxide injection project are also presented in support of the extended model. The field evidence supports that considerable changes to coal permeability occur with CO{sub 2} injection, with significant implication for the design, implementation and performance of enhanced coalbed methane recovery and CO{sub 2} sequestration projects.

  3. 4-D High-Resolution Seismic Reflection Monitoring of Miscible CO2 Injected into a Carbonate Reservoir

    SciTech Connect (OSTI)

    Richard D. Miller; Abdelmoneam E. Raef; Alan P. Byrnes; William E. Harrison

    2007-06-30T23:59:59.000Z

    The objective of this research project was to acquire, process, and interpret multiple high-resolution 3-D compressional wave and 2-D, 2-C shear wave seismic data in the hopes of observing changes in fluid characteristics in an oil field before, during, and after the miscible carbon dioxide (CO{sub 2}) flood that began around December 1, 2003, as part of the DOE-sponsored Class Revisit Project (DOE No.DE-AC26-00BC15124). Unique and key to this imaging activity is the high-resolution nature of the seismic data, minimal deployment design, and the temporal sampling throughout the flood. The 900-m-deep test reservoir is located in central Kansas oomoldic limestones of the Lansing-Kansas City Group, deposited on a shallow marine shelf in Pennsylvanian time. After 30 months of seismic monitoring, one baseline and eight monitor surveys clearly detected changes that appear consistent with movement of CO{sub 2} as modeled with fluid simulators and observed in production data. Attribute analysis was a very useful tool in enhancing changes in seismic character present, but difficult to interpret on time amplitude slices. Lessons learned from and tools/techniques developed during this project will allow high-resolution seismic imaging to be routinely applied to many CO{sub 2} injection programs in a large percentage of shallow carbonate oil fields in the midcontinent.

  4. Ultra-low emittance beam generation using two-color ionization injection in a CO2 laser-driven plasma accelerator

    E-Print Network [OSTI]

    Schroeder, C B; Bulanov, S S; Chen, M; Esarey, E; Geddes, C G R; Vay, J -L; Yu, L -L; Leemans, W P

    2015-01-01T23:59:59.000Z

    Ultra-low emittance (tens of nm) beams can be generated in a plasma accelerator using ionization injection of electrons into a wakefield. An all-optical method of beam generation uses two laser pulses of different colors. A long-wavelength drive laser pulse (with a large ponderomotive force and small peak electric field) is used to excite a large wakefield without fully ionizing a gas, and a short-wavelength injection laser pulse (with a small ponderomotive force and large peak electric field), co-propagating and delayed with respect to the pump laser, to ionize a fraction of the remaining bound electrons at a trapped wake phase, generating an electron beam that is accelerated in the wake. The trapping condition, the ionized electron distribution, and the trapped bunch dynamics are discussed. Expressions for the beam transverse emittance, parallel and orthogonal to the ionization laser polarization, are presented. An example is shown using a 10-micron CO2 laser to drive the wake and a frequency-doubled Ti:Al2...

  5. Selection of coals of different maturities for CO2 Storage by modelling of CH4 and CO2 adsorption isotherms

    E-Print Network [OSTI]

    Paris-Sud XI, Université de

    rue de la Férollerie, 45072 Orléans Cedex, France Abstract CO2 injection in unmineable coal seams capacities on various coals for the future modelling of CO2 injection in coal seams. Keywords: CO2 storage is estimated from 3 up to 200 GtCO2 therefore CO2 storage in coal seams is one of the potential types

  6. CO2 leakage through existing wells: current technology and regulations S. Taku Ide1

    E-Print Network [OSTI]

    for the most likely features, events and processes that affect well integrity after initial CO2 injection. As long as the #12;integrity of the cap rock is not compromised by permeable conduits like wellsCO2 leakage through existing wells: current technology and regulations S. Taku Ide1 , S. Julio

  7. International Symposium on Site Characterization for CO2 Geological Storage

    E-Print Network [OSTI]

    Tsang, Chin-Fu

    2006-01-01T23:59:59.000Z

    CONSTRAIN CO2 INJECTION FEASIBILITY: TEAPOT DOME EOR PILOTEOR, and coupled process modeling will investigate the total system including preliminary estimates of CO2

  8. numerical methodology to model and monitor co2 sequestration

    E-Print Network [OSTI]

    santos,,,

    CO2 sequestration is a means of mitigating the greenhouse effect [1]. Geologic sequestration involves injecting CO2 into a target geologic formation at depths ...

  9. Numerical modeling of injection and mineral trapping of CO2 withH2S and SO2 in a Sandstone Formation

    SciTech Connect (OSTI)

    Xu, Tianfu; Apps, John A.; Pruess, Karsten; Yamamoto, Hajime

    2004-09-07T23:59:59.000Z

    Carbon dioxide (CO{sub 2}) injection into deep geologic formations could decrease the atmospheric accumulation of this gas from anthropogenic sources. Furthermore, by co-injecting H{sub 2}S or SO{sub 2}, the products respectively of coal gasification or combustion, with captured CO{sub 2}, problems associated with surface disposal would be mitigated. We developed models that simulate the co-injection of H{sub 2}S or SO{sub 2} with CO{sub 2} into an arkose formation at a depth of about 2 km and 75 C. The hydrogeology and mineralogy of the injected formation are typical of those encountered in Gulf Coast aquifers of the United States. Six numerical simulations of a simplified 1-D radial region surrounding the injection well were performed. The injection of CO{sub 2} alone or co-injection with SO{sub 2} or H{sub 2}S results in a concentrically zoned distribution of secondary minerals surrounding a leached and acidified region adjacent to the injection well. Co-injection of SO{sub 2} with CO{sub 2} results in a larger and more strongly acidified zone, and alteration differs substantially from that caused by the co-injection of H{sub 2}S or injection of CO{sub 2} alone. Precipitation of carbonates occurs within a higher pH (pH > 5) peripheral zone. Significant quantities of CO{sub 2} are sequestered by ankerite, dawsonite, and lesser siderite. The CO{sub 2} mineral-trapping capacity of the formation can attain 40-50 kg/m{sup 3} medium for the selected arkose. In contrast, secondary sulfates precipitate at lower pH (pH < 5) within the acidified zone. Most of the injected SO{sub 2} is transformed and immobilized through alunite precipitation with lesser amounts of anhydrite and minor quantities of pyrite. The dissolved CO{sub 2} increases with time (enhanced solubility trapping). The mineral alteration induced by injection of CO{sub 2} with either SO{sub 2} or H{sub 2}S leads to corresponding changes in porosity. Significant increases in porosity occur in the acidified zones where mineral dissolution dominates. With co-injection of SO{sub 2}, the porosity increases from an initial 0.3 to 0.43 after 100 years. However, within the CO{sub 2} mineral-trapping zone, the porosity decreases to about 0.28 for both cases, because of the addition of CO{sub 2} mass as secondary carbonates to the rock matrix. Precipitation of sulfates at the acidification front causes porosity to decrease to 0.23. The limited information currently available on the mineralogy of naturally occurring high-pressure CO{sub 2} reservoirs is generally consistent with our simulations.

  10. Synthetic versus real time-lapse seismic data at the Sleipner CO2 injection site. R. J. Arts*, TNO-Geological Survey of the Netherlands & Delft University of Technology, R.A. Chadwick,

    E-Print Network [OSTI]

    Santos, Juan

    , each up to a few metres thick. Quantitative seismic interpretation of the time-lapse data has included km2 . Previous interpretations of the seismic data (Arts et al., 2004; Chadwick et al. 2004; 2005Synthetic versus real time-lapse seismic data at the Sleipner CO2 injection site. R. J. Arts*, TNO

  11. System-level modeling for geological storage of CO2

    E-Print Network [OSTI]

    Zhang, Yingqi; Oldenburg, Curtis M.; Finsterle, Stefan; Bodvarsson, Gudmundur S.

    2006-01-01T23:59:59.000Z

    of Geologic Storage of CO2, in Carbon Dioxide Capture forFormations - Results from the CO2 Capture Project: GeologicBenson, Process Modeling of CO2 Injection into Natural Gas

  12. Changes in the chemistry of shallow groundwater related to the 2008 injection of CO2 at the ZERT field site, Bozeman, Montana

    E-Print Network [OSTI]

    2010-01-01T23:59:59.000Z

    including BTEX from depleted oil reservoirs and non oil-of CO 2 in a depleted oil reservoir, New Mexico. USA Appl

  13. Changes in the chemistry of shallow groundwater related to the 2008 injection of CO2 at the ZERT Field Site, Bozeman, Montana

    E-Print Network [OSTI]

    Kharaka, Y.K.

    2010-01-01T23:59:59.000Z

    including BTEX from depleted oil reservoirs and non oil-of CO 2 in a depleted oil reservoir, New Mexico, USA Applied

  14. Study of CO2 Mobility Control in Heterogeneous Media Using CO2 Thickening Agents

    E-Print Network [OSTI]

    Al Yousef, Zuhair

    2012-10-19T23:59:59.000Z

    CO2 injection is an effective method for performing enhanced oil recovery (EOR). There are several factors that make CO2 useful for EOR, including promoting swelling, reducing oil viscosity, decreasing oil density, and vaporizing and extracting...

  15. Design and Implementation of a CO2 Flood Utilizing Advanced Reservoir Characterization and Horizontal Injection Wells In a Shallow Shelf Carbonate Approaching Waterflood Depletion, Class II

    SciTech Connect (OSTI)

    Czirr, K.L.; Gaddis, M.P.; Moshell, M.K.

    2002-02-21T23:59:59.000Z

    The principle objective of this project is to demonstrate the economic viability and widespread applicability of an innovative reservoir management and carbon dioxide (CO2) flood project development approach for improving CO2 flood project economics in shallow shelf carbonate (SSC) reservoirs.

  16. Near Miscible CO2 Application to Improve Oil Recovery

    E-Print Network [OSTI]

    Bui, Ly H.

    2010-07-26T23:59:59.000Z

    Carbon dioxide (CO2) injection for enhanced oil recovery is a proven technology. CO2 injection is normally operated at a pressure above the minimum miscibility pressure (MMP), which is determined by crude oil composition and reservoir conditions...

  17. Gravity monitoring of CO2 movement during sequestration: Model studies

    E-Print Network [OSTI]

    Gasperikova, E.

    2008-01-01T23:59:59.000Z

    form of enhanced petroleum production as CO 2 is injected.for monitoring production in petroleum reservoirs. The cost

  18. A model comparison initiative for a CO2 injection field test: An introduction to Sim-SEQ

    E-Print Network [OSTI]

    Mukhopadhyay, S.

    2013-01-01T23:59:59.000Z

    Energy's Regional Carbon Sequestration Partnerships Programimplications for carbon sequestration, Environmental Earthtrapping for geologic carbon sequestration, International

  19. A model comparison initiative for a CO2 injection field test: An introduction to Sim-SEQ

    E-Print Network [OSTI]

    Mukhopadhyay, S.

    2013-01-01T23:59:59.000Z

    characterization data, as well as review of monitoring data as they become available, (2) conversion of the geological

  20. A model comparison initiative for a CO2 injection field test: An introduction to Sim-SEQ

    E-Print Network [OSTI]

    Mukhopadhyay, S.

    2013-01-01T23:59:59.000Z

    boundary conditions, rock properties, etc. , were given.linkages between rock properties, pressure, gravity, andconditions, rock and fluid properties, etc. , in addition to

  1. A Review of Hazardous Chemical Species Associated with CO2 Capturefrom Coal-Fired Power Plants and Their Potential Fate in CO2 GeologicStorage

    SciTech Connect (OSTI)

    Apps, J.A.

    2006-02-23T23:59:59.000Z

    Conventional coal-burning power plants are major contributors of excess CO2 to the atmospheric inventory. Because such plants are stationary, they are particularly amenable to CO2 capture and disposal by deep injection into confined geologic formations. However, the energy penalty for CO2 separation and compression is steep, and could lead to a 30-40 percent reduction in useable power output. Integrated gas combined cycle (IGCC) plants are thermodynamically more efficient, i.e.,produce less CO2 for a given power output, and are more suitable for CO2 capture. Therefore, if CO2 capture and deep subsurface disposal were to be considered seriously, the preferred approach would be to build replacement IGCC plants with integrated CO2 capture, rather than retrofit existing conventional plants. Coal contains minor quantities of sulfur and nitrogen compounds, which are of concern, as their release into the atmosphere leads to the formation of urban ozone and acid rain, the destruction of stratospheric ozone, and global warming. Coal also contains many trace elements that are potentially hazardous to human health and the environment. During CO2 separation and capture, these constituents could inadvertently contaminate the separated CO2 and be co-injected. The concentrations and speciation of the co-injected contaminants would differ markedly, depending on whether CO2 is captured during the operation of a conventional or an IGCC plant, and the specific nature of the plant design and CO2 separation technology. However, regardless of plant design or separation procedures, most of the hazardous constituents effectively partition into the solid waste residue. This would lead to an approximately two order of magnitude reduction in contaminant concentration compared with that present in the coal. Potential exceptions are Hg in conventional plants, and Hg and possibly Cd, Mo and Pb in IGCC plants. CO2 capture and injection disposal could afford an opportunity to deliberately capture environmental pollutants in the gaseous state and co-inject them with the CO2, in order to mitigate problems associated with solid waste disposal in surface impoundments. Under such conditions, the injected pollutant concentrations could be roughly equivalent to their concentrations in the coal feed. The fate of the injected contaminants can only be determined through further testing and geochemical modeling. However, the concentrations of inadvertent contaminants in the injected CO2 would probably be comparable to their ambient concentrations in confining shales of the injection zone. In general, the aqueous concentrations of hazardous constituents in distal parts of the injection zone, regardless of source, are likely to be limited by equilibrium with respect to coexisting solid phases under the acid conditions induced by the dissolved high pressure CO2, rather than by the initial concentrations of injected contaminants. Therefore, even if a deliberate policy of contaminant recovery and injection were to be pursued, water quality in USDWs would more likely depend on thermodynamic controls governing aqueous contaminant concentrations in the presence of high pressure CO2 rather than in the injected CO2. The conclusions reached in this report are preliminary, and should be confirmed through more comprehensive data evaluation and supporting geochemical modeling.

  2. Design and Implementation of a CO(2) Flood Utilizing Advanced Reservoir Characterization and Horizontal Injection Wells in Shallow Shelf Carbonate Approaching Waterflood Depletion

    SciTech Connect (OSTI)

    NONE

    1997-12-31T23:59:59.000Z

    The work reported herein covers select tasks in Budget Phase 11. The principle Task in Budget Phase 11 included in this report is Field Demonstration. Completion of many of the Field Demonstration tasks during the last report period enabled an optimum carbon dioxide (CO{sub 2}) flood project to be designed, economically evaluated, and implemented in the field. Field implementation of the project commenced during late 1995, with actual C0{sub 2} injection commencing in mid-July, 1996. This report summarizes activities incurred following initial project start-up, towards the goal of optimizing project performance. The current project has focused on reducing initial investment cost by utilizing horizontal injection wells and concentrating the project in the best productivity area of the field. An innovative C0{sub 2} purchase agreement (no take-or-pay provisions, C0{sub 2} purchase price tied to West Texas Intermediate (WTI) crude oil price) and gas recycle agreement (expensing costs as opposed to a large upfront capital investment for compression) were negotiated to further improve the project economics. The Grayburg-San Andres section had previously been divided into multiple zones based on the core study and gamma ray markers that correlate wells within the Unit. Each zone was mapped as continuous across the field. Previous core studies concluded that the reservoir quality in the South Cowden Unit (SCU) is controlled primarily by the distribution of a bioturbated and diagenetically-altered rock type with a distinctive chaotic texture. The chaotic modifier is derived from the visual effect of pervasive, small-scale intermixing of tan oil-stained reservoir rock with tight gray non- reservoir rock. The chaotic reservoir rock extends from Zone C (4780`-4800`) to the lower part of Zone F (4640`-4680`). Zones D (4755`-4780`) and E (4680`-4755`) are considered the main floodable zones, though Zone F is also productive and Zone C is productive above the oil- water contact. During Budget Phase 1, the Stratamodel computer program was utilized as the primary tool to integrate the diverse geologic, petrophysical, and seismic data into a coherent three dimensional (3-D) model. The basic porosity model having been constructed, critiqued and modified based on field production and detailed cross-section displays, permeability data was imported into the model, and a 3-D interpolation of the permeability was completed.

  3. Dynamics of CO2 fluxes and concentrations during a shallow subsurface CO2 release

    SciTech Connect (OSTI)

    Lewicki, J.L.; Hilley, G.E.; Dobeck, L.; Spangler, L.

    2009-09-01T23:59:59.000Z

    A field facility located in Bozeman, Montana provides the opportunity to test methods to detect, locate, and quantify potential CO2 leakage from geologic storage sites. From 9 July to 7 August 2008, 0.3 t CO2 d{sup -1} were injected from a 100-m long, {approx}2.5 m deep horizontal well. Repeated measurements of soil CO2 fluxes on a grid characterized the spatio-temporal evolution of the surface leakage signal and quantified the surface leakage rate. Infrared CO2 concentration sensors installed in the soil at 30 cm depth at 0 to 10 m from the well and at 4 cm above the ground at 0 and 5 m from the well recorded surface breakthrough of CO2 leakage and migration of CO2 leakage through the soil. Temporal variations in CO2 concentrations were correlated with atmospheric and soil temperature, wind speed, atmospheric pressure, rainfall, and CO2 injection rate.

  4. CO2 sequestration | EMSL

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    CO2 sequestration CO2 sequestration Leads No leads are available at this time. Low-Temperature Carbon Monoxide Oxidation Catalysed by Regenerable Atomically Dispersed Palladium on...

  5. CO2 Sequestration Modeling Using Pattern Recognition and Data Mining;

    E-Print Network [OSTI]

    Mohaghegh, Shahab

    carbon dioxide (CO2) sequestration process is to ensure a sustained confinement of the injected CO2CO2 Sequestration Modeling Using Pattern Recognition and Data Mining; Case Study of SACROC field, USA Abstract Capturing carbon dioxide (CO2) from industrial and energy-related sources and depositing

  6. International Symposium on Site Characterization for CO2 Geological Storage

    E-Print Network [OSTI]

    Tsang, Chin-Fu

    2006-01-01T23:59:59.000Z

    157 WELL INTEGRITY IN CO 2 ENVIRONMENTS: PERFORMANCE, RISK,of CO 2 injection, wells integrity and long term behavior ofcan compromise the well integrity and thus its functional

  7. CO2 flood tests on whole core samples of the Mt. Simon sandstone, Illinois Basin

    SciTech Connect (OSTI)

    O'Connor, William K.; Rush, Gilbert E.

    2005-09-01T23:59:59.000Z

    Geological sequestration of CO2, whether by enhanced oil recovery (EOR), coal-bed methane (CBM) recovery, or saline aquifer injection is a promising near-term sequestration methodology. While tremendous experience exists for EOR, and CBM recovery has been demonstrated in existing fields, saline aquifer injection studies have only recently been initiated. Studies evaluating the availability of saline aquifers suitable for CO2 injection show great potential, however, the long-term fate of the CO2 injected into these ancient aqueous systems is still uncertain. For the subject study, a series of laboratory-scale CO2 flood tests were conducted on whole core samples of the Mt. Simon sandstone from the Illinois Basin. By conducting these tests on whole core samples rather than crushed core, an evaluation of the impact of the CO2 flood on the rock mechanics properties as well as the geochemistry of the core and brine solution has been possible. This empirical data could provide a valuable resource for the validation of reservoir models under development for these engineered CO2 systems.

  8. Reactive transport modeling to study changes in water chemistry induced by CO2 injection at the Frio-I brine pilot

    SciTech Connect (OSTI)

    Kharaka, Y.K; Doughty, C.; Freifeld, B.M.; Daley, T.M.; Xu, T.

    2009-11-01T23:59:59.000Z

    To demonstrate the potential for geologic storage of CO{sub 2} in saline aquifers, the Frio-I Brine Pilot was conducted, during which 1600 tons of CO{sub 2} were injected into a high-permeability sandstone and the resulting subsurface plume of CO{sub 2} was monitored using a variety of hydrogeological, geophysical, and geochemical techniques. Fluid samples were obtained before CO{sub 2} injection for baseline geochemical characterization, during the CO{sub 2} injection to track its breakthrough at a nearby observation well, and after injection to investigate changes in fluid composition and potential leakage into an overlying zone. Following CO{sub 2} breakthrough at the observation well, brine samples showed sharp drops in pH, pronounced increases in HCO{sub 3}{sup -} and aqueous Fe, and significant shifts in the isotopic compositions of H{sub 2}O and dissolved inorganic carbon. Based on a calibrated 1-D radial flow model, reactive transport modeling was performed for the Frio-I Brine Pilot. A simple kinetic model of Fe release from the solid to aqueous phase was developed, which can reproduce the observed increases in aqueous Fe concentration. Brine samples collected after half a year had lower Fe concentrations due to carbonate precipitation, and this trend can be also captured by our modeling. The paper provides a method for estimating potential mobile Fe inventory, and its bounding concentration in the storage formation from limited observation data. Long-term simulations show that the CO{sub 2} plume gradually spreads outward due to capillary forces, and the gas saturation gradually decreases due to its dissolution and precipitation of carbonates. The gas phase is predicted to disappear after 500 years. Elevated aqueous CO{sub 2} concentrations remain for a longer time, but eventually decrease due to carbonate precipitation. For the Frio-I Brine Pilot, all injected CO{sub 2} could ultimately be sequestered as carbonate minerals.

  9. DESIGN AND IMPLEMENTATION OF A CO2 FLOOD UTILIZING ADVANCED RESERVOIR CHARACTERIZATION AND HORIZONTAL INJECTION WELLS IN A SHALLOW SHELF CARBONATE APPROACHING WATERFLOOD DEPLETION

    SciTech Connect (OSTI)

    K.J. Harpole; Ed G. Durrett; Susan Snow; J.S. Bles; Carlon Robertson; C.D. Caldwell; D.J. Harms; R.L. King; B.A. Baldwin; D. Wegener; M. Navarrette

    2002-09-01T23:59:59.000Z

    The purpose of this project was to economically design an optimum carbon dioxide (CO{sub 2}) flood for a mature waterflood nearing its economic abandonment. The original project utilized advanced reservoir characterization and CO{sub 2} horizontal injection wells as the primary methods to redevelop the South Cowden Unit (SCU). The development plans; project implementation and reservoir management techniques were to be transferred to the public domain to assist in preventing premature abandonment of similar fields. The Unit was a mature waterflood with water cut exceeding 95%. Oil must be mobilized through the use of a miscible or near-miscible fluid to recover significant additional reserves. Also, because the unit was relatively small, it did not have the benefit of economies of scale inherent in normal larger scale projects. Thus, new and innovative methods were required to reduce investment and operating costs. Two primary methods used to accomplish improved economics were use of reservoir characterization to restrict the flood to the higher quality rock in the unit and use of horizontal injection wells to cut investment and operating costs. The project consisted of two budget phases. Budget Phase I started in June 1994 and ended late June 1996. In this phase Reservoir Analysis, Characterization Tasks and Advanced Technology Definition Tasks were completed. Completion enabled the project to be designed, evaluated, and an Authority for Expenditure (AFE) for project implementation submitted to working interest owners for approval. Budget Phase II consisted of the implementation and execution of the project in the field. Phase II was completed in July 2001. Performance monitoring, during Phase II, by mid 1998 identified the majority of producing wells which under performed their anticipated withdrawal rates. Newly drilled and re-activated wells had lower offtake rates than originally forecasted. As a result of poor offtake, higher reservoir pressure was a concern for the project as it limited CO{sub 2} injectivity. To reduce voidage balance, and reservoir pressure, a disposal well was therefore drilled. Several injection surveys indicated the CO{sub 2} injection wells had severe conformance issues. After close monitoring of the project to the end of 1999, it was evident the project would not recover the anticipated tertiary reserves. The main reasons for under-performance were poor in zone CO{sub 2} injection into the upper San Andres layers, poorer offtake rates from newly drilled replacement wells and a higher than required reservoir pressure. After discussion internally within Phillips, externally with the Department of Energy (DOE) and SCU partners, a redevelopment of South Cowden was agreed upon to commence in year 2000. The redevelopment essentially abandoned the original development for Budget Phase II in favor of a revised approach. This involved conformance techniques to resolve out of zone CO{sub 2} injection and use of horizontal wells to improve in zone injectivity and productivity. A phased approach was used to ensure short radius lateral drilling could be implemented effectively at South Cowden. This involved monitoring drilling operations and then production response to determine if larger investments during the second phase were justified. Redevelopment Phase 1 was completed in May 2000. It was deemed a success in regard to finding suitable/cost-effective technology for drilling horizontal laterals and finding a technique that could sustain long-term productivity from the upper layers of the San Andres reservoir. Four existing vertical producing wells were isolated from their existing completions and sidetracked with horizontal laterals into the upper layers of the San Andres. Overall average offtake rates for the four wells increased by a factor of 12 during the first four months after completion of Phase 1. Phase 2 of the redevelopment focused on current CO{sub 2} vertical injection wells. Techniques were applied to resolve near well conformance concerns and then either single or dual laterals were dril

  10. BNL | CO2 Laser

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    CO2 Laser The ATF is one of the only two facilities worldwide operating picosecond, terawatt-class CO2 lasers. Our laser system consists of a picoseconds pulse-injector based on...

  11. EA-1886: Big Sky Regional Carbon Sequestration Partnership- Phase III: Large Volume CO2 Injection-Site Characterization, Well Drilling, and Infrastructure Development, Injection, MVA, and Site Closure, Kevin Dome, Toole County, Montana

    Broader source: Energy.gov [DOE]

    This EA will evaluate the environmental impacts of a proposal for the Big Sky Carbon Sequestration Regional Partnership to demonstrate the viability and safety of CO2 storage in a regionally significant subsurface formation in Toole County, Montana and to promote the commercialization of future anthropogenic carbon storage in this region.

  12. Investigation of feasibility of injecting power plant waste gases for enhanced coalbed methane recovery from low rank coals in Texas

    E-Print Network [OSTI]

    Saugier, Luke Duncan

    2004-09-30T23:59:59.000Z

    such as power plants. CO2 emissions can be offset by sequestration of produced CO2 in natural reservoirs such as coal seams, which may initially contain methane. Production of coalbed methane can be enhanced through CO2 injection, providing an opportunity...

  13. DOI: 10.1002/cssc.201000032 The Immobility of CO2 in Marine Sediments Beneath 1500

    E-Print Network [OSTI]

    Schrag, Daniel

    to capture CO2 produced at indus- trial facilities and approaches to inject the CO2 into geologic of buoyant CO2 in terrestrial reservoirs that often contain fractures, faults, and abandoned wells and may

  14. CO2 Sequestration in Unmineable Coal Seams: Potential Environmental Impacts

    SciTech Connect (OSTI)

    Hedges, S.W.; Soong, Yee; McCarthy Jones, J.R.; Harrison, D.K.; Irdi, G.A.; Frommell, E.A.; Dilmore, R.M.; Pique, P.J.; Brown, T.D

    2005-09-01T23:59:59.000Z

    An initial investigation into the potential environmental impacts of CO2 sequestration in unmineable coal seams has been conducted, focusing on changes in the produced water during enhanced coalbed methane (ECBM) production using a CO2 injection process (CO2-ECBM). Two coals have been used in this study, the medium volatile bituminous Upper Freeport coal (APCS 1) of the Argonne Premium Coal Samples series, and an as-mined Pittsburgh #8 coal, which is a high volatile bituminous coal. Coal samples were reacted with either synthetic produced water or field collected produced water and gaseous carbon dioxide at 40 ?C and 50 bar to evaluate the potential for mobilizing toxic metals during CO2-ECBM/sequestration. Microscopic and x-ray diffraction analysis of the post-reaction coal samples clearly show evidence of chemical reaction, and chemical analysis of the produced water shows substantial changes in composition. These results suggest that changes to the produced water chemistry and the potential for mobilizing toxic trace elements from coalbeds are important factors to be considered when evaluating deep, unmineable coal seams for CO2 sequestration.

  15. ORIGINAL ARTICLE Navajo SandstonebrineCO2 interaction: implications

    E-Print Network [OSTI]

    Zhu, Chen

    ORIGINAL ARTICLE Navajo Sandstone­brine­CO2 interaction: implications for geological carbon to the injected CO2 is largely unknown. Experiments involving the reac- tion of Navajo Sandstone with acidic brine experiment examined sandstone interaction with CO2-impregnated brine; the second experiment examined

  16. Spatio-temporal changes in CO2 emissions during the second ZERT...

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    Spatio-temporal changes in CO2 emissions during the second ZERT injection, August-September 2008. Spatio-temporal changes in CO2 emissions during the second ZERT injection,...

  17. Life Cycle Inventory of CO2 in an Enhanced Oil Recovery System

    E-Print Network [OSTI]

    Jaramillo, Paulina

    identified as a method of sequestering CO2 recovered from power plants. In CO2- flood EOR, CO2 is injected in EOR projects, thus reducing the amount of CO2 emitted into the atmosphere. This claim, however with sequestration via CO2- flood EOR under a number of different scenarios and explores the impact of various

  18. CO2.indd

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    STORAGE & ENHANCED OIL RECOVERY Objective R MOTC can play a signifi cant role in carbon dioxide (CO 2 ) storage and enhanced oil recovery technology development and fi eld...

  19. EMSL - CO2 sequestration

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    co2-sequestration en Low-Temperature Carbon Monoxide Oxidation Catalysed by Regenerable Atomically Dispersed Palladium on Alumina. http:www.emsl.pnl.govemslwebpublications...

  20. Mulitdimensional reactive transport modeling of CO2 minreal sequestration in basalts at the Helllisheidi geothermal field, Iceland

    E-Print Network [OSTI]

    Aradottir, E.S.P.

    2013-01-01T23:59:59.000Z

    geothermal power plant. In simulations of the pilot CO 2simulation of a 10 year full-scale CO 2 injection from Hellisheidi power plant. (

  1. Evaluating the Suitability for CO2 Storage at the FutureGen 2.0 Site, Morgan County, Illinois, USA

    SciTech Connect (OSTI)

    Bonneville, Alain; Gilmore, Tyler J.; Sullivan, E. C.; Vermeul, Vincent R.; Kelley, Mark E.; White, Signe K.; Appriou, Delphine; Bjornstad, Bruce N.; Gerst, Jacqueline L.; Gupta, Neeraj; Horner, Jacob A.; McNeil, Caitlin; Moody, Mark A.; Rike, William M.; Spane, Frank A.; Thorne, Paul D.; Zeller, Evan R.; Zhang, Z. F.; Hoffman, Jeffrey; Humphreys, Kenneth K.

    2013-08-05T23:59:59.000Z

    FutureGen 2.0 site will be the first near-zero emission power plant with fully integrated long-term storage in a deep, non-potable saline aquifer in the United States. The proposed FutureGen 2.0 CO2 storage site is located in northeast Morgan County, Illinois, U.S.A., forty-eight kilometres from the Meredosia Energy Center where a large-scale oxy-combustion demonstration will be conducted. The demonstration will involve > 90% carbon capture, which will produce more than one million metric tons (MMT) of CO2 per year. The CO2 will be compressed at the power plant and transported via pipeline to the storage site. To examine CO2 storage potential of the site, a 1,467m characterization well (FGA#1) was completed in December 2011. The target reservoir for CO2 storage is the Mt. Simon Sandstone and Elmhurst Sandstone Member of the lower Eau Claire Formation for a combined thickness of 176 m. Confining beds of the overlying Lombard and Proviso Members (upper Eau Claire Formation) reach a thickness of 126 m. Characterization of the target injection zone and the overlying confining zone was based on wellbore data, cores, and geophysical logs, along with surface geophysical (2-D seismic profiles, magnetic and gravity), and structural data collected during the initial stage of the project . Based on this geological model, 3D simulations of CO2 injection and redistribution were conducted using STOMP-CO2, a multiphase flow and transport simulator. After this characterization stage, it appears that the injection site is a suitable geologic system for CO2 sequestration and that the injection zone is sufficient to receive up to 33 MMT of CO2 at a rate of 1.1 MMT/yr. GHGT-11 conference

  2. amine methanol, ether . Amine amine CO2

    E-Print Network [OSTI]

    Hong, Deog Ki

    IP [2012] 7 C O 2 (CO2) . CO2 amine methanol, ether . Amine amine CO2 CO2 .Amine CO2 (functional group) amine amine+ +promoter .Amine CO2 CO2 . . , methanol ether methanol, ether promoter CO2 CO2 H2S, COS CO2 . Methanol rectisol process, di-methylene ether polypropylene glycol selexol (-30oC) . CO2

  3. New ORNL Pellet Injection System and Installation/Initial Operations on MST

    SciTech Connect (OSTI)

    Combs, S.K. [Oak Ridge National Laboratory (United States); Baylor, L.R. [Oak Ridge National Laboratory (United States); Fehling, D.T. [Oak Ridge National Laboratory (United States); Fisher, P.W. [Oak Ridge National Laboratory (United States); Foust, C.R. [Oak Ridge National Laboratory (United States); Rasmussen, D.A. [Oak Ridge National Laboratory (United States); Wilgen, J.B. [Oak Ridge National Laboratory (United States); Chapman, B.E. [University of Wisconsin-Madison (United States); Oliva, S.P. [University of Wisconsin-Madison (United States); Prager, S.C. [University of Wisconsin-Madison (United States); Sarff, J.S. [University of Wisconsin-Madison (United States); Wyman, M.D. [University of Wisconsin-Madison (United States); Brower, D.L. [University of California-Los Angeles (United States); Ding, W.X. [University of California-Los Angeles (United States); Terry, S.D. [University of California-Los Angeles (United States); Deng, B.H. [University of California-Los Angeles (United States)

    2003-09-15T23:59:59.000Z

    A compact pellet injection system that was recently developed at the Oak Ridge National Laboratory has been installed on the Madison Symmetric Torus (MST) at University of Wisconsin and used in initial plasma fueling experiments. The system, referred to as a ''pellet injector in a suitcase,'' is a pipe gun device with a four-barrel capability (presently equipped with two 1.0-mm-bore barrels), and it uses a cryogenic refrigerator for in-situ hydrogen pellet formation (typically, D{sub 2} pellets). This new, portable, stand-alone pellet injection system was developed to provide a flexible means of plasma fueling on a wide variety of magnetic confinement devices, with relatively low costs for installation and operation. The injector has already been used to produce useful results with pellets on MST plasmas, including significant and rapid increases (almost 100%) in the line average density, and effectively depositing fuel in the plasma core (central densities of [approximately equal to] 1.4 x 10{sup 19} m{sup -3}). In this paper, the injection system, its performance, and reliability will be described, and results from some initial MST pellet experiments will be highlighted.

  4. Co2 geological sequestration

    SciTech Connect (OSTI)

    Xu, Tianfu

    2004-11-18T23:59:59.000Z

    Human activities are increasingly altering the Earth's climate. A particular concern is that atmospheric concentrations of carbon dioxide (CO{sub 2}) may be rising fast because of increased industrialization. CO{sub 2} is a so-called ''greenhouse gas'' that traps infrared radiation and may contribute to global warming. Scientists project that greenhouse gases such as CO{sub 2} will make the arctic warmer, which would melt glaciers and raise sea levels. Evidence suggests that climate change may already have begun to affect ecosystems and wildlife around the world. Some animal species are moving from one habitat to another to adapt to warmer temperatures. Future warming is likely to exceed the ability of many species to migrate or adjust. Human production of CO{sub 2} from fossil fuels (such as at coal-fired power plants) is not likely to slow down soon. It is urgent to find somewhere besides the atmosphere to put these increased levels of CO{sub 2}. Sequestration in the ocean and in soils and forests are possibilities, but another option, sequestration in geological formations, may also be an important solution. Such formations could include depleted oil and gas reservoirs, unmineable coal seams, and deep saline aquifers. In many cases, injection of CO2 into a geological formation can enhance the recovery of hydrocarbons, providing value-added byproducts that can offset the cost of CO{sub 2} capture and sequestration. Before CO{sub 2} gas can be sequestered from power plants and other point sources, it must be captured. CO{sub 2} is also routinely separated and captured as a by-product from industrial processes such as synthetic ammonia production, H{sub 2} production, and limestone calcination. Then CO{sub 2} must be compressed into liquid form and transported to the geological sequestration site. Many power plants and other large emitters of CO{sub 2} are located near geological formations that are amenable to CO{sub 2} sequestration.

  5. High Resolution Simulation and Characterization of Density-Driven Flow in CO2 Storage in Saline Aquifers

    E-Print Network [OSTI]

    are routinely used to study the process of carbon dioxide (CO2) sequestration in saline aquifers. In this paper TOUGH2-MP. 1. Introduction Geologic carbon dioxide (CO2) sequestration involves injecting CO2

  6. Post-Combustion CO2 Capture 11 -13 July 2010

    E-Print Network [OSTI]

    Post-Combustion CO2 Capture Workshop 11 - 13 July 2010 Tufts European Center Talloires, France Institute | | Clean Air Task Force | | Asia Clean Energy Innovation Initiative | #12;Post-Combustion CO2 Capture Workshop 11 - 13 July 2010 Talloires, France PROCEEDINGS: Post-Combustion CO2 Capture Workshop

  7. THE ECONOMICS OF CO2 SEPARATION AND CAPTURE Howard J. Herzog

    E-Print Network [OSTI]

    economic source of CO2, especially for use in enhanced oil recovery (EOR) operations where CO2 is injected the price of oil dropped in the mid-1980s, the recovered CO2 was too expensive for EOR operations, forcingTHE ECONOMICS OF CO2 SEPARATION AND CAPTURE Howard J. Herzog Principal Research Engineer MIT Energy

  8. A numerical procedure to model and monitor CO2 sequestration in

    E-Print Network [OSTI]

    Santos, Juan

    sequestration over very long periods of time. · The analysis of CO2 underground storage safety in the long term procedure to model and monitor CO2 sequestration in aquifers ­ p. #12;Introduction. I · Storage of CO2 (31.6C, 7.38 MPa). · First industrial scale CO2 injection project: Sleipner gas field (North Sea

  9. A numerical procedure to model and monitor CO2 sequestration in aquifers

    E-Print Network [OSTI]

    Santos, Juan

    sequestration over very long periods of time. The analysis of CO2 underground storage safety in the long term procedure to model and monitor CO2 sequestration in aquifers ­ p. #12;Introduction. I Storage of CO2 (31.6C, 7.38 MPa). First industrial scale CO2 injection project: Sleipner gas field (North Sea

  10. Fayalite Dissolution and Siderite Formation in Water-Saturated Supercritical CO2

    SciTech Connect (OSTI)

    Qafoku, Odeta; Kovarik, Libor; Kukkadapu, Ravi K.; Ilton, Eugene S.; Arey, Bruce W.; Tucek, Jiri; Felmy, Andrew R.

    2012-11-25T23:59:59.000Z

    Olivines, a significant constituent of basaltic rocks, have the potential to immobilize permanently CO2 after it is injected in the deep subsurface, due to carbonation reactions occurring between CO2 and the host rock. To investigate the reactions of fayalitic olivine with supercritical CO2 (scCO2) and formation of mineral carbonates, experiments were conducted at temperatures of 35 °C to 80 °C, 90 atm pressure and anoxic conditions. For every temperature, the dissolution of fayalite was examined both in the presence of liquid water and H2O-saturated scCO2. The experiments were conducted in a high pressure batch reactor at reaction time extending up to 85 days. The newly formed products were characterized using a comprehensive suite of bulk and surface characterization techniques X-ray diffraction, Transmission/Emission Mössbauer Spectroscopy, Scanning Electron Microscopy coupled with Focused Ion Beam, and High Resolution Transmission Electron Microscopy. Siderite with rhombohedral morphology was formed at 35 °C, 50 °C, and 80 °C in the presence of liquid water and scCO2. In H2O-saturated scCO2, the formation of siderite was confirmed only at high temperature (80 °C). Characterization of reacted samples in H2O-saturated scCO2 with high resolution TEM indicated that siderite formation initiated inside voids created during the initial steps of fayalite dissolution. Later stages of fayalite dissolution result in the formation of siderite in layered vertical structures, columns or pyramids with a rhombus base morphology.

  11. Effects of carbon dioxide injection on the displacement of methane and carbonate dissolution in sandstone cores

    E-Print Network [OSTI]

    Maduakor, Ekene Obioma

    2006-10-30T23:59:59.000Z

    psig and temperature of 60oC using a 1 foot long and 1 inch diameter Berea sandstone core. Pure CO2 and treated flue gas (99.433 % mole CO2) were injected into the Berea sandstone core initially saturated with methane at a pressure of 1500 psig and 800...

  12. 24/02/2012 12:49SPE Projects, Facilities & Construction -CO2/Brine Surface Dissolution and Injection: CO2 Storage Enhancement Page 1 of 1http://www.spe.org/ejournals/jsp/journalapp.jsp?pageType=Preview&jid=EFC&pdfChronicleId=090147628022501b&mid=SPE-12471

    E-Print Network [OSTI]

    Haszeldine, Stuart

    24/02/2012 12:49SPE Projects, Facilities & Construction - CO2/Brine Surface Dissolution of Petroleum Engineers SPE Projects, Facilities & Construction Volume 6, Number 1, March 2011, pp. 41-53 SPE

  13. Exsolution Enhanced Oil Recovery with Concurrent CO2 Sequestration

    SciTech Connect (OSTI)

    Zuo, Lin; Benson, Sally M.

    2013-01-01T23:59:59.000Z

    A novel EOR method using carbonated water injection followed by depressurization is introduced. Results from micromodel experiments are presented to demonstrate the fundamental principles of this oil recovery method. A depressurization process (1 MPa/hr) was applied to a micromodel following carbonated water injection (Ca ? 10-5). The exsolved CO2 in water-filled pores blocked water flow in swiped portions and displaced water into oil-filled pores. Trapped oil after the carbonated water injection was mobilized by sequentially invading water. This method's self-distributed mobility control and local clogging was tested in a sandstone sample under reservoir conditions. A 10% incremental oil recovery was achieved by lowering the pressure 2 MPa below the CO2 liberation pressure. Additionally, exsolved CO2 resides in the pores of a reservoir as an immobile phase with a high residual saturation after oil production, exhibiting a potential synergy opportunity between CO2 EOR and CO2 sequestration

  14. International Symposium on Site Characterization for CO2 Geological Storage

    E-Print Network [OSTI]

    Tsang, Chin-Fu

    2006-01-01T23:59:59.000Z

    carbon dioxide-enhanced oil recovery project as a prototypeCO 2 injection for enhanced oil recovery. Indeed, most near-as well as Enhanced Oil Recovery projects. REFERENCES

  15. Improving CO2 Efficiency for Recovering Oil in Heterogeneous Reservoirs

    SciTech Connect (OSTI)

    Grigg, Reid B.; Svec, Robert K.

    2003-03-10T23:59:59.000Z

    The work strived to improve industry understanding of CO2 flooding mechanisms with the ultimate goal of economically recovering more of the U.S. oil reserves. The principle interests are in the related fields of mobility control and injectivity.

  16. Comparative Assessment of Status and Opportunities for CO2 Capture and Storage and Radioactive Waste Disposal in North America

    E-Print Network [OSTI]

    Oldenburg, C.

    2010-01-01T23:59:59.000Z

    coal-fired power plants will require multiple injection wells Pipeline as liquid CO 2 , injection through wells Liquid or supercritical

  17. CO2 interaction with aquifer and seal on geological timescales: the Miller oilfield, UK North Sea 

    E-Print Network [OSTI]

    Lu, Jiemin

    2008-01-01T23:59:59.000Z

    Carbon Capture and Storage (CCS) has been identified as a feasible technology to reduce CO2 emissions whilst permitting the continued use of fossil fuels. Injected CO2 must remain efficiently isolated from the atmosphere ...

  18. Influence of Rock Types on Seismic Monitoring of CO2 Sequestration in Carbonate Reservoirs 

    E-Print Network [OSTI]

    Mammadova, Elnara

    2012-10-19T23:59:59.000Z

    ) techniques such as high pressure CO2 injection may normally be required to recover oil in place in carbonate reservoirs. This study addresses how different rock types can influence the seismic monitoring of CO2 sequestration in carbonates. This research...

  19. Influence of Rock Types on Seismic Monitoring of CO2 Sequestration in Carbonate Reservoirs

    E-Print Network [OSTI]

    Mammadova, Elnara

    2012-10-19T23:59:59.000Z

    ) techniques such as high pressure CO2 injection may normally be required to recover oil in place in carbonate reservoirs. This study addresses how different rock types can influence the seismic monitoring of CO2 sequestration in carbonates. This research...

  20. Applications of mineral carbonation to geological sequestration of CO2

    SciTech Connect (OSTI)

    O'Connor, William K.; Rush, G.E.

    2005-01-01T23:59:59.000Z

    Geological sequestration of CO2 is a promising near-term sequestration methodology. However, migration of the CO2 beyond the natural reservoir seals could become problematic, thus the identification of means to enhance the natural seals could prove beneficial. Injection of a mineral reactant slurry could provide a means to enhance the natural reservoir seals by supplying the necessary cations for precipitation of mineral carbonates. The subject study evaluates the merit of several mineral slurry injection strategies by conduct of a series of laboratory-scale CO2 flood tests on whole core samples of the Mt. Simon sandstone from the Illinois Basin.

  1. Aquifer Management for CO2 Sequestration

    E-Print Network [OSTI]

    Anchliya, Abhishek

    2010-07-14T23:59:59.000Z

    to the Computer Modeling Group (CMG) and Kappa Engineering for providing the uninterrupted license of the software packages. I am grateful to Mr. Bob Brugman from CMG for his help with the GEM-GHG (Green House Gas) module of CMG. I would like to extend my... biological sinks of CO 2 and decreasing the carbon intensity of fossil fuels should be considered. Out of all the potential mitigation options for stabilizing atmospheric GHG concentrations, including injection into deep oceans, depleted oil reservoirs...

  2. Volumetric Properties and Fluid Phase Equilibria of CO2 + H2O

    SciTech Connect (OSTI)

    Capobianco, Ryan [Virginia Polytechnic Institute and State University; Gruszkiewicz, Miroslaw {Mirek} S [ORNL; Wesolowski, David J [ORNL; Cole, David R [ORNL; Bodnar, Robert [Virginia Polytechnic Institute and State University

    2013-01-01T23:59:59.000Z

    The need for accurate modeling of fluid-mineral processes over wide ranges of temperature, pressure and composition highlighted considerable uncertainties of available property data and equations of state, even for the CO2 + H2O binary system. In particular, the solubility, activity, and ionic dissociation equilibrium data for the CO2-rich phase, which are essential for understanding dissolution/precipitation, fluid-matrix reactions, and solute transport, are uncertain or missing. In this paper we report the results of a new experimental study of volumetric and phase equilibrium properties of CO2 + H2O, to be followed by measurements for bulk and confined multicomponent fluid mixtures. Mixture densities were measured by vibrating tube densimetry (VTD) over the entire composition range at T = 200 and 250 C and P = 20, 40, 60, and 80 MPa. Initial analysis of the mutual solubilities, determined from volumetric data, shows good agreement with earlier results for the aqueous phase, but finds that the data of Takenouchi and Kennedy (1964) significantly overestimated the solubility of water in supercritical CO2 (by a factor of more than two at 200 C). Resolving this well-known discrepancy will have a direct impact on the accuracy of predictive modeling of CO2 injection in geothermal reservoirs and geological carbon sequestration through improved equations of state, needed for calibration of predictive molecular-scale models and large-scale reactive transport simulations.

  3. ADJOINT BASED OPTIMAL CONTROL OF PARTIALLY MISCIBLE TWO-PHASE FLOW IN POROUS MEDIA WITH APPLICATIONS TO CO2

    E-Print Network [OSTI]

    Ulbrich, Michael

    WITH APPLICATIONS TO CO2 SEQUESTRATION IN UNDERGROUND RESERVOIRS MORITZ SIMON AND MICHAEL ULBRICH Abstract. With the target of optimizing CO2 sequestration in underground reservoirs, we investigate constrained optimal the amount of trapped CO2 in an underground reservoir after a fixed period of CO2 injection, while time

  4. An Introduction to CO2 Separation and Capture Technologies Howard Herzog

    E-Print Network [OSTI]

    recovery (EOR) operations where CO2 is injected into oil reservoirs to increase the mobility of the oil andAn Introduction to CO2 Separation and Capture Technologies Howard Herzog MIT Energy Laboratory August, 1999 In general, to economically sequester CO2 produced from power plants, one must first produce

  5. Seismic modeling to monitor CO2 geological storage: The Atzbach-Schwanenstadt gas field

    E-Print Network [OSTI]

    Santos, Juan

    ) and coal-bed methane production make CO2 geolog- ical storage cost-effective [e.g., Baines and Worden, describes the seismic properties of the reservoir rock saturated with CO2, methane and brine, and allows us response when injecting carbon dioxide (CO2) in a depleted gas reservoir. The petro-elastical model

  6. Constraining the density of CO2 within the Utsira formation using time-lapse gravity measurements

    E-Print Network [OSTI]

    Nooner, Scott

    best fit a high temperature forward model based on the seismically determined CO2 geometry, suggesting to study the behavior and physical properties of the injected CO2. The gravity measurements show1 Constraining the density of CO2 within the Utsira formation using time-lapse gravity measurements

  7. CO2 interaction with geomaterials.

    SciTech Connect (OSTI)

    Guthrie, George D. (U.S. Department of Energy, Pittsburgh, PA); Al-Saidi, Wissam A. (University of Pittsburgh, Pittsburgh, PA); Jordan, Kenneth D. (University of Pittsburgh, Pittsburgh, PA); Voora, Vamsee, K. (University of Pittsburgh, Pittsburgh, PA); Romanov, Vyacheslav N. (U.S. Department of Energy, Pittsburgh, PA); Lopano, Christina L (U.S. Department of Energy, Pittsburgh, PA); Myshakin, Eugene M. (URS Corporation, Pittsburgh, PA); Hur, Tae Bong (University of Pittsburgh, Pittsburgh, PA); Warzinski, Robert P. (U.S. Department of Energy, Pittsburgh, PA); Lynn, Ronald J. (URS Corporation, Pittsburgh, PA); Howard, Bret H. (U.S. Department of Energy, Pittsburgh, PA); Cygan, Randall Timothy

    2010-09-01T23:59:59.000Z

    This work compares the sorption and swelling processes associated with CO2-coal and CO2-clay interactions. We investigated the mechanisms of interaction related to CO2 adsortion in micropores, intercalation into sub-micropores, dissolution in solid matrix, the role of water, and the associated changes in reservoir permeability, for applications in CO2 sequestration and enhanced coal bed methane recovery. The structural changes caused by CO2 have been investigated. A high-pressure micro-dilatometer was equipped to investigate the effect of CO2 pressure on the thermoplastic properties of coal. Using an identical dilatometer, Rashid Khan (1985) performed experiments with CO2 that revealed a dramatic reduction in the softening temperature of coal when exposed to high-pressure CO2. A set of experiments was designed for -20+45-mesh samples of Argonne Premium Pocahontas No.3 coal, which is similar in proximate and ultimate analysis to the Lower Kittanning seam coal that Khan used in his experiments. No dramatic decrease in coal softening temperature has been observed in high-pressure CO2 that would corroborate the prior work of Khan. Thus, conventional polymer (or 'geopolymer') theories may not be directly applicable to CO2 interaction with coals. Clays are similar to coals in that they represent abundant geomaterials with well-developed microporous structure. We evaluated the CO2 sequestration potential of clays relative to coals and investigated the factors that affect the sorption capacity, rates, and permanence of CO2 trapping. For the geomaterials comparison studies, we used source clay samples from The Clay Minerals Society. Preliminary results showed that expandable clays have CO2 sorption capacities comparable to those of coal. We analyzed sorption isotherms, XRD, DRIFTS (infrared reflectance spectra at non-ambient conditions), and TGA-MS (thermal gravimetric analysis) data to compare the effects of various factors on CO2 trapping. In montmorillonite, CO2 molecules may remain trapped for several months following several hours of exposure to high pressure (supercritical conditions), high temperature (above boiling point of water) or both. Such trapping is well preserved in either inert gas or the ambient environment and appears to eventually result in carbonate formation. We performed computer simulations of CO2 interaction with free cations (normal modes of CO2 and Na+CO2 were calculated using B3LYP / aug-cc-pVDZ and MP2 / aug-cc-pVDZ methods) and with clay structures containing interlayer cations (MD simulations with Clayff potentials for clay and a modified CO2 potential). Additionally, interaction of CO2 with hydrated Na-montmorillonite was studied using density functional theory with dispersion corrections. The sorption energies and the swelling behavior were investigated. Preliminary modeling results and experimental observations indicate that the presence of water molecules in the interlayer region is necessary for intercalation of CO2. Our preliminary conclusion is that CO2 molecules may intercalate into interlayer region of swelling clay and stay there via coordination to the interlayer cations.

  8. Geologic controls influencing CO2 loss from a leaking well.

    SciTech Connect (OSTI)

    Hopkins, Polly L.; Martinez, Mario J.; McKenna, Sean Andrew; Klise, Katherine A.

    2010-12-01T23:59:59.000Z

    Injection of CO2 into formations containing brine is proposed as a long-term sequestration solution. A significant obstacle to sequestration performance is the presence of existing wells providing a transport pathway out of the sequestration formation. To understand how heterogeneity impacts the leakage rate, we employ two dimensional models of the CO2 injection process into a sandstone aquifer with shale inclusions to examine the parameters controlling release through an existing well. This scenario is modeled as a constant-rate injection of super-critical CO2 into the existing formation where buoyancy effects, relative permeabilities, and capillary pressures are employed. Three geologic controls are considered: stratigraphic dip angle, shale inclusion size and shale fraction. In this study, we examine the impact of heterogeneity on the amount and timing of CO2 released through a leaky well. Sensitivity analysis is performed to classify how various geologic controls influence CO2 loss. A 'Design of Experiments' approach is used to identify the most important parameters and combinations of parameters to control CO2 migration while making efficient use of a limited number of computations. Results are used to construct a low-dimensional description of the transport scenario. The goal of this exploration is to develop a small set of parametric descriptors that can be generalized to similar scenarios. Results of this work will allow for estimation of the amount of CO2 that will be lost for a given scenario prior to commencing injection. Additionally, two-dimensional and three-dimensional simulations are compared to quantify the influence that surrounding geologic media has on the CO2 leakage rate.

  9. CO2 Sequestration short course

    SciTech Connect (OSTI)

    DePaolo, Donald J. [Lawrence Berkeley National Laboratory; Cole, David R [The Ohio State University; Navrotsky, Alexandra [University of California-Davis; Bourg, Ian C [Lawrence Berkeley National Laboratory

    2014-12-08T23:59:59.000Z

    Given the public’s interest and concern over the impact of atmospheric greenhouse gases (GHGs) on global warming and related climate change patterns, the course is a timely discussion of the underlying geochemical and mineralogical processes associated with gas-water-mineral-interactions encountered during geological sequestration of CO2. The geochemical and mineralogical processes encountered in the subsurface during storage of CO2 will play an important role in facilitating the isolation of anthropogenic CO2 in the subsurface for thousands of years, thus moderating rapid increases in concentrations of atmospheric CO2 and mitigating global warming. Successful implementation of a variety of geological sequestration scenarios will be dependent on our ability to accurately predict, monitor and verify the behavior of CO2 in the subsurface. The course was proposed to and accepted by the Mineralogical Society of America (MSA) and The Geochemical Society (GS).

  10. Continuous CO2 extractor and methods

    SciTech Connect (OSTI)

    None listed

    2010-06-15T23:59:59.000Z

    The purpose of this CRADA was to assist in technology transfer from Russia to the US and assist in development of the technology improvements and applications for use in the U.S. and worldwide. Over the period of this work, ORNL has facilitated design, development and demonstration of a low-pressure liquid extractor and development of initial design for high-pressure supercritical CO2 fluid extractor.

  11. An Investigation of CO2 Sequestration

    E-Print Network [OSTI]

    Saldin, Dilano

    An Investigation of CO2 Sequestration through Mineralization Conference on Sustainable Construction area and increased availability of CO2 for rapid carbonation. The hardened and carbonated materials Slag #12;Carbonation Chemistry Dissolution of CO2 in water. CO2(g) CO2(aq) Formation of carbonic acid

  12. Dewetting of silica surfaces upon reactions with supercritical CO2 and brine: Pore-scale studies in micromodels

    E-Print Network [OSTI]

    Kim, Y.

    2013-01-01T23:59:59.000Z

    CO 2 injected into depleted oil reservoirs may have faster2 sequestration in depleted oil and gas reservoirs - caprocksaline aquifers, depleted oil and gas reservoirs, unmineable

  13. Adsorption and Strain: The CO2-Induced Swelling of Coal

    E-Print Network [OSTI]

    Paris-Sud XI, Université de

    Adsorption and Strain: The CO2-Induced Swelling of Coal M. Vandamme1 , L. Brochard2 , B. Lecampion3.07.014 #12;Abstract Enhanced coal bed methane recovery (ECBM) consists in injecting carbon dioxide in coal gets adsorbed at the surface of the coal pores, which causes the coal to swell. This swelling

  14. Surface CO2 leakage during the first shallow subsurface CO2 release experiment

    E-Print Network [OSTI]

    Lewicki, J.L.; Oldenburg, C.; Dobeck, L.; Spangler, L.

    2008-01-01T23:59:59.000Z

    numbered 0-6. Plots of F CO2 measured along the surface wellin Figure 2. Figure 2. Log F CO2 maps for measurements madeof soil CO 2 flux (F CO2 ). The surface leakage onset,

  15. Initial Results in Power System Identification from Injected Probing Signals Using a Subspace Method

    SciTech Connect (OSTI)

    Zhou, Ning; Pierre, John W.; Hauer, John F.

    2006-08-01T23:59:59.000Z

    In this paper, the authors use the Numerical algorithm for Subspace State Space System IDentification (N4SID) to extract dynamic parameters from phasor measurements collected on the western North American Power Grid. The data were obtained during tests on June 7, 2000, and they represent wide area response to several kinds of probing signals including Low-Level Pseudo-Random Noise (LLPRN) and Single-Mode Square Wave (SMSW) injected at the Celilo terminal of the Pacific HVDC In-tertie (PDCI). An identified model is validated using a cross vali-dation method. Also, the obtained electromechanical modes are compared with the results from Prony analysis of a ringdown and with signal analysis of ambient data measured under similar op-erating conditions. The consistent results show that methods in this class can be highly effective even when the probing signal is small.

  16. Predicting CO2-water interfacial tension under pressure and temperature conditions of geologic CO2 storage

    E-Print Network [OSTI]

    Nielsen, L.C.

    2013-01-01T23:59:59.000Z

    E EPM2- TIP4P2005 PPL- TIP4P2005 Predicted (f) a P ? CO2 2SE? CO2 2SE? CO2 2SE ? CO2 2SE ? CO2 2SE ? CO2 2SE a Surface excess CO

  17. MODELING OF CO2 LEAKAGE UP THROUGH AN ABANDONED WELL FROM DEEP SALINE AQUIFER TO SHALLOW FRESH

    E-Print Network [OSTI]

    Paris-Sud XI, Université de

    1 MODELING OF CO2 LEAKAGE UP THROUGH AN ABANDONED WELL FROM DEEP SALINE AQUIFER TO SHALLOW FRESH restricted to: (i) supercritical CO2 injection and storage within the Dogger reservoir aquifer, (ii) CO2 the cement-rock formation interface in the abandoned well (iii) impacts on the Albian aquifer water quality

  18. Weeks Island gravity stable CO2 pilot: Final report

    SciTech Connect (OSTI)

    Johnston, J.R.; Perry, G.E.

    1989-01-01T23:59:59.000Z

    The Weeks Island ''S'' sand Reservoir B (''S'' RB) gravity-stable CO2 field test was completed during February 1988. Injection started in October 1978 and production began in January 1981 in this high-permeability, steeply-dipping sandstone reservoir. About 264,000 barrels of oil or 65 percent of the starting volume has been recovered. A 24-percent pore-volume slug of CO2 mixed with about six mole percent of natural gas (mostly methane) was injected at the start of the pilot. Since 1983, produced CO2 plus hydrocarbon gases have been recycled. CO2 usage statistics are 9.34 MCF/BO with recycle and 3.24 MCF/BO based on purchased CO2. Previous annual reports document the pilot design, implementation, and early results for the 1977 to June 1981 time period. This report is a review of early pilot history and a more detailed account of the post June 1981 results and overall interpretation. A reservoir-simulation history match of pilot performance plus core and log data from a 1983 swept-zone evaluation well are described in this report. A brief description of the production facility and an account of the corrosion control program are also included. 11 refs., 34 figs.

  19. Potential for CO2 Sequestration and Enhanced Coalbed Methane Production, Blue Creek Field, NW Black Warrior Basin, Alabama

    E-Print Network [OSTI]

    He, Ting

    2011-02-22T23:59:59.000Z

    basin, Alabama. It considered the injection and production rate, the components of injected gas, coal dewatering, permeability anisotropy, various CO2 soak times, completion of multiple reservoir layers and pressure constraints at the injector...

  20. Modeling long-term CO2 storage, sequestration and cycling

    SciTech Connect (OSTI)

    Bacon, Diana H.

    2013-11-11T23:59:59.000Z

    The application of numerical and analytical models to the problem of storage, sequestration and migration of carbon dioxide in geologic formations is discussed. A review of numerical and analytical models that have been applied to CO2 sequestration are presented, as well as a description of frameworks for risk analysis. Application of models to various issues related to carbon sequestration are discussed, including trapping mechanisms, density convection mixing, impurities in the CO2 stream, changes in formation porosity and permeability, the risk of vertical leakage, and the impacts on groundwater resources if leakage does occur. A discussion of the development and application of site-specific models first addresses the estimation of model parameters and the use of natural analogues to inform the development of CO2 sequestration models, and then surveys modeling that has been done at two commercial-scale CO2 sequestration sites, Sleipner and In Salah, along with a pilot-scale injection sites used to study CO2 sequestration in saline aquifers (Frio) and an experimental site designed to test monitoring of CO2 leakage in the vadose zone (ZERT Release Facility).

  1. 8, 73737389, 2008 Scientists' CO2

    E-Print Network [OSTI]

    Paris-Sud XI, Université de

    ACPD 8, 7373­7389, 2008 Scientists' CO2 emissions A. Stohl Title Page Abstract Introduction Publications on behalf of the European Geosciences Union. 7373 #12;ACPD 8, 7373­7389, 2008 Scientists' CO2 substantial emissions of carbon dioxide (CO2). In this pa- per, the CO2 emissions of the employees working

  2. 6, 1092910958, 2006 Regional scale CO2

    E-Print Network [OSTI]

    Paris-Sud XI, Université de

    ACPD 6, 10929­10958, 2006 Regional scale CO2 flux estimation using radon A. I. Hirsch Title Page Chemistry and Physics Discussions On using radon-222 and CO2 to calculate regional-scale CO2 fluxes A. I (Adam.Hirsch@noaa.gov) 10929 #12;ACPD 6, 10929­10958, 2006 Regional scale CO2 flux estimation using

  3. Potential method for measurement of CO2 leakage from underground sequestration fields using radioactive tracers

    SciTech Connect (OSTI)

    Bachelor, Paula P.; McIntyre, Justin I.; Amonette, James E.; Hayes, James C.; Milbrath, Brian D.; Saripalli, Prasad

    2008-07-01T23:59:59.000Z

    Reduction of anthropogenic carbon dioxide (CO2) release to the environment is a pressing challenge that should be addressed to avert the potential devastating effects of global warming. Within the United States, the most abundant sources of CO2 emissions are those generate from coal- or gas-fired power plants; one method to control CO2 emissions is to sequester it in deep underground geological formations. From integrated assessment models the overall leakage rates from these storage locations must be less than 0.1% of stored volume per year for long-term control. The ability to detect and characterize nascent leaks, in conjunction with subsequent remediation efforts, will significantly decrease the amount of CO2 released back into the environment. Because potential leakage pathways are not necessarily known a priori, onsite monitoring must be performed; the monitoring region in the vicinity of a CO2 injection well may be as large as 100 km2, which represents the estimated size of a supercritical CO2 bubble that would form under typical injection scenarios. By spiking the injected CO2 with a radiological or stable isotope tracer, it will be possible to detect ground leaks from the sequestered CO2 using fewer sampling stations, with greater accuracy than would be possible using simple CO2 sensors. The relative merits of various sorbent materials, radiological and stable isotope tracers, detection methods and potential interferences will be discussed.

  4. EFFECTS OF CO2 LEAKAGES FROM STORAGE SITES ON THE QUALITY OF POTABLE GROUNDWATER

    E-Print Network [OSTI]

    was packed into two fixed-bed PVC columns. In the one column, gas CO2 and water were co-injected while only gas effect due mainly to the combustion of fossil fuels and CO2 emissions in the atmosphere

  5. Regulation for Underground Storage of CO2 Passed by U.S. States

    E-Print Network [OSTI]

    Regulation for Underground Storage of CO2 Passed by U.S. States Holly Javedan Massachusetts Institute of Technology 77 Massachusetts Avenue, Cambridge, MA 02139 #12;p. 2 TABLE OF CONTENTS ABSTRACT capture, transportation, injection and storage of CO2. To date nine states have passed regulation

  6. Using Big Data and Smart Field Technology for Detecting Leakage in a CO2 Storage Projects

    E-Print Network [OSTI]

    Mohaghegh, Shahab

    sequestration of carbon dioxide is one of the most fascinating developing technologies in order to reduce Leakage Detection System (ILDS). The main concern for geologic CO2 sequestration is the capability of the underground carbon dioxide storage to confine and sustain the injected CO2 for very long time. If a leakage

  7. Short communication Satellite-derived surface water pCO2 and airsea CO2 fluxes

    E-Print Network [OSTI]

    Short communication Satellite-derived surface water pCO2 and air­sea CO2 fluxes in the northern for the estimation of the partial pressure of carbon dioxide (pCO2) and air­sea CO2 fluxes in the northern South), respectively, the monthly pCO2 fields were computed. The derived pCO2 was compared with the shipboard pCO2

  8. Simulation assessment of CO2 sequestration potential and enhanced methane recovery in low-rank coalbeds of the Wilcox Group, east-central Texas 

    E-Print Network [OSTI]

    Hernandez Arciniegas, Gonzalo

    2006-10-30T23:59:59.000Z

    Carbon dioxide (CO2) from energy consumption is a primary source of greenhouse gases. Injection of CO2 from power plants in coalbed reservoirs is a plausible method for reducing atmospheric emissions, and it can have the ...

  9. MODELING AND CONTROL OF A O2/CO2 GAS TURBINE CYCLE FOR CO2 CAPTURE

    E-Print Network [OSTI]

    Foss, Bjarne A.

    MODELING AND CONTROL OF A O2/CO2 GAS TURBINE CYCLE FOR CO2 CAPTURE Lars Imsland Dagfinn Snarheim and control of a semi-closed O2/CO2 gas turbine cycle for CO2 capture. In the first part the process predictive control, Gas turbines, CO2 capture 1. INTRODUCTION Gas turbines are widely used for power

  10. Research project on CO2 geological storage and groundwaterresources: Large-scale hydrological evaluation and modeling of impact ongroundwater systems

    SciTech Connect (OSTI)

    Birkholzer, Jens; Zhou, Quanlin; Rutqvist, Jonny; Jordan,Preston; Zhang,K.; Tsang, Chin-Fu

    2007-10-24T23:59:59.000Z

    If carbon dioxide capture and storage (CCS) technologies areimplemented on a large scale, the amounts of CO2 injected and sequesteredunderground could be extremely large. The stored CO2 then replaces largevolumes of native brine, which can cause considerable pressureperturbation and brine migration in the deep saline formations. Ifhydraulically communicating, either directly via updipping formations orthrough interlayer pathways such as faults or imperfect seals, theseperturbations may impact shallow groundwater or even surface waterresources used for domestic or commercial water supply. Possibleenvironmental concerns include changes in pressure and water table,changes in discharge and recharge zones, as well as changes in waterquality. In compartmentalized formations, issues related to large-scalepressure buildup and brine displacement may also cause storage capacityproblems, because significant pressure buildup can be produced. Toaddress these issues, a three-year research project was initiated inOctober 2006, the first part of which is summarized in this annualreport.

  11. ATMOSPHERIC CO2 A GLOBAL LIMITING RESOURCE

    E-Print Network [OSTI]

    Schwartz, Stephen E.

    Carbondioxideatmosphericburden,PgC Land use Fossil CO2 from land use emissions ­ not fossil fuel combustion ­ was the dominant CO2 Comparison of CO2 mixing ratio from fossil fuel combustion and land use changes 400 380 360 340 cores 0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 Forcing,Wm -2 #12;ATMOSPHERIC CO2 EMISSIONS Time series 1700

  12. 5, 33133340, 2005 SCIAMACHY CO2 and

    E-Print Network [OSTI]

    Paris-Sud XI, Université de

    ACPD 5, 3313­3340, 2005 SCIAMACHY CO2 and aerosols S. Houweling et al. Title Page Abstract Evidence of systematic errors in SCIAMACHY-observed CO2 due to aerosols S. Houweling 1,2 , W. Hartmann 1 Commons License. 3313 #12;ACPD 5, 3313­3340, 2005 SCIAMACHY CO2 and aerosols S. Houweling et al. Title

  13. Flow Instabilities During Injection of CO2 into Saline Aquifers

    E-Print Network [OSTI]

    Garcia, Julio E.; Pruess, Karsten

    2008-01-01T23:59:59.000Z

    processes in oil reservoirs. Petrol. Trans. AIME, Vargaftik,by gas or water drive. Petrol. Trans. AIME, 195:91–98.uid displacement in sands. Petrol. Trans. AIME, x 10 T (s) (

  14. CO2 Injection Begins in Illinois | Department of Energy

    Energy Savers [EERE]

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Home Page onYou are now leaving Energy.gov You are now leaving Energy.gov You are being directed off Energy.gov. Are you0 ARRAM-04-07 AuditOptimizingEnergyDepartmentREALTY CHPDecatur,

  15. Physical Constraints on Geologic CO2 Sequestration in Low-Volume Basalt Formations

    SciTech Connect (OSTI)

    Ryan M. Pollyea; Jerry P. Fairley; Robert K. Podgorney; Travis L. McLing

    2014-03-01T23:59:59.000Z

    Deep basalt formations within large igneous provinces have been proposed as target reservoirs for carbon capture and sequestration on the basis of favorable CO2-water-rock reaction kinetics that suggest carbonate mineralization rates on the order of 102–103 d. Although these results are encouraging, there exists much uncertainty surrounding the influence of fracture-controlled reservoir heterogeneity on commercial-scale CO2 injections in basalt formations. This work investigates the physical response of a low-volume basalt reservoir to commercial-scale CO2 injections using a Monte Carlo numerical modeling experiment such that model variability is solely a function of spatially distributed reservoir heterogeneity. Fifty equally probable reservoirs are simulated using properties inferred from the deep eastern Snake River Plain aquifer in southeast Idaho, and CO2 injections are modeled within each reservoir for 20 yr at a constant mass rate of 21.6 kg s–1. Results from this work suggest that (1) formation injectivity is generally favorable, although injection pressures in excess of the fracture gradient were observed in 4% of the simulations; (2) for an extensional stress regime (as exists within the eastern Snake River Plain), shear failure is theoretically possible for optimally oriented fractures if Sh is less than or equal to 0.70SV; and (3) low-volume basalt reservoirs exhibit sufficient CO2 confinement potential over a 20 yr injection program to accommodate mineral trapping rates suggested in the literature.

  16. Samenvatting CO2 is het meest belangrijke broeikasgas. The concentratie van CO2 in de atmosfeer

    E-Print Network [OSTI]

    van den Brink, Jeroen

    Samenvatting CO2 is het meest belangrijke broeikasgas. The concentratie van CO2 in de atmosfeer brandstoffen en veranderingen in landgebruik. Toenemende concentraties van CO2 in de atmosfeer zullen naar toename van CO2 in de atmosfeer op de dynamiek van de microbiële gemeenschap in de directe omgeving van de

  17. MAC-Kaust Project P1 CO2 Sequestration Modeling of CO2 sequestration including parameter

    E-Print Network [OSTI]

    Turova, Varvara

    MAC-Kaust Project P1 ­ CO2 Sequestration Modeling of CO2 sequestration including parameter identification and numerical simulation M. Brokate, O. A. PykhteevHysteresis aspects of CO2 sequestration modeling K-H. Hoffmann, N. D. Botkin Objectives and methods of CO2 sequestration There is a popular belief

  18. How secure is CO2 storage? Leakage mechanisms of natural CO2 reservoirs

    E-Print Network [OSTI]

    How secure is CO2 storage? Leakage mechanisms of natural CO2 reservoirs Johannes Miocic, Stuart. The goal of CCS is to store carbon dioxide (CO2) in the subsurface for a long period of time (>10,000 yr).1 It is important that the stored CO2 does not leak from the reservoir to the surface . 3. Faults as leakage

  19. Surface controls on the characteristics of natural CO2 seeps: implications for engineered CO2 stores

    E-Print Network [OSTI]

    Haszeldine, Stuart

    of the CO2 seeps is most strongly governed by the flow properties of the outcropping rocks, and local emerge where valleys erode into CO2 aquifers, and these are typically high flux seeps. Seep type is knownSurface controls on the characteristics of natural CO2 seeps: implications for engineered CO2

  20. Surface Ocean CO2 Atlas (SOCAT) gridded data products

    SciTech Connect (OSTI)

    Sabine, Christopher [NOAA Pacific Marine Environmental Laboratory; Hankin, S. [Pacific Northwest National Laboratory (PNNL); Koyuk, H [Joint Institute for the Study of the Atmosphere and Ocean, University of Washington; Bakker, D C E [School of Environmental Sciences, University of East Anglia, Norwich, UK; Pfeil, B [Geophysical Institute, University of Bergen; Uni Research AS, Bergen, Norway; Olsen, A [Bjerknes Centre for Climate Research, UNIFOB AS, Bergen, Norway; Metzl, N [Universite Pierre et Marie Curie, LOCEAN/IPSL, Paris, France; Kozyr, Alexander [ORNL; Fassbender, A [School of Oceanography, University of Washington, Seattle, WA; Manke, A [Pacific Marine Environmental Laboratory, National Oceanic and Atmospheric Administration; Malczyk, J [Jetz Laboratory, Department of Ecology and Evolutionary Biology, Yale University; Akl, J [CSIRO Wealth from Oceans Flagship, Hobart, Tasmania, Australia; Alin, S R [Pacific Marine Environmental Laboratory, National Oceanic and Atmospheric Administration; Bellerby, R G J [Geophysical Institute, University of Bergen, Bergen, Norway; Borges, A [University of Liege, Chemical Oceanography Unit, Institut de Physique, Liege, Belgium; Boutin, J [Universite Pierre et Marie Curie, LOCEAN/IPSL, Paris, France; Brown, P J [School of Environmental Sciences, University of East Anglia, Norwich, UK; Cai, W-J [Department of Marine Sciences, University of Georgia; Chavez, F P [Monterey Bay Aquarium Research Institute, Moss Landing, CA; Chen, A [Institute of Marine Geology and Chemistry, National Sun Yat-sen University, Kaohsiung, Taiwan; Cosa, C [Pacific Marine Environmental Laboratory, National Oceanic and Atmospheric Administration; Feely, R A [Pacific Marine Environmental Laboratory, National Oceanic and Atmospheric Administration; Gonzalez-Davila, M [Universidad de Las Palmas de Gran Canaria, Facultad de Ciencias del Mar, Las Palmas de Gran Canaria,; Goyet, C [Institut de Modélisation et d'Analyse en Géo-Environnement et Santé, Université de Perpignan; Hardman-Mountford, N [CSIRO, Marine and Atmospheric Research, Wembley, Western Australia, Australia; Heinze, C [Geophysical Institute, University of Bergen, Bergen, Norway; Hoppema, M [Alfred Wegener Institute for Polar and Marine Research, Bremerhaven, Germany; Hunt, C W [Ocean Process Analysis Lab, University of New Hampshire, Durham, New Hampshire; Hydes, D [National Oceanography Centre, Southampton, UK; Ishii, M [Japan Meteorological Agency, Meteorological Research Institute, Tsukuba, Japan; Johannessen, T [Geophysical Institute, University of Bergen, Bergen, Norway; Key, R M [Atmospheric and Oceanic Sciences, Princeton University, Princeton, New Jersey; Kortzinger, A [GEOMAR, Helmholtz Centre for Ocean Research, Kiel, Germany; Landschutzer, P [School of Environmental Sciences, University of East Anglia, Norwich, UK; Lauvset, S K [Geophysical Institute, University of Bergen, Bergen, Norway; Lefevre, N [Université Pierre et Marie Curie, LOCEAN/IPSL, Paris, France; Lenton, A [Centre for Australian Weather and Climate Research, Hobart, Tasmania, Australia; Lourantou, A [Université Pierre et Marie Curie, LOCEAN/IPSL, Paris, France; Merlivat, L [Université Pierre et Marie Curie, LOCEAN/IPSL, Paris, France; Midorikawa, T [Nagasaki Marine Observatory, Nagasaki, Japan; Mintrop, L [MARIANDA, Kiel, Germany; Miyazaki, C [Faculty of Environmental Earth Science, Hokkaido University, Hokkaido, Japan; Murata, A [Japan Agency for Marine-Earth Science and Technology, Yokosuka, Japan; Nakadate, A [Marine Division, Global Environment and Marine Department, Japan Meteorological Agency, Tokyo, Japan; Nakano, Y [Japan Agency for Marine-Earth Science and Technology, Yokosuka, Japan; Nakaoka, S [National Institute for Environmental Studies (NIES), Tsukuba, Japan; Nojiri, Y [National Institute for Environmental Studies, Tsukuba, Japan; et al.

    2013-01-01T23:59:59.000Z

    A well documented, publicly available, global data set for surface ocean carbon dioxide (CO2) parameters has been called for by international groups for nearly two decades. The Surface Ocean CO2 Atlas (SOCAT) project was initiated by the international marine carbon science community in 2007 with the aim of providing a comprehensive, publicly available, regularly updated, global data set of marine surface CO2, which had been subject to quality control (QC). SOCAT version 1.5 was made public in September 2011 and holds 6.3 million quality controlled surface CO2 data from the global oceans and coastal seas, spanning four decades (1968 2007). The SOCAT gridded data is the second data product to come from the SOCAT project. Recognizing that some groups may have trouble working with millions of measurements, the SOCAT gridded product was generated to provide a robust regularly spaced fCO2 product with minimal spatial and temporal interpolation which should be easier to work with for many applications. Gridded SOCAT is rich with information that has not been fully explored yet, but also contains biases and limitations that the user needs to recognize and address.

  1. Molecular Dynamics Simulations of CO2 Formation in Interstellar Ices

    E-Print Network [OSTI]

    Arasa, Carina; van Dishoeck, Ewine F; Kroes, Geert-Jan

    2013-01-01T23:59:59.000Z

    CO2 ice is one of the most abundant components in ice-coated interstellar ices besides H2O and CO, but the most favorable path to CO2 ice is still unclear. Molecular dynamics calculations on the ultraviolet photodissociation of different kinds of CO-H2O ice systems have been performed at 10 K in order to demonstrate that the reaction between CO and an OH molecule resulting from H2O photodissociation through the first excited state is a possible route to form CO2 ice. However, our calculations, which take into account different ice surface models, suggest that there is another product with a higher formation probability ((3.00+-0.07)x10-2), which is the HOCO complex, whereas the formation of CO2 has a probability of only (3.6+-0.7)x10-4. The initial location of the CO is key to obtain reaction and form CO2: the CO needs to be located deep into the ice. The HOCO complex becomes trapped in the cold ice surface in the trans-HOCO minimum because it quickly loses its internal energy to the surrounding ice, preventi...

  2. Modeling of CO2 storage in aquifers

    E-Print Network [OSTI]

    santos,,,

    Feb 6, 2011 ... atmosphere, increasing its temperature (greenhouse effect). To minimize climate change impacts, geological sequestration of CO2 is an ...

  3. QGESS: CO2 Impurity Design Parameters

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    limits Component Unit (Max unless Otherwise noted) Carbon Steel Pipeline Enhanced Oil Recovery Saline Reservoir Sequestration Saline Reservoir CO 2 & H 2 S Co- sequestration...

  4. The supply chain of CO2 emissions

    E-Print Network [OSTI]

    Davis, S. J; Peters, G. P; Caldeira, K.

    2011-01-01T23:59:59.000Z

    emissions from traded fossil fuels; Top), production (F Pr )Regional, and National Fossil-Fuel CO 2 Emissions (Carbonfrom the burning of fossil fuels are conventionally

  5. New Strategies for Finding Abandoned Wells at Proposed Geologic Storage Sites for CO2

    SciTech Connect (OSTI)

    Hammack, R.W.; Veloski, G.A.

    2007-09-01T23:59:59.000Z

    Prior to the injection of CO2 into geological formations, either for enhanced oil recovery or for CO2 sequestration, it is necessary to locate wells that perforate the target formation and are within the radius of influence for planned injection wells. Locating and plugging wells is necessary because improperly plugged well bores provide the most rapid route for CO2 escape to the surface. This paper describes the implementation and evaluation of helicopter and ground-based well detection strategies at a 100+ year old oilfield in Wyoming where a CO2 flood is planned. This project was jointly funded by the U.S. Department of Energy’s National Energy Technology Laboratory and Fugro Airborne Surveys.

  6. Original article The effects of elevated CO2 and water stress

    E-Print Network [OSTI]

    Paris-Sud XI, Université de

    dépit d'une première phase de stimulation de la production de biomasse (+44 %, 30 juillet 1993) par le 1993). Despite an initial stimulation of biomass growth (+44%) by elevated CO2 CO2 treatments, irrespective of water- ing regime. Under drought conditions, although

  7. Balancing the global energy demand with a decrease in an-thropogenic CO2 emissions to mitigate climate change has

    E-Print Network [OSTI]

    Entekhabi, Dara

    - and gas-burning power plants, compressed into a supercritical fluid and injected into 11 deep saline, they assumed that the rate of CO2 production from the power plants would increase linearly, reach a maxi- mum to evaluate the prospects of using CCS to store CO2 emissions that would be captured from the flue gas of coal

  8. A Computationally Efficient Approach to Applying the SAFT Equation for CO2 + H2O Phase Equilibrium

    E-Print Network [OSTI]

    Patzek, Tadeusz W.

    into depleted oil and/or natural gas reservoirs is already underway to reduce CO2 emission to the atmosphere [4 into oil (hydrocarbon) reservoirs is a recognized technology for enhancing oil production and CO2 injection]. Predicting the sequestration potential and long term behavior of man-made geologic reservoirs requires

  9. Reactivity of iron-bearing minerals and CO2 sequestration: A multi-disciplinary experimental approach

    SciTech Connect (OSTI)

    Schoonen, Martin A. [Stony Brook University] (ORCID:0000000271331160)

    2014-12-22T23:59:59.000Z

    The reactivity of sandstones was studied under conditions relevant to the injection of supercritical carbon dioxide in the context of carbon geosequestration. The emphasis of the study was on the reactivity of iron-bearing minerals when exposed to supercritical CO2 (scCO2) and scCO2 with commingled aqueous solutions containing H2S and/or SO2. Flow through and batch experiments were conducted. Results indicate that sandstones, irrespective of their mineralogy, are not reactive when exposed to pure scCO2 or scCO2 with commingled aqueous solutions containing H2S and/or SO2 under conditions simulating the environment near the injection point (flow through experiments). However, sandstones are reactive under conditions simulating the edge of the injected CO2 plume or ahead of the plume (batch experiments). Sandstones containing hematite (red sandstone) are particularly reactive. The composition of the reaction products is strongly dependent on the composition of the aqueous phase. The presence of dissolved sulfide leads to the conversion of hematite into pyrite and siderite. The relative amount of the pyrite and siderite is influenced by the ionic strength of the solution. Little reactivity is observed when sulfite is present in the aqueous phase. Sandstones without hematite (grey sandstones) show little reactivity regardless of the solution composition.

  10. Semi-analytical Solution for Multiphase Fluid Flow Applied to CO2 Sequestration in Geologic Porous Media

    E-Print Network [OSTI]

    Mohamed, Ahmed Mohamed Anwar Sayed

    2013-08-01T23:59:59.000Z

    atmospheric emissions of CO_(2). Feasibility assessments of proposed sequestration sites require realistic and computationally efficient models to simulate the subsurface pressure response and monitor the injection process, and quantify the risks of leakage...

  11. Capturing CO2 from Air Anca Timofte

    E-Print Network [OSTI]

    Fischlin, Andreas

    emissions through renewable fuels · Storage of fluctuating renewable energies · Short-term: Substitute concentrated CO2 from atmospheric air Renewable energy source for Climeworks and subsequent fuel synthesis in Greenhouses Beverage Carbonation CO2 Supply for Renewable Fuel Synthesis #12;5 Climeworks plant delivers

  12. Legal Implications of CO2 Ocean Storage

    E-Print Network [OSTI]

    Legal Implications of CO2 Ocean Storage Jason Heinrich Working Paper Laboratory for Energy the deployment of CO2 storage technologies used in the marine environment. This paper will address some of the legal issues involved in ocean storage of carbon dioxide from a US perspective. The following paragraphs

  13. 2, 711743, 2006 Glacial CO2

    E-Print Network [OSTI]

    Paris-Sud XI, Université de

    CO2 change: a simple "hypsometric effect" on deep-ocean carbon sequestration? L. C. Skinner Godwin carbon sequestration, this mechanism may help to significantly reduce the "deficit" of explained glacialCPD 2, 711­743, 2006 Glacial CO2 sequestration L. C. Skinner Title Page Abstract Introduction

  14. Capturing CO2 via reactions in nanopores.

    SciTech Connect (OSTI)

    Leung, Kevin; Nenoff, Tina Maria; Criscenti, Louise Jacqueline; Tang, Z [University of Cincinnati; Dong, J. H. [University of Cincinnati

    2008-10-01T23:59:59.000Z

    This one-year exploratory LDRD aims to provide fundamental understanding of the mechanism of CO2 scrubbing platforms that will reduce green house gas emission and mitigate the effect of climate change. The project builds on the team member's expertise developed in previous LDRD projects to study the capture or preferential retention of CO2 in nanoporous membranes and on metal oxide surfaces. We apply Density Functional Theory and ab initio molecular dynamics techniques to model the binding of CO2 on MgO and CaO (100) surfaces and inside water-filled, amine group functionalized silica nanopores. The results elucidate the mechanisms of CO2 trapping and clarify some confusion in the literature. Our work identifies key future calculations that will have the greatest impact on CO2 capture technologies, and provides guidance to science-based design of platforms that can separate the green house gas CO2 from power plant exhaust or even from the atmosphere. Experimentally, we modify commercial MFI zeolite membranes and find that they preferentially transmit H2 over CO2 by a factor of 34. Since zeolite has potential catalytic capability to crack hydrocarbons into CO2 and H2, this finding paves the way for zeolite membranes that can convert biofuel into H2 and separate the products all in one step.

  15. 4, 23852405, 2007 CO2 and climate

    E-Print Network [OSTI]

    Paris-Sud XI, Université de

    BGD 4, 2385­2405, 2007 CO2 and climate affect European carbon ballance R. Harrison and C. Jones Competing roles of rising CO2 and climate change in the contemporary European carbon balance R. Harrison and C. Jones Met Office, Hadley Centre for Climate Change, Exeter, EX1 3PB, UK Received: 13 April 2007

  16. CO2 Capture with Enzyme Synthetic Analogue

    SciTech Connect (OSTI)

    Harry Cordatos

    2010-11-08T23:59:59.000Z

    Overview of an ongoing, 2 year research project partially funded by APRA-E to create a novel, synthetic analogue of carbonic anhydrase and incorporate it into a membrane for removal of CO2 from flue gas in coal power plants. Mechanism background, preliminary feasibility study results, molecular modeling of analogue-CO2 interaction, and program timeline are provided.

  17. Prospects for Subsurface CO2 Sequestration

    E-Print Network [OSTI]

    Firoozabadi, Abbas

    Prospects for Subsurface CO2 Sequestration Abbas Firoozabadi and Philip Cheng Dept. of Chemical in Wiley InterScience (www.interscience.wiley.com). Keywords: CO2 sequestration, mixing, diffusion coal in the future. Coal has a high carbon to hydrogen ratio while natural gas, the premium fuel

  18. Sustainable Carbon Sequestration: Increasing CO2-Storage Efficiency through a CO2-Brine Displacement Approach

    E-Print Network [OSTI]

    Akinnikawe, Oyewande

    2012-10-19T23:59:59.000Z

    CO2 sequestration is one of the proposed methods for reducing anthropogenic CO2 emissions to the atmosphere and therefore mitigating global climate change. Few studies on storing CO2 in an aquifer have been conducted on a regional scale. This study...

  19. Sustainable Carbon Sequestration: Increasing CO2-Storage Efficiency through a CO2-Brine Displacement Approach 

    E-Print Network [OSTI]

    Akinnikawe, Oyewande

    2012-10-19T23:59:59.000Z

    CO2 sequestration is one of the proposed methods for reducing anthropogenic CO2 emissions to the atmosphere and therefore mitigating global climate change. Few studies on storing CO2 in an aquifer have been conducted on a regional scale. This study...

  20. IMPLEMENTING A NOVEL CYCLIC CO2 FLOOD IN PALEOZOIC REEFS

    SciTech Connect (OSTI)

    James R. Wood; W. quinlan; A. Wylie

    2006-06-01T23:59:59.000Z

    Recycled CO2 is being used in this demonstration project to produce bypassed oil from the Silurian Dover 35 Niagaran pinnacle reef located in Otsego County, Michigan. CO2 injection in the Dover 35 field into the Salling-Hansen 4-35A well began on May 6, 2004. A second injection well, the Salling-Hansen 1-35, commenced injection in August 2004. Oil production in the Pomerzynski 5-35 producing well increased from 9 BOPD prior to operations to an average of 165 BOPD in December, 2004 and has produced at an average rate of 61 BOPD (Jan-Dec, 2005). The Salling-Hansen 4-35A also produced during this reporting period an average of 29 BOPD. These increases have occurred as a result of CO2 injection and the production rate appears to be stabilizing. CO2 injection volume has reached approximately 2.18 BCF. The CO2 injection phase of this project has been fully operational since December 2004 and most downhole mechanical issues have been solved and surface facility modifications have been completed. It is anticipated that filling operations will run for another 6-12 months from July 1, 2005. In most other aspects, the demonstration is going well and hydrocarbon production has been stabilized at an average rate of 57 BOPD (July-Dec, 2005). Our industry partners continue to experiment with injection rates and pressures, various downhole and surface facility mechanical configurations, and the huff-n-puff technique to develop best practices for these types of enhanced recovery projects. Subsurface characterization was completed using well log tomography and 3D visualizations to map facies distributions and reservoir properties in the Belle River Mills, Chester 18, Dover 35, and Dover 36 Fields. The Belle River Mills and Chester 18 fields are being used as type-fields because they have excellent log and/or core data coverage. Amplitude slicing of the log porosity, normalized gamma ray, core permeability, and core porosity curves are showing trends that indicate significant heterogeneity and compartmentalization in these reservoirs associated with the original depositional fabric and pore types of the carbonate reservoir rocks. Accumulated pressure data supports the hypothesis of extreme heterogeneity in the Dover 35. Some intervals now have pressure readings over 2345 psig (April 29, 2005) in the A-1 Carbonate while nearby Niagaran Brown intervals only show 1030 psig (March 7, 2005). This is a pressure differential over 1300 psig and suggests significant vertical barriers in the reef, consistent with the GR tomography modeling. Digital and hard copy data have been compiled for the Niagaran reefs in the Michigan Basin, including a detailed summary of 20 fields in the vicinity of the demonstration well. Technology transfer took place through technical presentations regarding visualization of the reservoir heterogeneity in these Niagaran reefs. Oral presentations were given at two Petroleum Technology Transfer Council workshops, a Michigan Oil and Gas Association Conference, a Michigan Basin Geological Society meeting, and the Eastern American Association of Petroleum Geologist's Annual meeting. In addition, we met with our industry partners several times during the first half of 2005 to communicate and discuss the reservoir characterization and field site aspects of the demonstration project. A technical paper was published in the April 2005 issue of the AAPG Bulletin on the characterization of the Belle River Mills Field.

  1. Uncertainty quantification for the impact of injection rate fluctuation on the geomechanical response of geological carbon sequestration

    SciTech Connect (OSTI)

    Bao, Jie; Chu, Yanjun; Xu, Zhijie; Tartakovsky, Alexandre M.; Fang, Yilin

    2014-02-02T23:59:59.000Z

    We present an analysis of the geomechanical effects of injection rate fluctuations for geological sequestration of carbon dioxide (CO2). Initially, we present analytical solutions for the effects of injection rate fluctuations on CO2 fluid pressure spatial distribution and temporal evolution for a typical injection scenario. Numerical calculations are performed using a finite element method to investigate the effects of injection rate fluctuations on geomechanical deformation, stresses, and potential failure of the aquifer and caprock layers. The numerical method was first validated by the fluid pressure distribution’s good agreement with the analytical solution. It was shown that for any Gaussian fluctuations of injection rate Q with given mean Q ? and variance ?_Q, the coefficients of variance for fluid pressure (?_p=?_p?p ? ), deformation (?_u=?_u?u ? ), and stresses (?_?=?_??? ? ) increase linearly with the coefficient of variance for injection rate (?_Q=?_Q?Q ? ). The proportional constants are identified, and the fluctuations have the most pronounced effect on the geomechanical stresses, and, therefore, on the potential failure of the aquifer and caprock layers. Instead of expensive computational simulation, this study provides an efficient tool to estimate the geomechanical response variance to injection rate fluctuation. A failure analysis was presented based on the numerical results, where probability of failure was estimated for fluctuating injection rates with different mean and variance during the entire injection period. It was found that with increasing injection rate fluctuation, the failure probability increases significantly. Therefore, the risk associated with injection rate fluctuations should be carefully evaluated.?

  2. Risk Assessment and Monitoring of Stored CO2 in Organic Rocks Under Non-Equilibrium Conditions

    SciTech Connect (OSTI)

    Malhotra, Vivak

    2014-06-30T23:59:59.000Z

    The USA is embarking upon tackling the serious environmental challenges posed to the world by greenhouse gases, especially carbon dioxide (CO2). The dimension of the problem is daunting. In fact, according to the Energy Information Agency, nearly 6 billion metric tons of CO2 were produced in the USA in 2007 with coal-burning power plants contributing about 2 billion metric tons. To mitigate the concerns associated with CO2 emission, geological sequestration holds promise. Among the potential geological storage sites, unmineable coal seams and shale formations in particular show promise because of the probability of methane recovery while sequestering the CO2. However. the success of large-scale sequestration of CO2 in coal and shale would hinge on a thorough understanding of CO2's interactions with host reservoirs. An important parameter for successful storage of CO2 reservoirs would be whether the pressurized CO2 would remain invariant in coal and shale formations under reasonable internal and/or external perturbations. Recent research has brought to the fore the potential of induced seismicity, which may result in caprock compromise. Therefore, to evaluate the potential risks involved in sequestering CO2 in Illinois bituminous coal seams and shale, we studied: (i) the mechanical behavior of Murphysboro (Illinois) and Houchin Creek (Illinois) coals, (ii) thermodynamic behavior of Illinois bituminous coal at - 100oC ? T ? 300oC, (iii) how high pressure CO2 (up to 20.7 MPa) modifies the viscosity of the host, (iv) the rate of emission of CO2 from Illinois bituminous coal and shale cores if the cores, which were pressurized with high pressure (? 20.7 MPa) CO2, were exposed to an atmospheric pressure, simulating the development of leakage pathways, (v) whether there are any fractions of CO2 stored in these hosts which are resistance to emission by simply exposing the cores to atmospheric pressure, and (vi) how compressive shockwaves applied to the coal and shale cores, which were pressurized with high pressure CO2, determine the fate of sequestered CO2 in these cores. Our results suggested that Illinois bituminous coal in its unperturbed state, i.e., when not pressurized with CO2, showed large variations in the mechanical properties. Modulus varied from 0.7 GPa to 3.4 GPa even though samples were extracted from a single large chunk of coal. We did not observe any glass transition for Illinois bituminous coal at - 100oC ? T ? 300oC, however, when the coal was pressurized with CO2 at ambient ? P ? 20.7 MPa, the viscosity of the coal decreased and inversely scaled with the CO2 pressure. The decrease in viscosity as a function of pressure could pose CO2 injection problems for coal as lower viscosity would allow the solid coal to flow to plug the fractures, fissures, and cleats. Our experiments also showed a very small fraction of CO2 was absorbed in coal; and when CO2 pressurized coals were exposed to atmospheric conditions, the loss of CO2 from coals was massive. Half of the sequestered gas from the coal cores was lost in less than 20 minutes. Our shockwave experiments on Illinois bituminous coal, New Albany shale (Illinois), Devonian shale (Ohio), and Utica shale (Ohio) presented clear evidence that the significant emission of the sequestered CO2 from these formations cannot be discounted during seismic activity, especially if caprock is compromised. It is argued that additional shockwave studies, both compressive and transverse, would be required for successfully mapping the risks associated with sequestering high pressure CO2 in coal and shale formations.

  3. Analysis of CO2 Separation from Flue Gas, Pipeline Transportation, and Sequestration in Coal

    SciTech Connect (OSTI)

    Eric P. Robertson

    2007-09-01T23:59:59.000Z

    This report was written to satisfy a milestone of the Enhanced Coal Bed Methane Recovery and CO2 Sequestration task of the Big Sky Carbon Sequestration project. The report begins to assess the costs associated with separating the CO2 from flue gas and then injecting it into an unminable coal seam. The technical challenges and costs associated with CO2 separation from flue gas and transportation of the separated CO2 from the point source to an appropriate sequestration target was analyzed. The report includes the selection of a specific coal-fired power plant for the application of CO2 separation technology. An appropriate CO2 separation technology was identified from existing commercial technologies. The report also includes a process design for the chosen technology tailored to the selected power plant that used to obtain accurate costs of separating the CO2 from the flue gas. In addition, an analysis of the costs for compression and transportation of the CO2 from the point-source to an appropriate coal bed sequestration site was included in the report.

  4. Enhanced Coal Bed Methane Recovery and CO2 Sequestration in the Powder River Basin

    SciTech Connect (OSTI)

    Eric P. Robertson

    2010-06-01T23:59:59.000Z

    Unminable coal beds are potentially large storage reservoirs for the sequestration of anthropogenic CO2 and offer the benefit of enhanced methane production, which can offset some of the costs associated with CO2 sequestration. The objective of this report is to provide a final topical report on enhanced coal bed methane recovery and CO2 sequestration to the U.S. Department of Energy in fulfillment of a Big Sky Carbon Sequestration Partnership milestone. This report summarizes work done at Idaho National Laboratory in support of Phase II of the Big Sky Carbon Sequestration Partnership. Research that elucidates the interaction of CO2 and coal is discussed with work centering on the Powder River Basin of Wyoming and Montana. Sorption-induced strain, also referred to as coal swelling/shrinkage, was investigated. A new method of obtaining sorption-induced strain was developed that greatly decreases the time necessary for data collection and increases the reliability of the strain data. As coal permeability is a strong function of sorption-induced strain, common permeability models were used to fit measured permeability data, but were found inadequate. A new permeability model was developed that can be directly applied to coal permeability data obtained under laboratory stress conditions, which are different than field stress conditions. The coal permeability model can be used to obtain critical coal parameters that can be applied in field models. An economic feasibility study of CO2 sequestration in unminable coal seams in the Powder River Basin of Wyoming was done. Economic analyses of CO2 injection options are compared. Results show that injecting flue gas to recover methane from CBM fields is marginally economical; however, this method will not significantly contribute to the need to sequester large quantities of CO2. Separating CO2 from flue gas and injecting it into the unminable coal zones of the Powder River Basin seam is currently uneconomical, but can effectively sequester over 86,000 tons (78,200 Mg) of CO2 per acre while recovering methane to offset costs. The cost to separate CO2 from flue gas was identified as the major cost driver associated with CO2 sequestration in unminable coal seams. Improvements in separations technology alone are unlikely to drive costs low enough for CO2 sequestration in unminable coal seams in the Powder River Basin to become economically viable. Breakthroughs in separations technology could aid the economics, but in the Powder River Basin, they cannot achieve the necessary cost reductions for breakeven economics without incentives.

  5. Thermodynamic Data for Geochemical Modeling of Carbonate Reactions Associated with CO2 Sequestration – Literature Review

    SciTech Connect (OSTI)

    Krupka, Kenneth M.; Cantrell, Kirk J.; McGrail, B. Peter

    2010-09-28T23:59:59.000Z

    Permanent storage of anthropogenic CO2 in deep geologic formations is being considered as a means to reduce the concentration of atmospheric CO2 and thus its contribution to global climate change. To ensure safe and effective geologic sequestration, numerous studies have been completed of the extent to which the CO2 migrates within geologic formations and what physical and geochemical changes occur in these formations when CO2 is injected. Sophisticated, computerized reservoir simulations are used as part of field site and laboratory CO2 sequestration studies. These simulations use coupled multiphase flow-reactive chemical transport models and/or standalone (i.e., no coupled fluid transport) geochemical models to calculate gas solubility, aqueous complexation, reduction/oxidation (redox), and/or mineral solubility reactions related to CO2 injection and sequestration. Thermodynamic data are critical inputs to modeling geochemical processes. The adequacy of thermodynamic data for carbonate compounds has been identified as an important data requirement for the successful application of these geochemical reaction models to CO2 sequestration. A review of thermodynamic data for CO2 gas and carbonate aqueous species and minerals present in published data compilations and databases used in geochemical reaction models was therefore completed. Published studies that describe mineralogical analyses from CO2 sequestration field and natural analogue sites and laboratory studies were also reviewed to identify specific carbonate minerals that are important to CO2 sequestration reactions and therefore require thermodynamic data. The results of the literature review indicated that an extensive thermodynamic database exists for CO2 and CH4 gases, carbonate aqueous species, and carbonate minerals. Values of ?fG298° and/or log Kr,298° are available for essentially all of these compounds. However, log Kr,T° or heat capacity values at temperatures above 298 K exist for less than approximately one-third of these compounds. Because the temperatures of host formations that will be used for CO2 injection and sequestration will be at tempera¬tures in the range of 50ºC to 100ºC or greater, the lack of high temperature thermodynamic values for key carbonate compounds especially minerals, will impact the accuracy of some modeling calculations.

  6. Data Assimilation Tools for CO2 Reservoir Model Development – A Review of Key Data Types, Analyses, and Selected Software

    SciTech Connect (OSTI)

    Rockhold, Mark L.; Sullivan, E. C.; Murray, Christopher J.; Last, George V.; Black, Gary D.

    2009-09-30T23:59:59.000Z

    Pacific Northwest National Laboratory (PNNL) has embarked on an initiative to develop world-class capabilities for performing experimental and computational analyses associated with geologic sequestration of carbon dioxide. The ultimate goal of this initiative is to provide science-based solutions for helping to mitigate the adverse effects of greenhouse gas emissions. This Laboratory-Directed Research and Development (LDRD) initiative currently has two primary focus areas—advanced experimental methods and computational analysis. The experimental methods focus area involves the development of new experimental capabilities, supported in part by the U.S. Department of Energy’s (DOE) Environmental Molecular Science Laboratory (EMSL) housed at PNNL, for quantifying mineral reaction kinetics with CO2 under high temperature and pressure (supercritical) conditions. The computational analysis focus area involves numerical simulation of coupled, multi-scale processes associated with CO2 sequestration in geologic media, and the development of software to facilitate building and parameterizing conceptual and numerical models of subsurface reservoirs that represent geologic repositories for injected CO2. This report describes work in support of the computational analysis focus area. The computational analysis focus area currently consists of several collaborative research projects. These are all geared towards the development and application of conceptual and numerical models for geologic sequestration of CO2. The software being developed for this focus area is referred to as the Geologic Sequestration Software Suite or GS3. A wiki-based software framework is being developed to support GS3. This report summarizes work performed in FY09 on one of the LDRD projects in the computational analysis focus area. The title of this project is Data Assimilation Tools for CO2 Reservoir Model Development. Some key objectives of this project in FY09 were to assess the current state-of-the-art in reservoir model development, the data types and analyses that need to be performed in order to develop and parameterize credible and robust reservoir simulation models, and to review existing software that is applicable to these analyses. This report describes this effort and highlights areas in which additional software development, wiki application extensions, or related GS3 infrastructure development may be warranted.

  7. IMPLEMENTING A NOVEL CYCLIC CO2 FLOOD IN PALEOZOIC REEFS

    SciTech Connect (OSTI)

    James R. Wood; W. Quinlan; A. Wylie

    2004-01-01T23:59:59.000Z

    Recycled CO2 will be used in this demonstration project to produce bypassed oil from the Silurian Dover 35 pinnacle reef (Otsego County) in the Michigan Basin. Contract negotiations by our industry partner to gain access to the CO2 supply have been completed and the State of Michigan has issued an order to allow operation of the project. Injection of CO2 is scheduled to begin in February, 2004. Subsurface characterization is being completed using well log tomography animations and 3D visualizations to map facies distributions and reservoir properties in two reefs, the Belle River Mills and Chester 18 Fields. The Belle River Mills and Chester18 fields are being used as type-fields because they have excellent log and/or core data coverage. Amplitude slicing of the normalized gamma ray and core permeability and core porosity curves is showing trends that indicate significant heterogeneity and compartmentalization in these reservoirs associated with the original depositional fabric of the rocks. Digital and hard copy data continues to be compiled for the Niagaran reefs in the Michigan Basin. Technology transfer took place through technical presentations regarding visualization of the heterogeneity of the Niagaran reefs. An oral presentation was given at the AAPG Eastern Section Meeting and a booth at the same meeting was used to meet one-on-one with operators.

  8. co2 capture | netl.doe.gov

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    CO2 Capture Technology Meeting Dates: June 23-26, 2015 Registration Fee: 360.00 Venue: 300 West Station Square Drive Pittsburgh, PA 15219-1122 Phone: (412)261-2000...

  9. CO2-Driven Enhanced Gas Recovery and Storage in Depleted Shale Reservoir-A Numerical Simulation Study

    E-Print Network [OSTI]

    Mohaghegh, Shahab

    are driving initiatives to develop carbon management technologies, including geologic sequestration of CO2 of carbon dioxide (CO2), especially from the combustion of fossil fuels, are being linked to global climate change and are of considerable concern. These concerns are driving initiatives to develop carbon

  10. Version 3.0 SOP 4 --p(CO2) October 12, 2007 (p(CO2))

    E-Print Network [OSTI]

    Version 3.0 SOP 4 -- p(CO2) October 12, 2007 91 SOP 4 (p(CO2)) - 1. . microatmospheres . (20°C 250-2000 µatm) (mole fraction) . 2. CO2 (mole fraction) . 2 2(CO ) (CO( ) . . Frit . #12;October 12, 2007 SOP 4 -- p(CO2) Version 3.0 92 CO2 CO2 2 . p(CO2) (1) . 4. 3

  11. International Collaboration on CO2 Sequestration

    SciTech Connect (OSTI)

    Peter H. Israelsson; E. Eric Adams

    2007-06-30T23:59:59.000Z

    On December 4, 1997, the US Department of Energy (USDOE), the New Energy and Industrial Technology Development Organization of Japan (NEDO), and the Norwegian Research Council (NRC) entered into a Project Agreement for International Collaboration on CO{sub 2} Ocean Sequestration. Government organizations from Japan, Canada, and Australia, and a Swiss/Swedish engineering firm later joined the agreement, which outlined a research strategy for ocean carbon sequestration via direct injection. The members agreed to an initial field experiment, with the hope that if the initial experiment was successful, there would be subsequent field evaluations of increasingly larger scale to evaluate environmental impacts of sequestration and the potential for commercialization. The evolution of the collaborative effort, the supporting research, and results for the International Collaboration on CO{sub 2} Ocean Sequestration were documented in almost 100 papers and reports, including 18 peer-reviewed journal articles, 46 papers, 28 reports, and 4 graduate theses. These efforts were summarized in our project report issued January 2005 and covering the period August 23, 1998-October 23, 2004. An accompanying CD contained electronic copies of all the papers and reports. This report focuses on results of a two-year sub-task to update an environmental assessment of acute marine impacts resulting from direct ocean sequestration. The approach is based on the work of Auerbach et al. [6] and Caulfield et al. [20] to assess mortality to zooplankton, but uses updated information concerning bioassays, an updated modeling approach and three modified injection scenarios: a point release of negatively buoyant solid CO{sub 2} hydrate particles from a moving ship; a long, bottom-mounted diffuser discharging buoyant liquid CO{sub 2} droplets; and a stationary point release of hydrate particles forming a sinking plume. Results suggest that in particular the first two discharge modes could be successfully designed to largely avoid zooplankton mortality. Sub-lethal and ecosystem effects are discussed qualitatively, but not analyzed quantitatively.

  12. Atmospheric CO2 concentrations during ancient greenhouse climates were similar

    E-Print Network [OSTI]

    Ahmad, Sajjad

    Atmospheric CO2 concentrations during ancient greenhouse climates were similar to those predicted atmospheric CO2 concentrations (½CO2atm) during Earth's ancient greenhouse episodes is essential for accurately predicting the response of future climate to elevated CO2 levels. Empirical estimates of ½CO2atm

  13. Growth, CO2 Consumption, and H2 Production of Anabaena variabilis ATCC 29413-U under Different Irradiances and CO2 Concentrations

    E-Print Network [OSTI]

    Berberoglu, Halil; Barra, Natasha; Pilon, Laurent; Jay, Jenny

    2008-01-01T23:59:59.000Z

    Phase Medium Irradiance ? H2 ? CO2 Maximum Reported Ratesa) Specific CO 2 uptake rate, ? CO2 (kg CO 2 /kg dry cell/h)

  14. September 26th, 2006 The Use of Water Injection for

    E-Print Network [OSTI]

    Mohaghegh, Shahab

    methane Coal surface Desorption of Methane and Gas Production #12;Coal surface Abandoned CBM Well Depleted Reservoir #12;Coal surface CO2 Injection Process CO2 molecule #12;Coal surface Free CO2 on the Cleat System for Reservoir Data Model Design Conclusions, Publications, Redesign #12;Defining the Model #12;Model Design

  15. DOE Targets Rural Indiana Geologic Formation for CO2 Storage Field Test

    Broader source: Energy.gov [DOE]

    A U.S. Department of Energy team of regional partners has begun injecting 8,000 tons of carbon dioxide (CO2) to evaluate the carbon storage potential and test the enhanced oil recovery (EOR) potential of the Mississippian-aged Clore Formation in Posey County, Ind.

  16. MEMBRANE PROCESS TO SEQUESTER CO2 FROM POWER PLANT FLUE GAS

    SciTech Connect (OSTI)

    Tim Merkel; Karl Amo; Richard Baker; Ramin Daniels; Bilgen Friat; Zhenjie He; Haiqing Lin; Adrian Serbanescu

    2009-03-31T23:59:59.000Z

    The objective of this project was to assess the feasibility of using a membrane process to capture CO2 from coal-fired power plant flue gas. During this program, MTR developed a novel membrane (Polaris™) with a CO2 permeance tenfold higher than commercial CO2-selective membranes used in natural gas treatment. The Polaris™ membrane, combined with a process design that uses a portion of combustion air as a sweep stream to generate driving force for CO2 permeation, meets DOE post-combustion CO2 capture targets. Initial studies indicate a CO2 separation and liquefaction cost of $20 - $30/ton CO2 using about 15% of the plant energy at 90% CO2 capture from a coal-fired power plant. Production of the Polaris™ CO2 capture membrane was scaled up with MTR’s commercial casting and coating equipment. Parametric tests of cross-flow and countercurrent/sweep modules prepared from this membrane confirm their near-ideal performance under expected flue gas operating conditions. Commercial-scale, 8-inch diameter modules also show stable performance in field tests treating raw natural gas. These findings suggest that membranes are a viable option for flue gas CO2 capture. The next step will be to conduct a field demonstration treating a realworld power plant flue gas stream. The first such MTR field test will capture 1 ton CO2/day at Arizona Public Service’s Cholla coal-fired power plant, as part of a new DOE NETL funded program.

  17. Active Management of Integrated Geothermal-CO2 Storage Reservoirs in Sedimentary Formations

    DOE Data Explorer [Office of Scientific and Technical Information (OSTI)]

    Buscheck, Thomas A.

    The purpose of phase 1 is to determine the feasibility of integrating geologic CO2 storage (GCS) with geothermal energy production. Phase 1 includes reservoir analyses to determine injector/producer well schemes that balance the generation of economically useful flow rates at the producers with the need to manage reservoir overpressure to reduce the risks associated with overpressure, such as induced seismicity and CO2 leakage to overlying aquifers. Based on a range of well schemes, techno-economic analyses of the levelized cost of electricity (LCOE) are conducted to determine the economic benefits of integrating GCS with geothermal energy production. In addition to considering CO2 injection, reservoir analyses are conducted for nitrogen (N2) injection to investigate the potential benefits of incorporating N2 injection with integrated geothermal-GCS, as well as the use of N2 injection as a potential pressure-support and working-fluid option. Phase 1 includes preliminary environmental risk assessments of integrated geothermal-GCS, with the focus on managing reservoir overpressure. Phase 1 also includes an economic survey of pipeline costs, which will be applied in Phase 2 to the analysis of CO2 conveyance costs for techno-economics analyses of integrated geothermal-GCS reservoir sites. Phase 1 also includes a geospatial GIS survey of potential integrated geothermal-GCS reservoir sites, which will be used in Phase 2 to conduct sweet-spot analyses that determine where promising geothermal resources are co-located in sedimentary settings conducive to safe CO2 storage, as well as being in adequate proximity to large stationary CO2 sources.

  18. INTERNATIONAL COLLABORATION ON CO2 SEQUESTRATION

    SciTech Connect (OSTI)

    Howard J. Herzog; E. Eric Adams

    2005-04-01T23:59:59.000Z

    On December 4, 1997, the US Department of Energy (DOE), the New Energy and Industrial Technology Development Organization of Japan (NEDO), and the Norwegian Research Council (NRC) entered into a ''Project Agreement for International Collaboration on CO{sub 2} Ocean Sequestration''. Government organizations from Japan, Canada, and Australia, and a Swiss/Swedish engineering firm later joined the agreement, which outlined a research strategy for ocean carbon sequestration via direct injection. The members agreed to an initial field experiment, with the hope that if the initial experiment was successful, there would be subsequent field evaluations of increasingly larger scale to evaluate environmental impacts of sequestration and the potential for commercialization. This report is a summary of the evolution of the collaborative effort, the supporting research, and results for the International Collaboration on CO{sub 2} Ocean Sequestration. Almost 100 papers and reports resulted from this collaboration, including 18 peer reviewed journal articles, 46 papers, 28 reports, and 4 graduate theses. A full listing of these publications is in the reference section.

  19. Satellite remote sounding of mid-tropospheric CO 2

    E-Print Network [OSTI]

    2008-01-01T23:59:59.000Z

    and Y. L. Yung (2006), CO 2 in the upper troposphere:derivatives with application to CO 2 , Geophys. Res. Lett. ,feasibility of monitoring CO 2 from high-resolution infrared

  20. International Symposium on Site Characterization for CO2 Geological Storage

    E-Print Network [OSTI]

    Tsang, Chin-Fu

    2006-01-01T23:59:59.000Z

    WITH SITE SCREENING AND SELECTION FOR CO 2 STORAGE D. A.77 ASSESSING AND EXPANDING CO 2 STORAGE CAPACITY IN DEPLETEDFOR CO 2 GEOLOGICAL STORAGE IN CENTRAL COAL BASIN (NORTHERN

  1. Assessment of Basin-Scale Hydrologic Impacts of CO2 Sequestration, Illinois Basin1 Mark Person*1

    E-Print Network [OSTI]

    Gable, Carl W.

    70 The Illinois Basin hosts dozens of coal fired power plants which generates about 300 million Formation. We used 726 injection wells located near51 42 power plants to deliver 80 million metric tons technical constraints on the injection of CO2 into deep (>1.5 km) reservoirs under supercritical75

  2. Hydro-mechanical modelling of geological CO2 storage and the study of possible caprock fracture mechanisms

    E-Print Network [OSTI]

    element modelling of a hypothetical underground carbon dioxide (CO2) storage operation. The hydro-mechanical properties of the materials modelled are chosen to be representative of a potential injection site. For high on the injection process, and on site and rock properties. Rutqvist et al. (2008) showed through a coupled

  3. abiotic co2 flows: Topics by E-print Network

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    into the potential behavior and the operational parameters of CO2 sequestration at CO2-EOR s... Dai, Zhenxue; Fessenden-Rahn, Julianna; Middleton, Richard; Pan, Feng; Jia,...

  4. af co2 fra: Topics by E-print Network

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    into the potential behavior and the operational parameters of CO2 sequestration at CO2-EOR s... Dai, Zhenxue; Fessenden-Rahn, Julianna; Middleton, Richard; Pan, Feng; Jia,...

  5. Summary Report on CO2 Geologic Sequestration & Water Resources Workshop

    E-Print Network [OSTI]

    Varadharajan, C.

    2013-01-01T23:59:59.000Z

    F Monitoring studies above EOR-CO2 fields Weyburn-MidaleTexas •? Over 30 years of CO2-EOR •? Sampled outside of

  6. Modeling CO2 Sequestration in a Saline Reservoir and Depleted...

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    Modeling CO 2 Sequestration in a Saline Reservoir and Depleted Oil Reservoir to Evaluate The Regional CO 2 Sequestration Potential of The Ozark Plateau Aquifer System,...

  7. Reaction of Water-Saturated Supercritical CO2 with Forsterite...

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    Water-Saturated Supercritical CO2 with Forsterite: Evidence for Magnesite Formation at Low Temperatures. Reaction of Water-Saturated Supercritical CO2 with Forsterite: Evidence for...

  8. Exsolution Enhanced Oil Recovery with Concurrent CO2 Sequestration...

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    Exsolution Enhanced Oil Recovery with Concurrent CO2 Sequestration. Exsolution Enhanced Oil Recovery with Concurrent CO2 Sequestration. Abstract: A novel EOR method using...

  9. Cryogenic CO2 Formation on Oxidized Gold Clusters Synthesized...

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    Cryogenic CO2 Formation on Oxidized Gold Clusters Synthesized via Reactive Layer Assisted Deposition. Cryogenic CO2 Formation on Oxidized Gold Clusters Synthesized via Reactive...

  10. From CO2 to Methanol via Novel Nanocatalysts

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    From CO2 to Methanol via Novel Nanocatalysts Print Researchers have found novel nanocatalysts that lower the barrier to converting carbon dioxide (CO2)-an abundant greenhouse...

  11. Geologic CO2 sequestration inhibits microbial growth | EMSL

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    community and could improve overall efficiency of CO2 sequestration. The Science Carbon dioxide (CO2) sequestration in deep subsurface environments has received...

  12. Variations in 13 C discrimination during CO2 exchange by

    E-Print Network [OSTI]

    as to differential diffusivities of 13 CO2 and 12 CO2 in air (Farquhar, O'Leary & Berry 1982; O'Leary 1984

  13. 10 MW Supercritical CO2 Turbine Test

    SciTech Connect (OSTI)

    Turchi, Craig

    2014-01-29T23:59:59.000Z

    The Supercritical CO2 Turbine Test project was to demonstrate the inherent efficiencies of a supercritical carbon dioxide (s-CO2) power turbine and associated turbomachinery under conditions and at a scale relevant to commercial concentrating solar power (CSP) projects, thereby accelerating the commercial deployment of this new power generation technology. The project involved eight partnering organizations: NREL, Sandia National Laboratories, Echogen Power Systems, Abengoa Solar, University of Wisconsin at Madison, Electric Power Research Institute, Barber-Nichols, and the CSP Program of the U.S. Department of Energy. The multi-year project planned to design, fabricate, and validate an s-CO2 power turbine of nominally 10 MWe that is capable of operation at up to 700°C and operates in a dry-cooled test loop. The project plan consisted of three phases: (1) system design and modeling, (2) fabrication, and (3) testing. The major accomplishments of Phase 1 included: Design of a multistage, axial-flow, s-CO2 power turbine; Design modifications to an existing turbocompressor to provide s-CO2 flow for the test system; Updated equipment and installation costs for the turbomachinery and associated support infrastructure; Development of simulation tools for the test loop itself and for more efficient cycle designs that are of greater commercial interest; Simulation of s-CO2 power cycle integration into molten-nitrate-salt CSP systems indicating a cost benefit of up to 8% in levelized cost of energy; Identification of recuperator cost as a key economic parameter; Corrosion data for multiple alloys at temperatures up to 650ºC in high-pressure CO2 and recommendations for materials-of-construction; and Revised test plan and preliminary operating conditions based on the ongoing tests of related equipment. Phase 1 established that the cost of the facility needed to test the power turbine at its full power and temperature would exceed the planned funding for Phases 2 and 3. Late in Phase 1 an opportunity arose to collaborate with another turbine-development team to construct a shared s-CO2 test facility. The synergy of the combined effort would result in greater facility capabilities than either separate project could produce and would allow for testing of both turbine designs within the combined budgets of the two projects. The project team requested a no-cost extension to Phase 1 to modify the subsequent work based on this collaborative approach. DOE authorized a brief extension, but ultimately opted not to pursue the collaborative facility and terminated the project.

  14. CO2 Compression | netl.doe.gov

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative1 First Use of Energy for All Purposes (Fuel and Nonfuel), 2002; Level: National5Sales for4,645 3,625govInstrumentstdmadapInactiveVisiting the TWPSuccess Stories Siteandscience, and8Critical4CO2 Compression CO2

  15. Development of Novel CO2 Adsorbents for Capture of CO2 from Flue Gas

    SciTech Connect (OSTI)

    Fauth, D.J.; Filburn, T.P. (University of Hartford, West Hartford, CT); Gray, M.L.; Hedges, S.W.; Hoffman, J.; Pennline, H.W.; Filburn, T.

    2007-06-01T23:59:59.000Z

    Capturing CO2 emissions generated from fossil fuel-based power plants has received widespread attention and is considered a vital course of action for CO2 emission abatement. Efforts are underway at the Department of Energy’s National Energy Technology Laboratory to develop viable energy technologies enabling the CO2 capture from large stationary point sources. Solid, immobilized amine sorbents (IAS) formulated by impregnation of liquid amines within porous substrates are reactive towards CO2 and offer an alternative means for cyclic capture of CO2 eliminating, to some degree, inadequacies related to chemical absorption by aqueous alkanolamine solutions. This paper describes synthesis, characterization, and CO2 adsorption properties for IAS materials previously tested to bind and release CO2 and water vapor in a closed loop life support system. Tetraethylenepentamine (TEPA), acrylonitrile-modified tetraethylenepentamine (TEPAN), and a single formulation consisting of TEPAN and N, N’-bis(2-hydroxyethyl)ethylenediamine (BED) were individually supported on a poly (methyl methacrylate) (PMMA) substrate and examined. CO2 adsorption profiles leading to reversible CO2 adsorption capacities were obtained using thermogravimetry. Under 10% CO2 in nitrogen at 25°C and 1 atm, TEPA supported on PMMA over 60 minutes adsorbed ~3.2 mmol/g{sorbent} whereas, TEPAN supported on PMMA along with TEPAN and BED supported on PMMA adsorbed ~1.7 mmol/g{sorbent} and ~2.3 mmol/g{sorbent} respectively. Cyclic experiments with a 1:1 weight ratio of TEPAN and BED supported on poly (methyl methacrylate) beads utilizing a fixed-bed flow system with 9% CO2, 3.5% O2, nitrogen balance with trace gas constituents were studied. CO2 adsorption capacity was ~ 3 mmols CO2/g{sorbent} at 40°C and 1.4 atm. No beneficial effect on IAS performance was found using a moisture-laden flue gas mixture. Tests with 750 ppmv NO in a humidified gas stream revealed negligible NO sorption onto the IAS. A high SO2 concentration resulted in incremental loss in IAS performance and revealed progressive degrees of “staining” upon testing. Adsorption of SO2 by the IAS necessitates upstream removal of SO2 prior to CO2 capture.

  16. Rapid precipitation of magnesite micro-crystals from Mg(OH)2-H2O-CO2 slurry enhanced by NaOH and a heat-ageing step (from

    E-Print Network [OSTI]

    Boyer, Edmond

    sequential reactions: (1) aqueous carbonation of synthetic brucite (Mg(OH)2) by injection of CO2 in a highly system at ambient temperatures and at atmospheric CO2 partial pressure is of both geological interest1 Rapid precipitation of magnesite micro-crystals from Mg(OH)2- H2O-CO2 slurry enhanced by Na

  17. Simulation of Coupled Processes of Flow, Transport, and Storage of CO2 in Saline Aquifers

    SciTech Connect (OSTI)

    Wu, Yu-Shu; Chen, Zizhong; Kazemi, Hossein; Yin, Xiaolong; Pruess, Karsten; Oldenburg, Curt; Winterfeld, Philip; Zhang, Ronglei

    2014-09-30T23:59:59.000Z

    This report is the final scientific one for the award DE- FE0000988 entitled “Simulation of Coupled Processes of Flow, Transport, and Storage of CO2 in Saline Aquifers.” The work has been divided into six tasks. In task, “Development of a Three-Phase Non-Isothermal CO2 Flow Module,” we developed a fluid property module for brine-CO2 mixtures designed to handle all possible phase combinations of aqueous phase, sub-critical liquid and gaseous CO2, supercritical CO2, and solid salt. The thermodynamic and thermophysical properties of brine-CO2 mixtures (density, viscosity, and specific enthalpy of fluid phases; partitioning of mass components among the different phases) use the same correlations as an earlier fluid property module that does not distinguish between gaseous and liquid CO2-rich phases. We verified the fluid property module using two leakage scenarios, one that involves CO2 migration up a blind fault and subsequent accumulation in a secondary “parasitic” reservoir at shallower depth, and another investigating leakage of CO2 from a deep storage reservoir along a vertical fault zone. In task, “Development of a Rock Mechanical Module,” we developed a massively parallel reservoir simulator for modeling THM processes in porous media brine aquifers. We derived, from the fundamental equations describing deformation of porous elastic media, a momentum conservation equation relating mean stress, pressure, and temperature, and incorporated it alongside the mass and energy conservation equations from the TOUGH2 formulation, the starting point for the simulator. In addition, rock properties, namely permeability and porosity, are functions of effective stress and other variables that are obtained from the literature. We verified the simulator formulation and numerical implementation using analytical solutions and example problems from the literature. For the former, we matched a one-dimensional consolidation problem and a two-dimensional simulation of the Mandel-Cryer effect. For the latter, we obtained a good match of temperature and gas saturation profiles, and surface uplift, after injection of hot fluid into a model of a caldera structure. In task, “Incorporation of Geochemical Reactions of Selected Important Species,” we developed a novel mathematical model of THMC processes in porous and fractured saline aquifers, simulating geo-chemical reactions associated with CO2 sequestration in saline aquifers. Two computational frameworks, sequentially coupled and fully coupled, were used to simulate the reactions and transport. We verified capabilities of the THMC model to treat complex THMC processes during CO2 sequestration by analytical solutions and we constructed reactive transport models to analyze the THMC process quantitatively. Three of these are 1D reactive transport under chemical equilibrium, a batch reaction model with equilibrium chemical reactions, and a THMC model with CO2 dissolution. In task “Study of Instability in CO2 Dissolution-Diffusion-Convection Processes,” We reviewed literature related to the study of density driven convective flows and on the instability of CO2 dissolution-diffusion-convection processes. We ran simulations that model the density-driven flow instability that would occur during CO2 sequestration. CO2 diffused through the top of the system and dissolved in the aqueous phase there, increasing its density. Density fingers formed along the top boundary, and coalesced into a few prominent ones, causing convective flow that forced the fluid to the system bottom. These simulations were in two and three dimensions. We ran additional simulations of convective mixing with density contrast caused by variable dissolved CO2 concentration in saline water, modeled after laboratory experiments in which supercritical CO2 was circulated in the headspace above a brine saturated packed sand in a pressure vessel. As CO2 dissolved into the upper part of the saturated sand, liquid phase density increases causing instability and setting off convective mixing. We obtained good agreement

  18. Evaluation of experimentally measured and model-calculated pH for rock-brine-CO2 systems under geologic CO2 sequestration conditions

    SciTech Connect (OSTI)

    Shao, Hongbo; Thompson, Christopher J.; Cantrell, Kirk J.

    2013-11-01T23:59:59.000Z

    pH is an essential parameter for understanding the geochemical reactions that occur in rock-brine-CO2 systems when CO2 is injected into deep geologic formations for long-term storage. Due to a lack of reliable experimental methods, most laboratory studies conducted under geological CO2 sequestration (GCS) conditions have relied on thermodynamic modeling to estimate pH. The accuracy of these model predictions is typically uncertain. In our previous work, we have developed a method for pH determination by in-situ spectrophotometry. In the present work, we expanded the applicable pH range for this method and measured the pH of several rock-brine-CO2 systems at GCS conditions for five rock samples collected from ongoing GCS demonstration projects. Experimental measurements were compared with pH values calculated using several geochemical modeling approaches. The effect of different thermodynamic databases on the accuracy of model prediction was evaluated. Results indicate that the accuracy of model calculations is rock-dependent. For rocks comprised of carbonate and sandstone, model results generally agreed well with experimentally measured pH; however, for basalt, significant differences were observed. These discrepancies may be due to the models’ failure to fully account for certain reaction occurring between the basalt minerals the CO2-saturated brine solutions.

  19. In Situ Spectrophotometric Determination of pH under Geologic CO2 Sequestration Conditions: Method Development and Application

    SciTech Connect (OSTI)

    Shao, Hongbo; Thompson, Christopher J.; Qafoku, Odeta; Cantrell, Kirk J.

    2013-02-25T23:59:59.000Z

    Injecting massive amounts of CO2 into deep geologic formations will cause a range of coupled thermal, hydrodynamic, mechanical, and chemical changes. A significant perturbation in water-saturated formations is the pH drop in the reservoir fluids due to CO2 dissolution. Knowing the pH under geological CO2 sequestration conditions is important for a better understanding of the short- and long-term risks associated with geological CO2 sequestration and will help in the design of sustainable sequestration projects. Most previous studies on CO2-rock-brine interactions have utilized thermodynamic modeling to estimate the pH. In this work, a spectrophotometric method was developed to determine the in-situ pH in CO2-H2O-NaCl systems in the presence and absence of reservoir rock by observing the spectra of a pH indicator, bromophenol blue, with a UV-visible spectrophotometer. Effects of temperature, pressure, and ionic strength on the pH measurement were evaluated. Measured pH values in CO2-H2O-NaCl systems were compared with several thermodynamic models. Results indicate that bromophenol blue can be used to accurately determine the pH of brine in contact with supercritical CO2 under geologic CO2 sequestration conditions.

  20. Porous Hexacyanometalates for CO2 capture applications

    SciTech Connect (OSTI)

    Motkuri, Radha K.; Thallapally, Praveen K.; McGrail, B. Peter

    2013-07-30T23:59:59.000Z

    Prussian blue analogues of M3[Fe(CN)6]2 x H2O (where M=Fe, Mn and Ni) were synthesized, characterized and tested for their gas sorption capabilities. The sorption studies reveal that, these Prussian blue materials preferentially sorb CO2 over N2 and CH4 at low pressure (1bar).

  1. Ocean Acidification: The Other CO2 Problem

    E-Print Network [OSTI]

    Childress, Michael J.

    reserved 1941-1405/09/0115-0169$20.00 Key Words biogeochemistry, calcification, carbon dioxide, climate of calcium carbonate saturation states, which impacts shell-forming marine organisms from plankton to benthic for marine organisms to adapt to increasing CO2 and broader implications for ocean ecosystems are not well

  2. Aquifer Management for CO2 Sequestration 

    E-Print Network [OSTI]

    Anchliya, Abhishek

    2010-07-14T23:59:59.000Z

    Storage of carbon dioxide is being actively considered for the reduction of green house gases. To make an impact on the environment CO2 should be put away on the scale of gigatonnes per annum. The storage capacity of deep saline aquifers...

  3. Projecting human development and CO2 emissions

    E-Print Network [OSTI]

    Costa, Luís; Kropp, Jürgen P

    2012-01-01T23:59:59.000Z

    We estimate cumulative CO2 emissions during the period 2000 to 2050 from developed and developing countries based on the empirical relationship between CO2 per capita emissions (due to fossil fuel combustion and cement production) and corresponding HDI. In order to project per capita emissions of individual countries we make three assumptions which are detailed below. First, we use logistic regressions to fit and extrapolate the HDI on a country level as a function of time. This is mainly motivated by the fact that the HDI is bounded between 0 and 1 and that it decelerates as it approaches 1. Second, we employ for individual countries the correlations between CO2 per capita emissions and HDI in order to extrapolate their emissions. This is an ergodic assumption. Third, we let countries with incomplete data records evolve similarly as their close neighbors (in the emissions-HDI plane, see Fig. 1 in the main text) with complete time series of CO2 per capita emissions and HDI. Country-based emissions estimates a...

  4. Natural and industrial analogues for leakage of CO2 from storagereservoirs: identification of features, events, and processes and lessonslearned

    SciTech Connect (OSTI)

    Lewicki, Jennifer L.; Birkholzer, Jens; Tsang, Chin-Fu

    2006-02-28T23:59:59.000Z

    The injection and storage of anthropogenic CO2 in deepgeologic formations is a potentially feasible strategy to reduce CO2emissions and atmospheric concentrations. While the purpose of geologiccarbon storage is to trap CO2 underground, CO2 could migrate away fromthe storage site into the shallow subsurface and atmosphere if permeablepathways such as well bores or faults are present. Large-magnitudereleases of CO2 have occurred naturally from geologic reservoirs innumerous volcanic, geothermal, and sedimentary basin settings. Carbondioxide and natural gas have also been released from geologic CO2reservoirs and natural gas storage facilities, respectively, due toinfluences such as well defects and injection/withdrawal processes. Thesesystems serve as natural and industrial analogues for the potentialrelease of CO2 from geologic storage reservoirs and provide importantinformation about the key features, events, and processes (FEPs) that areassociated with releases, as well as the health, safety, andenvironmental consequences of releases and mitigation efforts that can beapplied. We describe a range of natural releases of CO2 and industrialreleases of CO2 and natural gas in the context of these characteristics.Based on this analysis, several key conclusions can be drawn, and lessonscan be learned for geologic carbon storage. First, CO2 can bothaccumulate beneath, and be released from, primary and secondaryreservoirs with capping units located at a wide range of depths. Bothprimary and secondary reservoir entrapments for CO2 should therefore bewell characterized at storage sites. Second, many natural releases of CO2have been correlated with a specific event that triggered the release,such as magmatic fluid intrusion or seismic activity. The potential forprocesses that could cause geomechanical damage to sealing cap rocks andtrigger the release of CO2 from a storage reservoir should be evaluated.Third, unsealed fault and fracture zones may act as fast and directconduits for CO2 flow from depth to the surface. Risk assessment shouldtherefore emphasize determining the potential for and nature of CO2migration along these structures. Fourth, wells that are structurallyunsound have the potential to rapidly release large quantities of CO2 tothe atmosphere. Risk assessment should therefore be focused on thepotential for both active and abandoned wells at storage sites totransport CO2 to the surface, particularly at sites with depleted oil orgas reservoirs where wellsare abundant. Fifth, the style of CO2 releaseat the surface varies widely between and within different leakage sites.In rare circumstances, the release of CO2 can be a self-enhancing and/oreruptive process; this possibility should be assessed in the case of CO2leakage from storage reservoirs. Sixth, the hazard to human health hasbeen small in most cases of large surface releases of CO2. This could bedue to implementation of public education and CO2 monitoring programs;these programs should therefore be employed to minimize potential health,safety, and environmental effects associated with CO2 leakage. Finally,while changes in groundwater chemistry were related to CO2 leakage due toacidification and interaction with host rocks along flow paths, watersremained potable in most cases. Groundwaters should be monitored forchanges that may be associated with storage reservoirleakage.

  5. Northern California CO2 Reduction Project

    SciTech Connect (OSTI)

    Hymes, Edward

    2010-06-16T23:59:59.000Z

    C6 Resources LLC, a wholly owned subsidiary of Shell Oil Company, worked with the US Department of Energy (DOE) under a Cooperative Agreement to develop the Northern California CO2 Reduction Project. The objective of the Project is to demonstrate the viability of using Carbon Capture and Sequestration (CCS) to reduce existing greenhouse gas emissions from industrial sources on a large-scale. The Project will capture more than 700,000 metric tonnes of CO2 per year, which is currently being vented to the atmosphere from the Shell Martinez Refinery in Contra Costa County. The CO2 will be compressed and dehydrated at the refinery and then transported via pipeline to a sequestration site in a rural area in neighboring Solano County. The CO2 will be sequestered into a deep saline formation (more than two miles underground) and will be monitored to assure secure, long-term containment. The pipeline will be designed to carry as much as 1,400,000 metric tonnes of CO2 per year, so additional capacity will be available to accommodate CO2 captured from other industrial sources. The Project is expected to begin operation in 2015. The Project has two distinct phases. The overall objective of Phase 1 was to develop a fully definitive design basis for the Project. The Cooperative Agreement with the DOE provided cost sharing for Phase 1 and the opportunity to apply for additional DOE cost sharing for Phase 2, comprising the design, construction and operation of the Project. Phase 1 has been completed. DOE co-funding is provided by the American Recovery and Reinvestment Act (ARRA) of 2009. As prescribed by ARRA, the Project will stimulate the local economy by creating manufacturing, transportation, construction, operations, and management jobs while addressing the need to reduce greenhouse gas emissions at an accelerated pace. The Project, which will also assist in meeting the CO2 reduction requirements set forth in California?s Climate Change law, presents a major opportunity for both the environment as well as the region. C6 Resources is conducting the Project in collaboration with federally-funded research centers, such as Lawrence Berkeley National Lab and Lawrence Livermore National Lab. C6 Resources and Shell have identified CCS as one of the critical pathways toward a worldwide goal of providing cleaner energy. C6 Resources, in conjunction with the West Coast Regional Carbon Sequestration Partnership (WESTCARB), has conducted an extensive and ongoing public outreach and CCS education program for local, regional and state-wide stakeholders. As part of a long term relationship, C6 Resources will continue to engage directly with community leaders and residents to ensure public input and transparency. This topical report summarizes the technical work from Phase 1 of the Project in the following areas: ? Surface Facility Preliminary Engineering: summarizes the preliminary engineering work performed for CO2 capture, CO2 compression and dehydration at the refinery, and surface facilities at the sequestration site ? Pipeline Preliminary Engineering: summarizes the pipeline routing study and preliminary engineering design ? Geologic Sequestration: summarizes the work to characterize, model and evaluate the sequestration site ? Monitoring, Verification and Accounting (MVA): summarizes the MVA plan to assure long-term containment of the sequestered CO2

  6. Advanced Technologies for Monitoring CO2 Saturation and Pore Pressure in Geologic Formations: Linking the Chemical and Physical Effects to Elastic and Transport Properties

    SciTech Connect (OSTI)

    Mavko, G.; Vanorio, T.; Vialle, S.; Saxena, N.

    2014-03-31T23:59:59.000Z

    Ultrasonic P- and S-wave velocities were measured over a range of confining pressures while injecting CO2 and brine into the samples. Pore fluid pressure was also varied and monitored together with porosity during injection. Effective medium models were developed to understand the mechanisms and impact of observed changes and to provide the means for implementation of the interpretation methodologies in the field. Ultrasonic P- and S-wave velocities in carbonate rocks show as much as 20-50% decrease after injection of the reactive CO2-brine mixture; the changes were caused by permanent changes to the rock elastic frame associated with dissolution of mineral. Velocity decreases were observed under both dry and fluid-saturated conditions, and the amount of change was correlated with the initial pore fabrics. Scanning Electron Microscope images of carbonate rock microstructures were taken before and after injection of CO2-rich water. The images reveal enlargement of the pores, dissolution of micrite (micron-scale calcite crystals), and pitting of grain surfaces caused by the fluid- solid chemical reactivity. The magnitude of the changes correlates with the rock microtexture – tight, high surface area samples showed the largest changes in permeability and smallest changes in porosity and elastic stiffness compared to those in rocks with looser texture and larger intergranular pore space. Changes to the pore space also occurred from flow of fine particles with the injected fluid. Carbonates with grain-coating materials, such as residual oil, experienced very little permanent change during injection. In the tight micrite/spar cement component, dissolution is controlled by diffusion: the mass transfer of products and reactants is thus slow and the fluid is expected to be close to thermodynamical equilibrium with the calcite, leading to very little dissolution, or even precipitation. In the microporous rounded micrite and macropores, dissolution is controlled by advection: because of an efficient mass transfer of reactants and products, the fluid remains acidic, far from thermodynamical equilibrium and the dissolution of calcite is important. These conclusions are consistent with the lab observations. Sandstones from the Tuscaloosa formation in Mississippi were also subjected to injection under representative in situ stress and pore pressure conditions. Again, both P- and S-wave velocities decreased with injection. Time-lapse SEM images indicated permanent changes induced in the sandstone microstructure by chamosite dissolution upon injection of CO2-rich brine. After injection, the sandstone showed an overall cleaner microstructure. Two main changes are involved: (a) clay dissolution between grains and at the grain contact and (b) rearrangement of grains due to compaction under pressure Theoretical and empirical models were developed to quantify the elastic changes associated with injection. Permanent changes to the rock frame resulted in seismic velocity-porosity trends that mimic natural diagenetic changes. Hence, when laboratory measurments are not available for a candidate site, these trends can be estimated from depth trends in well logs. New theoretical equations were developed to predict the changes in elastic moduli upon substitution of pore-filling material. These equations reduce to Gassmann’s equations for the case of constant frame properties, low seismic frequencies, and fluid changes in the pore space. The new models also predict the change dissolution or precipitation of mineral, which cannot be described with the conventional Gassmann theory.

  7. IMPLEMENTING A NOVEL CYCLIC CO2 FLOOD IN PALEOZOIC REEFS

    SciTech Connect (OSTI)

    James R. Wood; W. Quinlan; A. Wylie

    2004-07-01T23:59:59.000Z

    Recycled CO2 will be used in this demonstration project to produce bypassed oil from the Silurian Dover 35 pinnacle reef (Otsego County) in the Michigan Basin. We began injecting CO2 in the Dover 35 field into the Salling-Hansen 4-35A well on May 6, 2004. Subsurface characterization is being completed using well log tomography animations and 3D visualizations to map facies distributions and reservoir properties in three reefs, the Belle River Mills, Chester 18, and Dover 35 Fields. The Belle River Mills and Chester 18 fields are being used as type-fields because they have excellent log and/or core data coverage. Amplitude slicing of the log porosity, normalized gamma ray, core permeability, and core porosity curves is showing trends that indicate significant heterogeneity and compartmentalization in these reservoirs associated with the original depositional fabric of the rocks. Digital and hard copy data continues to be compiled for the Niagaran reefs in the Michigan Basin. Technology transfer took place through technical presentations regarding visualization of the heterogeneity of the Niagaran reefs. Oral presentations were given at the Petroleum Technology Transfer Council workshop, Michigan Oil and Gas Association Conference, and Michigan Basin Geological Society meeting. A technical paper was submitted to the Bulletin of the American Association of Petroleum Geologists on the characterization of the Belle River Mills Field.

  8. Long-time evolution of sequestered CO$_2$ in porous media

    E-Print Network [OSTI]

    Cohen, Yossi

    2014-01-01T23:59:59.000Z

    CO$_2$ sequestration in subsurface reservoirs is important for limiting atmospheric CO$_2$ concentrations. However, a complete physical picture able to predict the structure developing within the porous medium is lacking. We investigate theoretically reactive transport in the long-time evolution of carbon in the brine-rock environment. As CO$_2$ is injected into a brine-rock environment, a carbonate-rich region is created amid brine. Within the carbonate-rich region minerals dissolve and migrate from regions of high concentration to low concentration, along with other dissolved carbonate species. This causes mineral precipitation at the interface between the two regions. We argue that precipitation in a small layer reduces diffusivity, and eventually causes mechanical trapping of the CO$_2$. Consequently, only a small fraction of the CO$_2$ is converted to solid mineral; the remainder either dissolves in water or is trapped in its original form. We also study the case of a pure CO$_2$ bubble surrounded by bri...

  9. Root-derived CO2 efflux via xylem stream rivals soil CO2 efflux.

    SciTech Connect (OSTI)

    Aubrey, Doug, P.; Teskey, Robert, O.

    2009-07-01T23:59:59.000Z

    • Respiration consumes a large portion of annual gross primary productivity in forest ecosystems and is dominated by belowground metabolism. Here, we present evidence of a previously unaccounted for internal CO2 flux of large magnitude from tree roots through stems. If this pattern is shown to persist over time and in other forests, it suggests that belowground respiration has been grossly underestimated. • Using an experimental Populus deltoides plantation as a model system, we tested the hypothesis that a substantial portion of the CO2 released from belowground autotrophic respiration remains within tree root systems and is transported aboveground through the xylem stream rather than diffusing into the soil atmosphere. • On a daily basis, the amount of CO2 that moved upward from the root system into the stem via the xylem stream (0.26 mol CO2 m?2 d?1) rivalled that which diffused from the soil surface to the atmosphere (0.27 mol CO2 m?2 d?1). We estimated that twice the amount of CO2 derived from belowground autotrophic respiration entered the xylem stream as diffused into the soil environment. • Our observations indicate that belowground autotrophic respiration consumes substantially more carbohydrates than previously recognized and challenge the paradigm that all root-respired CO2 diffuses into the soil atmosphere.

  10. CO2 stimulation of photosynthesis is not sustained during long-term (12 years) FACE treatments in Liquidambar styraciflua

    SciTech Connect (OSTI)

    Warren, Jeffrey [ORNL; Jensen, Anna M [ORNL; Medlyn, Belinda [Macquarie University; Norby, Richard J [ORNL; Tissue, David Thomas [ORNL

    2015-01-01T23:59:59.000Z

    Elevated atmospheric CO2 (eCO2) often increases photosynthetic CO2 assimilation (A) in field studies of temperate tree species, although there is evidence that the increases may decline through time due to biochemical and morphological acclimation, and environmental constraints. Indeed, at the free air CO2 enrichment (FACE) study in Oak Ridge, Tennessee, A was increased in 12-year-old sweetgum trees following two years of ~40% enhancement of CO2. A was re-assessed a decade later to determine if initial enhancement of CO2 was sustained through time. Measurements were conducted at prevailing CO2 and temperature on detached, re-hydrated branches using a portable gas exchange system. Photosynthetic CO2 response curves (A-Ci curves) were contrasted with earlier measurements using consistent leaf photosynthesis model equations. Relationships between maximum electron transport rate (Jmax), maximum Rubisco activity (Vcmax) and foliar nitrogen (N) and chlorophyll content were assessed. In 1999, light-saturated photosynthesis (Asat) for eCO2 treatments was 15.4 0.8 mol m-2 s-1, 22% higher than aCO2 treatments (P<0.01). By 2009, Asat declined to <50% of 1999 values, and there was no longer a significant effect of eCO2 (Asat = 6.9 or 5.7 0.7 mol m-2 s-1 for eCO2 or aCO2, respectively). In 1999, there was no treatment effect on area-based foliar N; however, by 2008, N content in eCO2 foliage was 17% less than in aCO2 foliage. Photosynthetic N use efficiency (Asat:N) was greater in eCO2 in 1999 resulting in greater Asat despite similar N content, but the enhanced efficiency in eCO2 trees was lost as foliar N declined to sub-optimal levels. There was no treatment difference in the declining linear relationships between Jmax or Vcmax with declining N, or in the ratio of Jmax:Vcmax through time. Results suggest that initial enhancement of photosynthesis to elevated CO2 will not be sustained through time if nitrogen becomes limited.

  11. CO2 Storage and Sink Enhancements: Developing Comparable Economics

    E-Print Network [OSTI]

    CO2 Storage and Sink Enhancements: Developing Comparable Economics B.R. Bock1 , R.G. Rhudy2 , and H technologies and practices under development for CO2 storage and sink enhancement, including options. For the geologic and ocean storage options, CO2 capture costs from another project were added to the costs of CO2

  12. Original article Limitation of photosynthetic activity by CO2

    E-Print Network [OSTI]

    Paris-Sud XI, Université de

    Original article Limitation of photosynthetic activity by CO2 availability in the chloroplasts to resistances opposing the CO2 fluxes in the mesophyll of tree leaves. To validate this assertion, values of CO2 CO2 assimilation and respiration rate measurement, and using the known electron requirements (four

  13. CO2 levels during the greenhouse of the Paleocene

    E-Print Network [OSTI]

    Shull, Kenneth R.

    CO2 levels during the greenhouse of the Paleocene Eocene Thermal Maximum (PETM) Francesca A. Mc, Boulder #12;Estimating paleopCO2 0 5 10 15 20 25 30 0 500 1000 1500 2000 2500 3000 Meter Level, start of CIE=0 pCO2 pCO2 values using different calculation methods Bulk nalk For the past 250 years human

  14. CO2 enrichment increases carbon and nitrogen input from

    E-Print Network [OSTI]

    CO2 enrichment increases carbon and nitrogen input from fine roots in a deciduous forest Colleen2 Ecological Society of America, 2008 #12;#12;#12;#12;#12;+ [CO2] #12;+ Net primary production + [CO2] #12;+ Net primary production + [CO2] + C and N storage in biomass #12;+ Net primary production

  15. Cost Assessment of CO2 Sequestration by Mineral Carbonation 

    E-Print Network [OSTI]

    Yeboah, F. E.; Yegulalp, T. M.; Singh, H.

    2006-01-01T23:59:59.000Z

    Cost Assessment of CO2 Sequestration by Mineral Carbonation Frank E. Yeboah Tuncel M. Yegulalp Harmohindar Singh Research Associate Professor Professor Center for Energy Research... them carbon dioxide (CO 2 ). This paper assesses the cost of sequestering CO 2 produced by a ZEC power plant using solid sequestration process. INTRODUCTION CO 2 is produced when electrical energy is generated using conventional fossil...

  16. Cost Assessment of CO2 Sequestration by Mineral Carbonation

    E-Print Network [OSTI]

    Yeboah, F. E.; Yegulalp, T. M.; Singh, H.

    2006-01-01T23:59:59.000Z

    Cost Assessment of CO2 Sequestration by Mineral Carbonation Frank E. Yeboah Tuncel M. Yegulalp Harmohindar Singh Research Associate Professor Professor Center for Energy Research... them carbon dioxide (CO 2 ). This paper assesses the cost of sequestering CO 2 produced by a ZEC power plant using solid sequestration process. INTRODUCTION CO 2 is produced when electrical energy is generated using conventional fossil...

  17. Tagging CO2 to Enable Quantitative Inventories of Geological Carbon Storage

    SciTech Connect (OSTI)

    Lackner, Klaus; Matter, Juerg; Park, Ah-Hyung; Stute, Martin; Carson, Cantwell; Ji, Yinghuang

    2014-06-30T23:59:59.000Z

    In the wake of concerns about the long term integrity and containment of sub-surface CO2 sequestration reservoirs, many efforts have been made to improve the monitoring, verification, and accounting methods for geo-sequestered CO2. Our project aimed to demonstrate the feasibility of a system designed to tag CO2 with carbon isotope 14C immediately prior to sequestration to a level that is normal on the surface (one part per trillion). Because carbon found at depth is naturally free of 14C, this tag would easily differentiate pre-existing carbon from anthropogenic injected carbon and provide an excellent handle for monitoring its whereabouts in the subsurface. It also creates an excellent handle for adding up anthropogenic carbon inventories. Future inventories in effect count 14C atoms. Accordingly, we have developed a 14C tagging system suitable for use at the part-per-trillion level. This system consists of a gas-exchange apparatus to make disposable cartridges ready for controlled injection into a fast flowing stream of pressurized CO2. We built a high-pressure injection and tagging system, and a 14C detection system. The disposable cartridge and injection system have been successfully demonstrated in the lab with a high-pressure flow reactor, as well as in the field at the CarbFix CO2 sequestration site in Iceland. The laser-based 14C detection system originally conceived has been shown to possess inadequate sensitivity for ambient levels. Alternative methods for detecting 14C, such as saturated cavity absorption ringdown spectroscopy and scintillation counting, may still be suitable. KEYWORDS

  18. CO2 Storage and Enhanced Oil Recovery: Bald Unit Test Site, Mumford Hills Oil Field, Posey County, Indiana

    SciTech Connect (OSTI)

    Frailey, Scott M.; Krapac, Ivan G.; Damico, James R.; Okwen, Roland T.; McKaskle, Ray W.

    2012-03-30T23:59:59.000Z

    The Midwest Geological Sequestration Consortium (MGSC) carried out a small-scale carbon dioxide (CO2) injection test in a sandstone within the Clore Formation (Mississippian System, Chesterian Series) in order to gauge the large-scale CO2 storage that might be realized from enhanced oil recovery (EOR) of mature Illinois Basin oil fields via miscible liquid CO2 flooding. As part of the MGSC�������¢����������������s Validation Phase (Phase II) studies, the small injection pilot test was conducted at the Bald Unit site within the Mumford Hills Field in Posey County, southwestern Indiana, which was chosen for the project on the basis of site infrastructure and reservoir conditions. Geologic data on the target formation were extensive. Core analyses, porosity and permeability data, and geophysical logs from 40 wells were used to construct cross sections and structure contour and isopach maps in order to characterize and define the reservoir architecture of the target formation. A geocellular model of the reservoir was constructed to improve understanding of CO2 behavior in the subsurface. At the time of site selection, the Field was under secondary recovery through edge-water injection, but the wells selected for the pilot in the Bald Unit had been temporarily shut-in for several years. The most recently shut-in production well, which was surrounded by four nearby shut-in production wells in a five-spot pattern, was converted to CO2 injection for this pilot. Two additional wells outside the immediate five-spot pattern, one of which was an active producer, were instrumented to measure surface temperature and pressure. The CO2 injection period lasted from September 3, 2009, through December 14, 2010, with one three-month interruption caused by cessation of CO2 deliveries due to winter weather. Water was injected into the CO2 injection well during this period. A total of 6,300 tonnes (6,950 tons) of CO2 were injected into the reservoir at rates that generally ranged from 18 to 32 tonnes (20 to 35 tons) per day. The CO2 injection bottomhole pressure generally remained at 8.3 to 9.0 MPag (1,200 to 1,300 psig). The CO2 injection was followed by continued monitoring for nine months during post-CO2 water injection. A monitoring, verification, and accounting (MVA) program was designed to determine the fate of injected CO2. Extensive periodic sampling and analysis of brine, groundwater, and produced gases began before CO2 injection and continued through the monitored waterflood periods. Samples were gathered from production wells and three newly installed groundwater monitoring wells. Samples underwent geochemical and isotopic analyses to reveal any CO2-related changes. Groundwater and kinetic modeling and mineralogical analysis were also employed to better understand the long-term dynamics of CO2 in the reservoir. No CO2 leakage into groundwater was detected, and analysis of brine and gas chemistry made it possible to track the path of plume migration and infer geochemical reactions and trapping of CO2. Cased-hole logging did not detect any CO2 in the near-wellbore region. An increase in CO2 concentration was first detected in February 2010 from the gas present in the carboy during brine sampling; however, there was no appreciable gas volume associated with the detection of CO2. The first indication of elevated gas rates from the commingled gas of the pilot�������¢����������������s production wells occurred in July 2010 and reached a maximum of 0.36 tonnes/day (0.41 tons/day) in September 2010. An estimated 27 tonnes (30 tons) of CO2 were produced at the surface from the gas separator at the tank battery from September 3, 2009, through September 11, 2011, representing 0.5% of the injected CO2. Consequently, 99.5%

  19. Effects of elevated CH4 and CO2 on the mobility of metals in near-surface sediments Hingst, M. 1

    E-Print Network [OSTI]

    Texas at Austin, University of

    , and injecting it into deep, geologic reservoirs for enhanced hydrocarbon recovery and storage. One concern pathways such as fractures and/or improperly plugged and abandoned wells. We hypothesize that CO2 migration the surface and oxidizes to CO2 (34%) in the vadose zone near a plugged and abandoned well. Four sediment

  20. Using CO2 & Algae to Treat Wastewater and

    E-Print Network [OSTI]

    Keller, Arturo A.

    Using CO2 & Algae to Treat Wastewater and Produce Biofuel Feedstock Tryg Lundquist Cal Poly State of the Industry and Growth · Algae's Role in WW Treatment · CO2's New Role · Research at Cal Poly · Future Work/MG 0.3 MGD average flow per facility #12;Reclaimed Algae Bacteria O2 CO2 N Organics N P CO2 P CO2 Waste

  1. SUBTASK 2.19 – OPERATIONAL FLEXIBILITY OF CO2 TRANSPORT AND STORAGE

    SciTech Connect (OSTI)

    Jensen, Melanie; Schlasner, Steven; Sorensen, James; Hamling, John

    2014-12-31T23:59:59.000Z

    Carbon dioxide (CO2) is produced in large quantities during electricity generation and by industrial processes. These CO2 streams vary in terms of both composition and mass flow rate, sometimes substantially. The impact of a varying CO2 stream on pipeline and storage operation is not fully understood in terms of either operability or infrastructure robustness. This study was performed to summarize basic background from the literature on the topic of operational flexibility of CO2 transport and storage, but the primary focus was on compiling real-world lessons learned about flexible operation of CO2 pipelines and storage from both large-scale field demonstrations and commercial operating experience. Modeling and pilot-scale results of research in this area were included to illustrate some of the questions that exist relative to operation of carbon capture and storage (CCS) projects with variable CO2 streams. It is hoped that this report’s real-world findings provide readers with useful information on the topic of transport and storage of variable CO2 streams. The real-world results were obtained from two sources. The first source consisted of five full-scale, commercial transport–storage projects: Sleipner, Snøhvit, In Salah, Weyburn, and Illinois Basin–Decatur. These scenarios were reviewed to determine the information that is available about CO2 stream variability/intermittency on these demonstration-scale projects. The five projects all experienced mass flow variability or an interruption in flow. In each case, pipeline and/or injection engineers were able to accommodate any issues that arose. Significant variability in composition has not been an issue at these five sites. The second source of real- world results was telephone interviews conducted with experts in CO2 pipeline transport, injection, and storage during which commercial anecdotal information was acquired to augment that found during the literature search of the five full-scale projects. The experts represented a range of disciplines and hailed from North America and Europe. Major findings of the study are that compression and transport of CO2 for enhanced oil recovery (EOR) purposes in the United States has shown that impurities are not likely to cause transport problems if CO2 stream composition standards are maintained and pressures are kept at 10.3 MPa or higher. Cyclic, or otherwise intermittent, CO2 supplies historically have not impacted in-field distribution pipeline networks, wellbore integrity, or reservoir conditions. The U.S. EOR industry has demonstrated that it is possible to adapt to variability and intermittency in CO2 supply through flexible operation of the pipeline and geologic storage facility. This CO2 transport and injection experience represents knowledge that can be applied in future CCS projects. A number of gaps in knowledge were identified that may benefit from future research and development, further enhancing the possibility for widespread application of CCS. This project was funded through the Energy & Environmental Research Center–U.S. Department of Energy Joint Program on Research and Development for Fossil Energy-Related Resources Cooperative Agreement No. DE-FC26-08NT43291. Nonfederal funding was provided by the IEA Greenhouse Gas R&D Programme.

  2. The response of soil CO2 ux to changes in atmospheric CO2, nitrogen supply and plant diversity

    E-Print Network [OSTI]

    Minnesota, University of

    The response of soil CO2 ¯ux to changes in atmospheric CO2, nitrogen supply and plant diversity J O. Paul, MN 55108 USA Abstract We measured soil CO2 ¯ux over 19 sampling periods that spanned two growing three major anthropogenic global changes: atmos- pheric carbon dioxide (CO2) concentration, nitrogen (N

  3. An estimate of monthly global emissions of anthropogenic CO2: Impact on the seasonal cycle of atmospheric CO2

    E-Print Network [OSTI]

    Hoffman, Forrest M.

    An estimate of monthly global emissions of anthropogenic CO2: Impact on the seasonal cycle of anthropogenic CO2 are presented. Approximating the seasonal CO2 emission cycle using a 2-harmonic Fourier series with regions of strong anthropogenic CO2 emissions. Citation: Erickson, D. J., III, R. T. Mills, J. Gregg, T. J

  4. Buildings, Commissioning, Efficiency, Comfort, and CO2

    E-Print Network [OSTI]

    Claridge, D. E.

    2006-01-01T23:59:59.000Z

    comfort, optimize energy use and identify retrofits for existing commercial and institutional buildings and central plant facilities. It includes the entire commissioning process from assessment through implementation and subsequent follow-up as necessary...Buildings, Commissioning, Efficiency, Comfort, and CO2 Asian Pacific Building Commissioning Conference ICEBONovember 8, 2006Shenzhen, ChinaPresented ByDavid E. ClaridgeEnergy Systems LaboratoryTexas A&M University Commissioning New Buildings...

  5. 10-MW Supercritical-CO2 Turbine

    Broader source: Energy.gov [DOE]

    This fact sheet describes a 10-megawatt supercritical carbon dioxide turbine project, awarded under the DOE's 2012 SunShot Concentrating Solar Power R&D award program. The research team, led by NREL, intends to showcase the turbomachinery for a new cycle—the supercritical carbon dioxide (s-CO2) Brayton cycle. The cycle is being optimized and tested at conditions representing dry cooling in desert environments, thereby accurately simulating real-world concentrating solar power system operating conditions.

  6. A Mechanistic Model for CO2 Sequestration in Tiffany Coal Bed Methane Field

    SciTech Connect (OSTI)

    Jenn-Tai Liang; Kevin T. Raterman; Eric P. Robertson

    2003-05-01T23:59:59.000Z

    The objective of this project is to develop mechanistic models specific to CO2 sequestration in BP’s Tiffany coal bed methane (CBM) field. In this study, the original field model was modified to match the field performance of a 5-spot pattern in the northern part of the Tiffany Field where BP plans to perform a micro-pilot test. The modified model consists of one high-permeability fast layer sandwiched between two low-permeability slow layers. In this mechanistic model, the fast layer represents well-cleated and fractured coal from all geological layers while the slow layers represent coal with little or no fracture development from the same geological layers. The model successfully matched the performance of the 5-spot pattern during the enhanced recovery period (N2 injection). However, in order to match nitrogen breakthrough times and nitrogen cut the vertical transmissibility between layers had to be set to zero. During gas injection, nitrogen was allowed to enter all three layers, not just the high-permeability fast layer. However, because the permeabilities of the slow layers were low and there is no communication between the fast and the slow layers, most of the injected nitrogen entered the high-permeability fast layer. This suggests that the future gas injection and CO2 sequestration may be restricted to only one third of the total available pay. For future gas injections, the modified model predicted early CO2 breakthrough with high CO2 cut. This suggests that the actual CO2 sequestration capability of the Tiffany Field might not be as high as originally expected. This is a direct consequence of the reduced available pay in the modified model. The modified model also predicted early inert gas (N2 plus CO2) breakthrough and high inert gas cut during future gas injections. If this is confirmed in the pilot test, the high volume of inert gas produced could overwhelm the reprocessing capability resulting in early termination of the project.

  7. Gulf of Mexico Miocene CO2 Site Characterization Mega Transect

    SciTech Connect (OSTI)

    Meckel, Timothy; Trevino, Ramon

    2014-09-30T23:59:59.000Z

    This project characterized the Miocene-age sub-seafloor stratigraphy in the near-offshore portion of the Gulf of Mexico adjacent to the Texas coast. The large number of industrial sources of carbon dioxide (CO2) in coastal counties and the high density of onshore urbanization and environmentally sensitive areas make this offshore region extremely attractive for long-term storage of carbon dioxide emissions from industrial sources (CCS). The study leverages dense existing geologic data from decades of hydrocarbon exploration in and around the study area to characterize the regional geology for suitability and storage capacity. Primary products of the study include: regional static storage capacity estimates, sequestration “leads” and prospects with associated dynamic capacity estimates, experimental studies of CO2-brine-rock interaction, best practices for site characterization, a large-format ‘Atlas’ of sequestration for the study area, and characterization of potential fluid migration pathways for reducing storage risks utilizing novel high-resolution 3D (HR3D) seismic surveys. In addition, three subcontracted studies address source-to-sink matching optimization, offshore well bore management and environmental aspects. The various geologic data and interpretations are integrated and summarized in a series of cross-sections and maps, which represent a primary resource for any near-term commercial deployment of CCS in the area. The regional study characterized and mapped important geologic features (e.g., Clemente-Tomas fault zone, the regionally extensive Marginulina A and Amphistegina B confining systems, etc.) that provided an important context for regional static capacity estimates and specific sequestration prospects of the study. A static capacity estimate of the majority of the Study area (14,467 mi2) was estimated at 86 metric Gigatonnes. While local capacity estimates are likely to be lower due to reservoir-scale characteristics, the offshore Miocene interval is a storage resource of National interest for providing CO2 storage as an atmospheric emissions abatement strategy. The natural petroleum system was used as an analog to infer seal quality and predict possible migration pathways of fluids in an engineered system of anthropogenic CO2 injection and storage. The regional structural features (e.g., Clemente-Tomas fault zone) that exert primary control on the trapping and distribution of Miocene hydrocarbons are expected to perform similarly for CCS. Industrial?scale CCS will require storage capacity utilizing well?documented Miocene hydrocarbon (dominantly depleted gas) fields and their larger structural closures, as well as barren (unproductive, brine?filled) closures. No assessment was made of potential for CO2 utilization for enhanced oil and gas recovery. The use of 3D numerical fluid flow simulations have been used in the study to greatly assist in characterizing the potential storage capacity of a specific reservoir. Due to the complexity of geologic systems (stratigraphic heterogeneity) and inherent limitations on producing a 3D geologic model, these simulations are typically simplified scenarios that explore the influence of model property variability (sensitivity study). A specific site offshore San Luis Pass (southern Galveston Island) was undertaken successfully, indicating stacked storage potential. Downscaling regional capacity estimates to the local scale (and the inverse) has proven challenging, and remains an outstanding gap in capacity assessments. In order to characterize regional seal performance and identify potential brine and CO2 leakage pathways, results from three high-resolution 3D (HR3D) seismic datasets acquired by the study using novel HR3D (P-Cable) acquisition system showed steady and significant improvements in data quality because of improved acquisition and processing technique. Finely detailed faults and stratigraphy in the shallowest 1000 milliseconds (~800 m) of data allowed for the identification and mapping of unconformable surfaces including what is probably

  8. Uncertainty analyses of CO2 plume expansion subsequent to wellbore CO2 leakage into aquifers

    SciTech Connect (OSTI)

    Hou, Zhangshuan; Bacon, Diana H.; Engel, David W.; Lin, Guang; Fang, Yilin; Ren, Huiying; Fang, Zhufeng

    2014-08-01T23:59:59.000Z

    In this study, we apply an uncertainty quantification (UQ) framework to CO2 sequestration problems. In one scenario, we look at the risk of wellbore leakage of CO2 into a shallow unconfined aquifer in an urban area; in another scenario, we study the effects of reservoir heterogeneity on CO2 migration. We combine various sampling approaches (quasi-Monte Carlo, probabilistic collocation, and adaptive sampling) in order to reduce the number of forward calculations while trying to fully explore the input parameter space and quantify the input uncertainty. The CO2 migration is simulated using the PNNL-developed simulator STOMP-CO2e (the water-salt-CO2 module). For computationally demanding simulations with 3D heterogeneity fields, we combined the framework with a scalable version module, eSTOMP, as the forward modeling simulator. We built response curves and response surfaces of model outputs with respect to input parameters, to look at the individual and combined effects, and identify and rank the significance of the input parameters.

  9. Numerical Modeling Studies of The Dissolution-Diffusion-Convection ProcessDuring CO2 Storage in Saline Aquifers

    SciTech Connect (OSTI)

    Pruess, Karsten; Zhang, Keni

    2008-11-17T23:59:59.000Z

    For purposes of geologic storage, CO2 would be injected into saline formations at supercritical temperature and pressure conditions, and would form a separate phase that is immiscible with the aqueous phase (brine). At typical subsurface temperature and pressure conditions, supercritical CO2 (scCO2) has lower density than the aqueous phase and would experience an upward buoyancy force. Accordingly, the CO2 is expected to accumulate beneath the caprock at the top of the permeable interval, and could escape from the storage formation wherever (sub-)vertical pathways are available, such as fractures or faults through the caprock, or improperly abandoned wells. Over time, an increasing fraction of CO2 may dissolve in the aqueous phase, and eventually some of the aqueous CO2 may react with rock minerals to form poorly soluble carbonates. Dissolution into the aqueous phase and eventual sequestration as carbonates are highly desirable processes as they would increase permanence and security of storage. Dissolution of CO2 will establish phase equilibrium locally between the overlying CO2 plume and the aqueous phase beneath. If the aqueous phase were immobile, CO2 dissolution would be limited by the rate at which molecular diffusion can remove dissolved CO2 from the interface between CO2-rich and aqueous phases. This is a slow process. However, dissolution of CO2 is accompanied by a small increase in the density of the aqueous phase, creating a negative buoyancy force that can give rise to downward convection of CO2-rich brine, which in turn can greatly accelerate CO2 dissolution. This study explores the process of dissolution-diffusion-convection (DDC), using high-resolution numerical simulation. We find that geometric features of convection patterns are very sensitive to small changes in problem specifications, reflecting self-enhancing feedbacks and the chaotic nature of the process. Total CO2 dissolution rates on the other hand are found to be quite robust against modest changes in problem parameters, and are essentially constant as long as no dissolved CO2 reaches the lower boundary of the system.

  10. Final Progress Report: Direct Experiments on the Ocean Disposal of Fossil Fuel CO2.

    SciTech Connect (OSTI)

    James P. Barry; Peter G. Brewer

    2004-05-25T23:59:59.000Z

    OAK-B135 This report summarizes activities and results of investigations of the potential environmental consequences of direct injection of carbon dioxide into the deep-sea as a carbon sequestration method. Results of field experiments using small scale in situ releases of liquid CO2 are described in detail. The major conclusions of these experiments are that mortality rates of deep sea biota will vary depending on the concentrations of CO2 in deep ocean waters that result from a carbon sequestration project. Large changes in seawater acidity and carbon dioxide content near CO2 release sites will likely cause significant harm to deep-sea marine life. Smaller changes in seawater chemistry at greater distances from release sites will be less harmful, but may result in significant ecosystem changes.

  11. Conversion of CO2 into Commercial Materials Using Carbon Feedstocks

    SciTech Connect (OSTI)

    Shen, Jian-Ping; Peters, Jonathan; Lail, Marty; Mobley, Paul; Turk, Brian

    2014-05-31T23:59:59.000Z

    In this project, our research focused on developing reaction chemistry that would support using carbon as a reductant for CO2 utilization that would permit CO2 consumption on a scale that would match or exceed anthropomorphic CO2 generation for energy production from fossil fuels. Armed with the knowledge that reactions attempting to produce compounds with an energy content greater than CO2 would be thermodynamically challenged and/or require significant amounts of energy, we developed a potential process that utilized a solid carbon source and recycled the carbon to effectively provide infinite time for the carbon to react. During testing of different carbon sources, we found a wide range of reaction rates. Biomass-derived samples had the most reactivity and coals and petcoke had the lowest. Because we had anticipated this challenge, we recognized that a catalyst would be necessary to improve reaction rates and conversion. From the data analysis of carbon samples, we recognized that alkali metals improved the reaction rate. Through parametric testing of catalyst formulations we were able to increase the reaction rate with petcoke by a factor of >70. Our efforts to identify the reaction mechanism to assist in improving the catalyst formulation demonstrated that the catalyst was catalyzing the extraction of oxygen from CO2 and using this extracted oxygen to oxidize carbon. This was a significant discovery in that if we could modify the catalyst formulation to permit controlled the oxidation, we would have a very power selective oxidation process. With selective oxidation, CO2 utilization could be effective used as one of the process steps in making many of the large volume commodity chemicals that support our modern lifestyles. The key challenges for incorporating these functionalities into the catalyst formulation were to make the oxidation selective and lower the temperature required for catalytic activity. We identified four catalyst families that had the potential to meet these challenges. Initial screening of the catalyst families did show that the reduction/oxidation activity did occur at lower temperatures and that these catalysts were able to cause carbon chain growth as well as C—C cleavage. A preliminary techno-economic feasibility of using petcoke/catalyst to produce a CO-rich syngas product was completed and showed significant economic promise. Testing of the different catalyst families demonstrated that Catalyst A was able to stably produce 5 sccm of ethylene/gram of catalyst at 900°C for one hour. For dry methane reforming, our Catalyst 4 was able to achieve production rates of > 10 sccm of CO and > 3 sccm of H2 per gram of catalyst at 600°C and 350 psig. Based on these developments, the potential for CO2 utilization in the production of large volume commodity chemicals is very promising.

  12. Developing a Comprehensive Risk Assessment Framework for Geological Storage CO2

    SciTech Connect (OSTI)

    Duncan, Ian

    2014-08-31T23:59:59.000Z

    The operational risks for CCS projects include: risks of capturing, compressing, transporting and injecting CO?; risks of well blowouts; risk that CO? will leak into shallow aquifers and contaminate potable water; and risk that sequestered CO? will leak into the atmosphere. This report examines these risks by using information on the risks associated with analogue activities such as CO2 based enhanced oil recovery (CO2-EOR), natural gas storage and acid gas disposal. We have developed a new analysis of pipeline risk based on Bayesian statistical analysis. Bayesian theory probabilities may describe states of partial knowledge, even perhaps those related to non-repeatable events. The Bayesian approach enables both utilizing existing data and at the same time having the capability to adsorb new information thus to lower uncertainty in our understanding of complex systems. Incident rates for both natural gas and CO2 pipelines have been widely used in papers and reports on risk of CO2 pipelines as proxies for the individual risk created by such pipelines. Published risk studies of CO2 pipelines suggest that the individual risk associated with CO2 pipelines is between 10-3 and 10-4, which reflects risk levels approaching those of mountain climbing, which many would find unacceptably high. This report concludes, based on a careful analysis of natural gas pipeline failures, suggests that the individual risk of CO2 pipelines is likely in the range of 10-6 to 10-7, a risk range considered in the acceptable to negligible range in most countries. If, as is commonly thought, pipelines represent the highest risk component of CCS outside of the capture plant, then this conclusion suggests that most (if not all) previous quantitative- risk assessments of components of CCS may be orders of magnitude to high. The potential lethality of unexpected CO2 releases from pipelines or wells are arguably the highest risk aspects of CO2 enhanced oil recovery (CO2-EOR), carbon capture, and storage (CCS). Assertions in the CCS literature, that CO2 levels of 10% for ten minutes, or 20 to 30% for a few minutes are lethal to humans, are not supported by the available evidence. The results of published experiments with animals exposed to CO2, from mice to monkeys, at both normal and depleted oxygen levels, suggest that lethal levels of CO2 toxicity are in the range 50 to 60%. These experiments demonstrate that CO2 does not kill by asphyxia, but rather is toxic at high concentrations. It is concluded that quantitative risk assessments of CCS have overestimated the risk of fatalities by using values of lethality a factor two to six lower than the values estimated in this paper. In many dispersion models of CO2 releases from pipelines, no fatalities would be predicted if appropriate levels of lethality for CO2 had been used in the analysis.

  13. A Review of Hazardous Chemical Species Associated with CO2 Capture from Coal-Fired Power Plants and Their Potential Fate in CO2 Geologic Storage

    E-Print Network [OSTI]

    Apps, J.A.

    2006-01-01T23:59:59.000Z

    Units Current Plant MEA CO 2 Recovery O 2 fired, Direct CO 2 Compression` MEA/MDEA CO 2 Recovery Steam

  14. PLAINS CO2 REDUCTION (PCOR) PARTNERSHIP

    SciTech Connect (OSTI)

    Edward N. Steadman; Daniel J. Daly; Lynette L. de Silva; John A. Harju; Melanie D. Jensen; Erin M. O'Leary; Wesley D. Peck; Steven A. Smith; James A. Sorensen

    2006-01-01T23:59:59.000Z

    During the period of October 1, 2003, through September 30, 2005, the Plains CO2 Reduction (PCOR) Partnership, identified geologic and terrestrial candidates for near-term practical and environmentally sound carbon dioxide (CO2) sequestration demonstrations in the heartland of North America. The PCOR Partnership region covered nine states and three Canadian provinces. The validation test candidates were further vetted to ensure that they represented projects with (1) commercial potential and (2) a mix that would support future projects both dependent and independent of CO2 monetization. This report uses the findings contained in the PCOR Partnership's two dozen topical reports and half-dozen fact sheets as well as the capabilities of its geographic information system-based Decision Support System to provide a concise picture of the sequestration potential for both terrestrial and geologic sequestration in the PCOR Partnership region based on assessments of sources, sinks, regulations, deployment issues, transportation, and capture and separation. The report also includes concise action plans for deployment and public education and outreach as well as a brief overview of the structure, development, and capabilities of the PCOR Partnership. The PCOR Partnership is one of seven regional partnerships under Phase I of the U.S. Department of Energy National Energy Technology Laboratory's Regional Carbon Sequestration Partnership program. The PCOR Partnership, comprising 49 public and private sector members, is led by the Energy & Environmental Research Center at the University of North Dakota. The international PCOR Partnership region includes the Canadian provinces of Alberta, Saskatchewan, and Manitoba and the states of Montana (part), Wyoming (part), North Dakota, South Dakota, Nebraska, Missouri, Iowa, Minnesota, and Wisconsin.

  15. co2-transport | netl.doe.gov

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative1 First Use of Energy for All Purposes (Fuel and Nonfuel), 2002; Level:Energy: Grid Integration Redefining What'sis Taking Over OurThe Iron4 Self-Scrubbing:,, , ., ..., ,+ . :,2013 NETL CO2 CaptureTransport Cost

  16. Insights into Silicate Carbonation Processes in Water-Bearing Supercritical CO2 Fluids

    SciTech Connect (OSTI)

    Miller, Quin RS; Thompson, Christopher J.; Loring, John S.; Windisch, Charles F.; Bowden, Mark E.; Hoyt, David W.; Hu, Jian Z.; Arey, Bruce W.; Rosso, Kevin M.; Schaef, Herbert T.

    2013-07-01T23:59:59.000Z

    Long-term geologic storage of carbon dioxide (CO2) is considered an integral part to moderating CO2 concentrations in the atmosphere and subsequently minimizing effects of global climate change. Although subsurface injection of CO2 is common place in certain industries, deployment at the scale required for emission reduction is unprecedented and therefore requires a high degree of predictability. Accurately modeling geochemical processes in the subsurface requires experimental derived data for mineral reactions occurring between the CO2, water, and rocks. Most work in this area has focused on aqueous-dominated systems in which dissolved CO2 reacts to form crystalline carbonate minerals. Comparatively little laboratory research has been conducted on reactions occurring between minerals in the host rock and the wet supercritical fluid phase. In this work, we studied the carbonation of wollastonite [CaSiO3] exposed to variably hydrated supercritical CO2 (scCO2) at a range of temperatures (50, 55 and 70 °C) and pressures (90,120 and 160 bar) that simulate conditions in geologic repositories. Mineral transformation reactions were followed by three novel in situ high pressure techniques, including x-ray diffraction that tracked the rate and extents of wollastonite conversion to calcite. Increased dissolved water concentrations in the supercritical CO2 resulted in increased silicate carbonation approaching ~50 wt. %. Development of thin water films on the mineral surface were directly observed with infrared spectroscopy and determined to be critical for facilitating carbonation processes. Even in extreme low water conditions, magic angle spinning nuclear magnetic resonance detected formation of Q3 [Si(OSi)3OH] and Q4 [Si(OSi)4] amorphous silica species. Unlike the thick (<10 ?m) passivating silica layers observed in the fully water saturated scCO2 experiments, images obtained from a focused ion beam sectioned sample indicted these coatings were chemically wollastonite but structurally amorphous. In addition, evidence of an intermediate hydrated amorphous calcium carbonate forming under these conditions further emphasize the importance of understanding geochemical processes occurring in water bearing scCO2 fluids.

  17. INFLUENCE OF CAPILLARY PRESSURE ON CO2 STORAGE AND MONITORING

    E-Print Network [OSTI]

    Santos, Juan

    volume - 1 + + = + - 1 + = : 2 solubility in brine : 2 formation volume factor : brine formation volume factor The Black-Oil formulation = - - = - - Darcy's Empirical Law + = 1 - = : capillary pressure brine brine CO2 CO2 #12;· The numerical solution was obtained

  18. atmospheric co2 face: Topics by E-print Network

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    the Duke Forest free-air CO2 enrichment (FACE) study. Rates of An Katul, Gabriel 11 Soil carbon sequestration in a pine forest after 9 years of atmospheric CO2 enrichment...

  19. air co2 enrichment: Topics by E-print Network

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    with increasing CO2 between ambient (1.0x California at Santa Cruz, University of 13 Soil carbon sequestration in a pine forest after 9 years of atmospheric CO2 enrichment...

  20. Formation Damage due to CO2 Sequestration in Saline Aquifers

    E-Print Network [OSTI]

    Mohamed, Ibrahim Mohamed 1984-

    2012-10-25T23:59:59.000Z

    Carbon dioxide (CO2) sequestration is defined as the removal of gas that would be emitted into the atmosphere and its subsequent storage in a safe, sound place. CO2 sequestration in underground formations is currently being considered to reduce...

  1. Quantum Chemistry of CO2 Interaction with Swelling Clays | netl...

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    of carbon dioxide (CO2). The minerals may affect the reservoir storage capacity as well as the integrity of its natural seals such as caprock formations. CO2 interaction...

  2. From CO2 to Methanol via Novel Nanocatalysts

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    From CO2 to Methanol via Novel Nanocatalysts From CO2 to Methanol via Novel Nanocatalysts Print Wednesday, 03 December 2014 00:00 Researchers have found novel nanocatalysts that...

  3. Enhanced Geothermal Systems (EGS) with CO2 as Heat Transmission...

    Open Energy Info (EERE)

    problems of aqueous fluids, make heretofore inaccessible energy resources available for human use, and provide ancillary benefits by using and storing CO2. A CO2-based EGS is...

  4. Summary Report on CO2 Geologic Sequestration & Water Resources Workshop

    E-Print Network [OSTI]

    Varadharajan, C.

    2013-01-01T23:59:59.000Z

    projects based CO 2 enhanced oil recovery in the US. Energydeveloped for CO 2 -enhanced oil recovery. In: 16th SPE/DOEpurposes such as enhanced oil recovery (EOR) and enhanced

  5. CO2 Capture by Absorption with Potassium Carbonate

    E-Print Network [OSTI]

    Rochelle, Gary T.

    CO2 Capture by Absorption with Potassium Carbonate First Quarterly Report 2007 Quarterly Progress of this work is to improve the process for CO2 capture by alkanolamine absorption/stripping by developing

  6. CO2 Capture by Absorption with Potassium Carbonate

    E-Print Network [OSTI]

    Rochelle, Gary T.

    CO2 Capture by Absorption with Potassium Carbonate Fourth Quarterly Report 2006 Quarterly Progress of this work is to improve the process for CO2 capture by alkanolamine absorption/stripping by developing

  7. Formation Damage due to CO2 Sequestration in Saline Aquifers 

    E-Print Network [OSTI]

    Mohamed, Ibrahim Mohamed 1984-

    2012-10-25T23:59:59.000Z

    the amount of CO2 emitted into the atmosphere. However, a better understanding of the chemical and physical interactions between CO2, water, and formation rock is necessary before sequestration. These interactions can be evaluated by the change in mineral...

  8. International Symposium on Site Characterization for CO2 Geological Storage

    E-Print Network [OSTI]

    Tsang, Chin-Fu

    2006-01-01T23:59:59.000Z

    WITH HETEROGENEITY IN OIL AND GAS RESERVOIRS APPLIED TO CO 2sedimentary basins, oil and gas fields, and industrial CO 2Harr, C.L. , 1996, Paradox oil and gas potential of the Ute

  9. CO2 capture processes in power plants - Le captage du CO2 dans les centrales thermiques

    E-Print Network [OSTI]

    Chakib Bouallou

    2010-08-12T23:59:59.000Z

    This review is devoted to assess and compare various processes aiming at recover CO2 from power plants fed with natural gas (NGCC) and pulverized coal (PC). These processes are post combustion CO2 capture using chemical solvents, natural gas reforming for pre-combustion capture and oxy-fuel combustion with cryogenic recovery of CO2. These processes were evaluated to give some clues for choosing the best option for each type of power plant. The comparison of these various concepts suggests that, in the short and medium term, chemical absorption is the most interesting process for NGCC power plants. For CP power plants, oxy-combustion can be a very interesting option, as well as post-combustion capture by chemical solvents.

  10. Assessment of Energy Efficiency Improvement and CO2 Emission Reduction Potentials in India's Cement Industry

    E-Print Network [OSTI]

    Morrow III, William R.

    2014-01-01T23:59:59.000Z

    Model Inputs Emissions Factors CO2 Emission factor for grid tonne CO2/MWh)  CO2 Emission factor for fuel  (tonne CO2/TJ)Improvements and CO2 Emission Reduction Potentials in the

  11. electroseismic monitoring of co2 sequestration: a finite element ...

    E-Print Network [OSTI]

    Fabio Zyserman

    Keywords: Electroseismic Modeling, Poroelasticity, CO2 sequestration, Finite element methods. 2000 AMS ... carbon dioxide emissisons into the atmosphere.

  12. CO2 stabilization, climate change and the terrestrial carbon sink

    E-Print Network [OSTI]

    White, Andrew

    CO2 stabilization, climate change and the terrestrial carbon sink A N D R E W W H I T E , * M E L V, Hybrid v4.1, with a subdaily timestep, was driven by increasing CO2 and transient climate output from scenarios were used: (i) IS92a, giving 790 ppm CO2 by 2100, (ii) CO2 stabilization at 750 ppm by 2225

  13. Summary Report on CO2 Geologic Sequestration & Water Resources Workshop

    E-Print Network [OSTI]

    Varadharajan, C.

    2013-01-01T23:59:59.000Z

    potential CO 2 storage and water extraction projects based on the effort’s findings DOE’s Interagency CCS

  14. Gravity monitoring of CO2 movement during sequestration: Model studies

    E-Print Network [OSTI]

    Gasperikova, E.

    2008-01-01T23:59:59.000Z

    combined CO 2 enhanced oil recovery (EOR) and sequestrationMODEL The enhanced oil recovery (EOR)/sequestration

  15. Monitoring CO 2 sequestration into deep saline aquifer and associated salt intrusion using coupled multiphase flow modeling and time lapse electrical resistivity tomography

    SciTech Connect (OSTI)

    Chuan Lu; CHI Zhang; Hai Hanag; Timothy C. Johnson

    2014-04-01T23:59:59.000Z

    Successful geological storage and sequestration of carbon dioxide (CO2) require efficient monitoring of the migration of CO2 plume during and after large-scale injection in order to verify the containment of the injected CO2 within the target formation and to evaluate potential leakage risk. Field studies have shown that surface and cross-borehole electrical resistivity tomography (ERT) can be a useful tool in imaging and characterizing solute transport in heterogeneous subsurface. In this synthetic study, we have coupled a 3-D multiphase flow model with a parallel 3-D time-lapse ERT inversion code to explore the feasibility of using time-lapse ERT for simultaneously monitoring the migration of CO2 plume in deep saline formation and potential brine intrusion into shallow fresh water aquifer. Direct comparisons of the inverted CO2 plumes resulting from ERT with multiphase flow simulation results indicate the ERT could be used to delineate the migration of CO2 plume. Detailed comparisons on the locations, sizes and shapes of CO2 plume and intruded brine plumes suggest that ERT inversion tends to underestimate the area review of the CO2 plume, but overestimate the thickness and total volume of the CO2 plume. The total volume of intruded brine plumes is overestimated as well. However, all discrepancies remain within reasonable ranges. Our study suggests that time-lapse ERT is a useful monitoring tool in characterizing the movement of injected CO2 into deep saline aquifer and detecting potential brine intrusion under large-scale field injection conditions.

  16. A Numerical Investigation of Wettability Alteration during Immiscible CO2

    E-Print Network [OSTI]

    Hossain, M. Enamul

    A Numerical Investigation of Wettability Alteration during Immiscible CO2 Flooding Process, April 2012 #12;2 Table of Contest Abstract 3 Introduction 3 Literature Review 5 CO2 Flooding 7 New alteration during CO2 flooding. However, limited research on numerical and/or analytical modeling

  17. Original article Interactive effects of elevated CO2, O3,

    E-Print Network [OSTI]

    Paris-Sud XI, Université de

    Original article Interactive effects of elevated CO2, O3, and soil water deficit on spring wheat of elevated carbon dioxide (CO2), ozone (O3), and soil water deficit on spring wheat (Triticum aestivum L. cv consisting of two O3levels (ambient and 1.5-times ambient) in combination with two CO2levels (ambient

  18. Cimpor inventa nova frmula para reduzir pegada de CO2

    E-Print Network [OSTI]

    Instituto de Sistemas e Robotica

    Cimpor inventa nova fórmula para reduzir pegada de CO2 CIMENTO. A Cimpor descobriu uma nova fórmula para produzir ci- mento que lhe permitirá reduzir a pegada de CO 2 em 25%. Segundo as contas da as fábricas do grupo, seriam emitidos menos quatro milhões de toneladas de CO 2 por ano, o que permitiria uma

  19. results and benefits... Birmingham Cutting your CO2

    E-Print Network [OSTI]

    Everest, Graham R

    results and benefits... Birmingham Cutting your CO2 Birmingham City Council July 2007 c a s e s t u of the BirminghamCutting CO2 campaign, news items, display materials etc. · Advising on pledge gathering materials system was launched in July 2007 as part of the `Birmingham Cutting Your CO2' campaign. By the end

  20. Aquatic primary production in a high-CO2 world

    E-Print Network [OSTI]

    Fussman, Gregor

    Aquatic primary production in a high-CO2 world Etienne Low-De´carie, Gregor F. Fussmann, and Graham-Penfield, Montreal, QC, H3A 1B1, Canada Here, we provide a review of the direct effect of increas- ing CO2 on aquatic: the assessment of theories about limitation of productivity and the integration of CO2 into the co

  1. CO2 Emissions Mitigation and Technological Advance: An

    E-Print Network [OSTI]

    PNNL-18075 CO2 Emissions Mitigation and Technological Advance: An Updated Analysis of Advanced/2003) #12;PNNL-18075 CO2 Emissions Mitigation and Technological Advance: An Analysis of Advanced Technology of atmospheric CO2 concentrations at 450 parts per million by volume (ppmv) and 550 ppmv in MiniCAM. Each

  2. CO2-avskiljning med syrgasfrbrnning -nya tekniska mjligheter

    E-Print Network [OSTI]

    Lemurell, Stefan

    CO2-avskiljning med syrgasförbränning - nya tekniska möjligheter Klas Andersson Avd. Energiteknik Chalmers Tekniska Högskola Chalmers Energikonferens 14 december 2012 #12;· Combustion and CO2 capture with power and industrial sectors #12;Air-Fuel Combustion Air Fuel Flue gas CO2: 10-20 % N2: 60

  3. Central serotonin neurons are required for arousal to CO2

    E-Print Network [OSTI]

    Central serotonin neurons are required for arousal to CO2 Gordon F. Buchanana,b,1 and George B neurons are stimulated by CO2, and sero- tonin activates thalamocortical networks, we hypothesized any arousal response to inhalation of 10% CO2 (with 21% O2 in balance N2) but had normal arousal

  4. Center for By-Products Utilization CO2 SEQUESTRATION

    E-Print Network [OSTI]

    Saldin, Dilano

    climate change, reduced GHGs, improved air quality, CO2 reduction & sequestration, and carbon offsets. #12 for the development of a technology for the carbon dioxide (CO2) sequestration in non-air entrained concreteCenter for By-Products Utilization CO2 SEQUESTRATION IN NON-AIR ENTRAINED CONCRETE By Tarun R. Naik

  5. Acid Gas Capture Using CO2-Binding Organic Liquids

    SciTech Connect (OSTI)

    Heldebrant, David J.; Koech, Phillip K.; Rainbolt, James E.; Zheng, Feng

    2010-11-10T23:59:59.000Z

    Current chemical CO2 scrubbing technology is primarily aqueous alkanolamine based. These systems rapidly bind CO2 (forming water-soluble carbamate and bicarbonate salts) however, the process has serious disadvantages. The concentration of monoethanolamine rarely exceeds 30 wt % due to the corrosive nature of the solution, and this reduces the maximum CO2 volumetric (?108 g/L) and gravimetric capacity (?7 wt%) of the CO2 scrubber. The ?30 wt % loading of ethanolamine also means that a large excess of water must be pumped and heated during CO2 capture and release, and this greatly increases the energy requirements especially considering the high specific heat of water (4 j/g-1K-1). Our approach is to switch to organic systems that chemically bind CO2 as liquid alkylcarbonate salts. Our CO2-binding organic liquids have higher CO2 solubility, lower specific heats, potential for less corrosion and lower binding energies for CO2 than aqueous systems. CO2BOLs also reversibly bind and release mixed sulfur oxides. Furthermore the CO2BOL system can be direct solvent replacements for any solvent based CO2 capture systems because they are commercially available reagents and because they are fluids they would not require extensive process re-engineering.

  6. Chemical Looping Combustion for inherent CO2 capture in a

    E-Print Network [OSTI]

    Evaluate CLC using syngas as fuel Effect of fuel Effect of operating conditions Use CLC for CO2-capture Reactor System O2,N2 CO2,H2O To CO2 recovery and compression #12;15 Clean syngas from different gasifiers

  7. CO2 Capture by Absorption with Potassium Carbonate

    E-Print Network [OSTI]

    Rochelle, Gary T.

    CO2 Capture by Absorption with Potassium Carbonate First Quarterly Report 2006 Quarterly Progress the process for CO2 capture by alkanolamine absorption/stripping by developing an alternative solvent, aqueous.................................................................................................................................... 8 Task 1 ­ Modeling Performance of Absorption/Stripping of CO2 with Aqueous K2CO3 Promoted

  8. CO2 Capture by Absorption with Potassium Carbonate

    E-Print Network [OSTI]

    Rochelle, Gary T.

    CO2 Capture by Absorption with Potassium Carbonate Third Quarterly Report 2006 Quarterly Progress of this work is to improve the process for CO2 capture by alkanolamine absorption/stripping by developing...................................................................................................................................11 Task 1 ­ Modeling Performance of Absorption/Stripping of CO2 with Aqueous K2CO3 Promoted

  9. CO2 Capture by Absorption with Potassium Carbonate

    E-Print Network [OSTI]

    Rochelle, Gary T.

    CO2 Capture by Absorption with Potassium Carbonate Second Quarterly Report 2006 Quarterly Progress of this work is to improve the process for CO2 capture by alkanolamine absorption/stripping by developing.................................................................................................................................. 10 Task 1 ­ Modeling Performance of Absorption/Stripping of CO2 with Aqueous K2CO3 Promoted

  10. Study of CO2 Mobility Control Using Cross-linked Gel Conformance Control and CO2 Viscosifiers in Heterogeneous Media

    E-Print Network [OSTI]

    Cai, Shuzong

    2011-10-21T23:59:59.000Z

    CO2 has been widely used as a displacement fluid in both immiscible and miscible displacement processes to obtain tertiary recovery from the field. There are several problems associated with the application of CO2 flooding, especially when...

  11. Directed Technical Change and the Adoption of CO2 Abatement Technology: The Case of CO2 Capture and Storage

    E-Print Network [OSTI]

    Otto, Vincent M.

    This paper studies the cost effectiveness of combining traditional environmental policy, such as CO2 trading schemes, and technology policy that has aims of reducing the cost and speeding the adoption of CO2 abatement ...

  12. Research Project on CO2 Geological Storage and Groundwater Resources: Water Quality Effects Caused by CO2 Intrusion into Shallow Groundwater

    E-Print Network [OSTI]

    Birkholzer, Jens

    2008-01-01T23:59:59.000Z

    Changes in Response to CO2 Leakage from Deep Geologicalstudy mineral trapping for CO2 disposal in deep arenaceousconstituents as function of P(CO2)? function of P(CO2)? – –

  13. Visualizing the Surface Infrastructure Used to Move 2 MtCO2/year from the Dakota Gasification Company to the Weyburn CO2 Enhanced Oil Recovery Project: Version of July 1, 2009

    SciTech Connect (OSTI)

    Dooley, James J.

    2009-07-09T23:59:59.000Z

    Google Earth Pro has been employed to create an interactive flyover of the world’s largest operational carbon dioxide capture and storage project. The visualization focuses on the transport and storage of 2 MtCO2/year which is captured from the Dakota Gasification Facility (Beula, North Dakota) and transported 205 miles and injected into the Weyburn oil field in Southeastern Saskatchewan.

  14. INTEGRATING MEA REGENERATION WITH CO2 COMPRESSION AND PEAKING TO REDUCE CO2 CAPTURE COSTS

    E-Print Network [OSTI]

    Rochelle, Gary T.

    system with no compression heat recovery, CO2 vapor recompression heat recovery, and multipressure stripping with and without vapor recompression heat recovery. These configurations were simulated using of power for sale to the grid based on 500 MW unit ) clearly outweighed the modest increases in capital

  15. Rate Determination of the CO2* Chemiluminescence Reaction CO + O + M = CO2* + M

    E-Print Network [OSTI]

    Kopp, Madeleine Marissa, 1987-

    2012-10-15T23:59:59.000Z

    flame characteristics, such as fuel consumption rate, heat release rate, and H-atom concentration. In 2002, Kim et al. [2] made detailed spectral measurements in SI, HCCI, and SCCI engines from various excited state species and determined that CO2...

  16. Predicting CO2-water interfacial tension under pressure and temperature conditions of geologic CO2 storage

    E-Print Network [OSTI]

    Nielsen, L.C.

    2013-01-01T23:59:59.000Z

    within ± 15% of nominal P. EPM2-SPC/E DZ- SPC/E PPL-SPC/EEPM2- TIP4P2005 PPL- TIP4P2005 Predicted (f) a P ? CO2 2SE ?to C and O atoms (Table 1). The PPL model (In Het Panhuis et

  17. CINETIQUES DE SORPTION DU CO2 DANS LE CADRE DU STOCKAGE GEOLOGIQUE DU CO2 DANS LE CHARBON

    E-Print Network [OSTI]

    Boyer, Edmond

    PROCESSES OF CO2 SORPTION FOR CO2 STORAGE IN COAL SEAMS Delphine CHARRIERE1, 2 , Zbigniew POKRYSZKA1 storage in coal seams and the enhancement on coalbed methane production requires information on the gas sorption mechanism of kinetics. In this work, both sorption kinetics of CO2 and CH4 are studied onto a coal

  18. Modeling and Evaluation of Geophysical Methods for Monitoring and Tracking CO2 Migration

    SciTech Connect (OSTI)

    Daniels, Jeff

    2012-11-30T23:59:59.000Z

    Geological sequestration has been proposed as a viable option for mitigating the vast amount of CO{sub 2} being released into the atmosphere daily. Test sites for CO{sub 2} injection have been appearing across the world to ascertain the feasibility of capturing and sequestering carbon dioxide. A major concern with full scale implementation is monitoring and verifying the permanence of injected CO{sub 2}. Geophysical methods, an exploration industry standard, are non-invasive imaging techniques that can be implemented to address that concern. Geophysical methods, seismic and electromagnetic, play a crucial role in monitoring the subsurface pre- and post-injection. Seismic techniques have been the most popular but electromagnetic methods are gaining interest. The primary goal of this project was to develop a new geophysical tool, a software program called GphyzCO2, to investigate the implementation of geophysical monitoring for detecting injected CO{sub 2} at test sites. The GphyzCO2 software consists of interconnected programs that encompass well logging, seismic, and electromagnetic methods. The software enables users to design and execute 3D surface-to-surface (conventional surface seismic) and borehole-to-borehole (cross-hole seismic and electromagnetic methods) numerical modeling surveys. The generalized flow of the program begins with building a complex 3D subsurface geological model, assigning properties to the models that mimic a potential CO{sub 2} injection site, numerically forward model a geophysical survey, and analyze the results. A test site located in Warren County, Ohio was selected as the test site for the full implementation of GphyzCO2. Specific interest was placed on a potential reservoir target, the Mount Simon Sandstone, and cap rock, the Eau Claire Formation. Analysis of the test site included well log data, physical property measurements (porosity), core sample resistivity measurements, calculating electrical permittivity values, seismic data collection, and seismic interpretation. The data was input into GphyzCO2 to demonstrate a full implementation of the software capabilities. Part of the implementation investigated the limits of using geophysical methods to monitor CO{sub 2} injection sites. The results show that cross-hole EM numerical surveys are limited to under 100 meter borehole separation. Those results were utilized in executing numerical EM surveys that contain hypothetical CO{sub 2} injections. The outcome of the forward modeling shows that EM methods can detect the presence of CO{sub 2}.

  19. Evaluating impacts of CO2 gas intrusion into a confined sandstone aquifer: Experimental results

    SciTech Connect (OSTI)

    Qafoku, Nikolla; Lawter, Amanda R.; Shao, Hongbo; Wang, Guohui; Brown, Christopher F.

    2014-12-31T23:59:59.000Z

    Deep subsurface storage and sequestration of CO2 has been identified as a potential mitigation technique for rising atmospheric CO2 concentrations. Sequestered CO2 represents a potential risk to overlying aquifers if the CO2 leaks from the deep storage reservoir. Experimental and modeling work is required to evaluate potential risks to groundwater quality and develop a systematic understanding of how CO2 leakage may cause important changes in aquifer chemistry and mineralogy by promoting dissolution/precipitation, adsorption/desorption, and redox reactions. Sediments from the High Plains aquifer in Kansas, United States, were used in this investigation, which is part of the National Risk Assessment Partnership Program sponsored by the US Department of Energy. This aquifer was selected to be representative of consolidated sand and gravel/sandstone aquifers overlying potential CO2 sequestration repositories within the continental US. In this paper, we present results from batch experiments conducted at room temperature and atmospheric pressure with four High Plains aquifer sediments. Batch experiments simulate sudden, fast, and short-lived releases of the CO2 gas as would occur in the case of well failure during injection. Time-dependent release of major, minor, and trace elements were determined by analyzing the contacting solutions. Characterization studies demonstrated that the High Plains aquifer sediments were abundant in quartz and feldspars, and contained about 15 to 20 wt% montmorillonite and up to 5 wt% micas. Some of the High Plains aquifer sediments contained no calcite, while others had up to about 7 wt% calcite. The strong acid extraction tests confirmed that in addition to the usual elements present in most soils, rocks, and sediments, the High Plains aquifer sediments had appreciable amounts of As, Cd, Pb, Cu, and occasionally Zn, which potentially may be mobilized from the solid to the aqueous phase during or after exposure to CO2. However, the results from the batch experiments showed that the High Plains sediments mobilized only low concentrations of trace elements (potential contaminants), which were detected occasionally in the aqueous phase during these experiments. Importantly, these occurrences were more frequent in the calcite-free sediment. Results from these investigations provide useful information to support site selection, risk assessment, and public education efforts associated with geological CO2 storage and sequestration.

  20. Characterization and Simulation of ECBM: History Matching of Forecasting CO2 Sequestration in Marshal County, West Virginia.

    E-Print Network [OSTI]

    Mohaghegh, Shahab

    . Bromhal, National Energy Technology Laboratory Copyright 2010, Society of Petroleum Engineers This paper injection. Introduction Sustain economic growth by providing sufficient energy and controlling the CO2 emissions as byproduct of producing Energy from fossil fuels is one of the most challenging tasks

  1. IMPROVING CO2 EFFICIENCY FOR RECOVERING OIL IN HETEROGENEOUS RESERVOIRS

    SciTech Connect (OSTI)

    Reid B. Grigg; Robert K. Svec; Zheng-Wen Zeng; Liu Yi; Baojun Bai

    2003-05-01T23:59:59.000Z

    A three-year contract for the project, DOE Contract No. DE-FG26-01BC15364, ''Improving CO{sub 2} Efficiency for Recovering Oil in Heterogeneous Reservoirs,'' was awarded and started on September 28, 2001. This project examines three major areas in which CO2 flooding can be improved: fluid and matrix interactions, conformance control/sweep efficiency, and reservoir simulation for improved oil recovery. This report discusses the activity during the six-month period covering October 1, 2002 through March 31, 2003 that covers the first and second fiscal quarters of the project's second year. During these two quarters of the project we have been working in several areas: reservoir fluid/rock interactions and their relationships to changing injectivity, and surfactant adsorption on quarried core and pure component granules, foam stability, and high flow rate effects. We also had a very productive project review in Midland, Texas. A paper on CO{sub 2}-brine-reservoir rock interaction was presented and included in the proceedings of the SPE International Symposium on Oilfield Chemistry, Houston, 5-8 February, 2003. Papers have been accepted for the Second Annual Conference on Carbon Sequestration in Alexandria, VA in May, the Society of Core Analysis meeting in Pau, France in September, and two papers for the SPE Annual Meeting in Denver, CO in October.

  2. Sequestration of Dissolved CO2 in the Oriskany Formation

    SciTech Connect (OSTI)

    Dilmore, R.M.; Allen, D.E. (Salem State College, Salem, MA); McCarthy-Jones, J.R.; Hedges, S.W.; Soong, Yee

    2008-04-15T23:59:59.000Z

    Experiments were conducted to determine the solubility of CO2 in a natural brine solution of the Oriskany formation under elevated temperature and pressure conditions. These data were collected at temperatures of 22 and 75 °C and pressures between 100 and 450 bar. Experimentally determined data were compared with CO2 solubility predictions using a model developed by Duan and Sun (Chem. Geol. 2003, 193, 257-271). Model results compare well with Oriskany brine CO2 solubility data collected experimentally, suggesting that the Duan and Sun model is a reliable tool for estimating solution CO2 capacity in high salinity aquifers in the temperature and pressure range evaluated. The capacity for the Oriskany formation to sequester dissolved CO2 was calculated using results of the solubility models, estimation of the density of CO2 saturated brine, and available geographic information system (GIS) information on the formation depth and thickness. Results indicate that the Oriskany formation can hold approximately 0.36 gigatonnes of dissolved CO2 if the full basin is considered. When only the region where supercritical CO2 can exist (temperatures greater than 31° C and pressures greater than 74 bar) is considered, the capacity of the Oriskany formation to sequester dissolved CO2 is 0.31 gigatonnes. The capacity estimate considering the potential to sequester free-phase supercritical CO2 if brine were displaced from formation pore space is 8.8 gigatonnes in the Oriskany formation.

  3. Supersonic Technology for CO2 Capture: A High Efficiency Inertial CO2 Extraction System

    SciTech Connect (OSTI)

    None

    2010-07-01T23:59:59.000Z

    IMPACCT Project: Researchers at ATK and ACENT Laboratories are developing a device that relies on aerospace wind-tunnel technologies to turn CO2 into a condensed solid for collection and capture. ATK’s design incorporates a special nozzle that converges and diverges to expand flue gas, thereby cooling it off and turning the CO2 into solid particles which are removed from the system by a cyclonic separator. This technology is mechanically simple, contains no moving parts and generates no chemical waste, making it inexpensive to construct and operate, readily scalable, and easily integrated into existing facilities. The increase in the cost to coal-fired power plants associated with introduction of this system would be 50% less than current technologies.

  4. Improved Efficiency of Miscible CO2 Floods and Enhanced Prospects for CO2 Flooding Heterogeneous Reservoirs

    SciTech Connect (OSTI)

    Grigg, Reid B.; Schechter, David S.

    1999-10-15T23:59:59.000Z

    The goal of this project is to improve the efficiency of miscible CO2 floods and enhance the prospects for flooding heterogeneous reservoirs. This report provides results of the second year of the three-year project that will be exploring three principles: (1) Fluid and matrix interactions (understanding the problems). (2) Conformance control/sweep efficiency (solving the problems. 3) Reservoir simulation for improved oil recovery (predicting results).

  5. A Parametric Study for Regenerative Ammonia-Based Scrubbing for the Capture of CO2

    SciTech Connect (OSTI)

    Resnik, K.P.; Garber, W.; Hreda, D.C.; Yeh, J.T.; Pennline, H.W.

    2006-09-01T23:59:59.000Z

    A continuous gas and liquid flow, regenerative scrubbing process for CO2 capture is currently being demonstrated at the bench-scale level. An aqueous ammonia-based solution captures CO2 from simulated flue gas in an absorber and releases a nearly pure stream of CO2 in the regenerator. After the regeneration, the solution of ammonium compounds is recycled to the absorber. The design of the continuous flow unit was based on earlier exploratory results from a semi-batch reactor, where a CO2 and N2 gas mixture flowed through a well-mixed batch of ammonia-based solution. Recently, a series of tests have been conducted on the continuous unit to observe the effect of various parameters on CO2 removal efficiency and regenerator effectiveness within the flow system. The parameters that were studied include absorber temperature, regenerator temperature, initial NH3 concentration, simulated flue gas flow rate, liquid solvent inventory in the flow system, and height of the packed-bed absorber. Results from this current testing campaign conducted in the continuous scrubbing unit as well as test results from a 5-cycle semi-batch reactor will be discussed.

  6. Assessment of Energy Efficiency Improvement and CO2 Emission Reduction Potentials in India's Cement Industry

    E-Print Network [OSTI]

    Morrow III, William R.

    2014-01-01T23:59:59.000Z

    Factors CO2 Emission factor for grid electricity  (tonne CO2 Savings Figure 6. 2010-2030 Electricity and Electricity-Base CO 2 Emissions

  7. Estimation of CO2 Emissions from China's Cement Production: Methodologies and Uncertainties

    E-Print Network [OSTI]

    Ke, Jing

    2014-01-01T23:59:59.000Z

    L. , 2006. Discussion of CO2 emission reduction in ChineseFurther discussion of CO2 emission reduction in Chinesecalculation method of CO2 emissions of cement production.

  8. Silurian "Clinton" Sandstone Reservoir Characterization for Evaluation of CO2-EOR Potential in the East Canton Oil Field, Ohio

    SciTech Connect (OSTI)

    Riley, Ronald; Wicks, John; Perry, Christopher

    2009-12-30T23:59:59.000Z

    The purpose of this study was to evaluate the efficacy of using CO2-enhanced oil recovery (EOR) in the East Canton oil field (ECOF). Discovered in 1947, the ECOF in northeastern Ohio has produced approximately 95 million barrels (MMbbl) of oil from the Silurian “Clinton” sandstone. The original oil-in-place (OOIP) for this field was approximately 1.5 billion bbl and this study estimates by modeling known reservoir parameters, that between 76 and 279 MMbbl of additional oil could be produced through secondary recovery in this field, depending on the fluid and formation response to CO2 injection. A CO2 cyclic test (“Huff-n-Puff”) was conducted on a well in Stark County to test the injectivity in a “Clinton”-producing oil well in the ECOF and estimate the dispersion or potential breakthrough of the CO2 to surrounding wells. Eighty-one tons of CO2 (1.39 MMCF) were injected over a 20-hour period, after which the well was shut in for a 32-day “soak” period before production was resumed. Results demonstrated injection rates of 1.67 MMCF of gas per day, which was much higher than anticipated and no CO2 was detected in gas samples taken from eight immediately offsetting observation wells. All data collected during this test was analyzed, interpreted, and incorporated into the reservoir characterization study and used to develop the geologic model. The geologic model was used as input into a reservoir simulation performed by Fekete Associates, Inc., to estimate the behavior of reservoir fluids when large quantities of CO2 are injected into the “Clinton” sandstone. Results strongly suggest that the majority of the injected CO2 entered the matrix porosity of the reservoir pay zones, where it diffused into the oil. Evidence includes: (A) the volume of injected CO2 greatly exceeded the estimated capacity of the hydraulic fracture and natural fractures; (B) there was a gradual injection and pressure rate build-up during the test; (C) there was a subsequent, gradual flashout of the CO2 within the reservoir during the ensuing monitored production period; and (D) a large amount of CO2 continually off-gassed from wellhead oil samples collected as late as 3½ months after injection. After the test well was returned to production, it produced 174 bbl of oil during a 60-day period (September 22 to November 21, 2008), which represents an estimated 58 percent increase in incremental oil production over preinjection estimates of production under normal, conditions. The geologic model was used in a reservoir simulation model for a 700-acre model area and to design a pilot to test the model. The model was designed to achieve a 1-year response time and a five-year simulation period. The reservoir simulation modeling indicated that the injection wells could enhance oil production and lead to an additional 20 percent recovery in the pilot area over a five-year period. The base case estimated that by injecting 500 MCF per day of CO2 into each of the four corner wells, 26,000 STBO would be produced by the central producer over the five-year period. This would compare to 3,000 STBO if a new well were drilled without the benefit of CO2 injection. This study has added significant knowledge to the reservoir characterization of the “Clinton” in the ECOF and succeeded in identifying a range on CO2-EOR potential. However, additional data on fluid properties (PVT and swelling test), fractures (oriented core and microseis), and reservoir characteristics (relative permeability, capillary pressure, and wet ability) are needed to further narrow the uncertainties and refine the reservoir model and simulation. After collection of this data and refinement of the model and simulation, it is recommended that a larger scale cyclic- CO2 injection test be conducted to better determine the efficacy of CO2-EOR in the “Clinton” reservoir in the ECOF.

  9. Silurian "Clinton" Sandstone Reservoir Characterization for Evaluation of CO2-EOR Potential in the East Canton Oil Field, Ohio

    SciTech Connect (OSTI)

    Ronald Riley; John Wicks; Christopher Perry

    2009-12-30T23:59:59.000Z

    The purpose of this study was to evaluate the efficacy of using CO2-enhanced oil recovery (EOR) in the East Canton oil field (ECOF). Discovered in 1947, the ECOF in northeastern Ohio has produced approximately 95 million barrels (MMbbl) of oil from the Silurian 'Clinton' sandstone. The original oil-in-place (OOIP) for this field was approximately 1.5 billion bbl and this study estimates by modeling known reservoir parameters, that between 76 and 279 MMbbl of additional oil could be produced through secondary recovery in this field, depending on the fluid and formation response to CO2 injection. A CO2 cyclic test ('Huff-n-Puff') was conducted on a well in Stark County to test the injectivity in a 'Clinton'-producing oil well in the ECOF and estimate the dispersion or potential breakthrough of the CO2 to surrounding wells. Eighty-one tons of CO2 (1.39 MMCF) were injected over a 20-hour period, after which the well was shut in for a 32-day 'soak' period before production was resumed. Results demonstrated injection rates of 1.67 MMCF of gas per day, which was much higher than anticipated and no CO2 was detected in gas samples taken from eight immediately offsetting observation wells. All data collected during this test was analyzed, interpreted, and incorporated into the reservoir characterization study and used to develop the geologic model. The geologic model was used as input into a reservoir simulation performed by Fekete Associates, Inc., to estimate the behavior of reservoir fluids when large quantities of CO2 are injected into the 'Clinton' sandstone. Results strongly suggest that the majority of the injected CO2 entered the matrix porosity of the reservoir pay zones, where it diffused into the oil. Evidence includes: (A) the volume of injected CO2 greatly exceeded the estimated capacity of the hydraulic fracture and natural fractures; (B) there was a gradual injection and pressure rate build-up during the test; (C) there was a subsequent, gradual flashout of the CO2 within the reservoir during the ensuing monitored production period; and (D) a large amount of CO2 continually off-gassed from wellhead oil samples collected as late as 3 1/2 months after injection. After the test well was returned to production, it produced 174 bbl of oil during a 60-day period (September 22 to November 21, 2008), which represents an estimated 58 percent increase in incremental oil production over preinjection estimates of production under normal, conditions. The geologic model was used in a reservoir simulation model for a 700-acre model area and to design a pilot to test the model. The model was designed to achieve a 1-year response time and a five-year simulation period. The reservoir simulation modeling indicated that the injection wells could enhance oil production and lead to an additional 20 percent recovery in the pilot area over a five-year period. The base case estimated that by injecting 500 MCF per day of CO2 into each of the four corner wells, 26,000 STBO would be produced by the central producer over the five-year period. This would compare to 3,000 STBO if a new well were drilled without the benefit of CO2 injection. This study has added significant knowledge to the reservoir characterization of the 'Clinton' in the ECOF and succeeded in identifying a range on CO2-EOR potential. However, additional data on fluid properties (PVT and swelling test), fractures (oriented core and microseis), and reservoir characteristics (relative permeability, capillary pressure, and wet ability) are needed to further narrow the uncertainties and refine the reservoir model and simulation. After collection of this data and refinement of the model and simulation, it is recommended that a larger scale cyclic-CO2 injection test be conducted to better determine the efficacy of CO2-EOR in the 'Clinton' reservoir in the ECOF.

  10. Supported polyethylenimine adsorbents for CO2 capture from flue gas

    SciTech Connect (OSTI)

    Fauth, D.J.; Gray, M.L.; Pennline, H.W.

    2008-10-01T23:59:59.000Z

    Anthropogenic CO2 emissions produced from fossil fuel combustion are believed to contribute to undesired consequences in global climate. Major contributors towards CO2 emissions are fossil fuel-fired power plants for electricity production. For this reason, CO2 capture from flue gas streams together with permanent sequestration in geologic formations is being considered a viable solution towards mitigation of the major greenhouse gas1. Technologies based on chemical absorption with alkanolamines have been assessed for first generation CO2 post-combustion capture primarily due to its advanced stage of development. However, limitations associated with these chemical solvents (i.e., low CO2 loadings, amine degradation by oxygen, equipment corrosion) manifest themselves in high capital and operating costs with reduced thermal efficiencies. Therefore, necessary design and development of alternative, lower cost approaches for CO2 capture from coal-fired combustion streams are warranted.

  11. Hybrid Membrane/Absorption Process for Post-combustion CO2 Capture

    SciTech Connect (OSTI)

    Li, Shiguang; Shou, S.; Pyrzynski, Travis; Makkuni, Ajay; Meyer, Howard

    2013-12-31T23:59:59.000Z

    This report summarizes scientific/technical progress made for bench-scale membrane contactor technology for post-combustion CO2 capture from DOE Contract No. DE-FE-0004787. Budget Period 1 (BP1) membrane absorber, Budget Period 2 (BP2) membrane desorber and Budget Period 3 (BP3) integrated system and field testing studies have been completed successfully and met or exceeded the technical targets (? 90% CO2 removal and CO2 purity of 97% in one membrane stage). Significant breakthroughs are summarized below: BP1 research: The feasibility of utilizing the poly (ether ether ketone), PEEK, based hollow fiber contractor (HFC) in combination with chemical solvents to separate and capture at least 90% of the CO2 from simulated flue gases has been successfully established. Excellent progress has been made as we have achieved the BP1 goal: ? 1,000 membrane intrinsic CO2 permeance, ? 90% CO2 removal in one stage, ? 2 psi gas side pressure drop, and ? 1 (sec)-1 mass transfer coefficient. Initial test results also show that the CO2 capture performance, using activated Methyl Diethanol Amine (aMDEA) solvent, was not affected by flue gas contaminants O2 (~3%), NO2 (66 ppmv), and SO2 (145 ppmv). BP2 research: The feasibility of utilizing the PEEK HFC for CO2-loaded solvent regeneration has been successfully established High CO2 stripping flux, one order of magnitude higher than CO2 absorption flux, have been achieved. Refined economic evaluation based on BP1 membrane absorber and BP2 membrane desorber laboratory test data indicate that the CO2 capture costs are 36% lower than DOE’s benchmark amine absorption technology. BP3 research: A bench-scale system utilizing a membrane absorber and desorber was integrated into a continuous CO2 capture process using contactors containing 10 to 20 ft2 of membrane area. The integrated process operation was stable through a 100-hour laboratory test, utilizing a simulated flue gas stream. Greater than 90% CO2 capture combined with 97% CO2 product purity was achieved throughout the test. Membrane contactor modules have been scaled from bench scale 2-inch diameter by 12-inch long (20 ft2 membrane surface area) modules to 4-inch diameter by 60-inch long pilot scale modules (165 ft2 membrane surface area). Pilot scale modules were tested in an integrated absorption/regeneration system for CO2 capture field tests at a coal-fired power plant (Midwest Generation’s Will County Station located in Romeoville, IL). Absorption and regeneration contactors were constructed utilizing high performance super-hydrophobic, nano-porous PEEK membranes with CO2 gas permeance of 2,000 GPU and a 1,000 GPU, respectively. Field tests using aMDEA solvent achieved greater than 90% CO2 removal in a single stage. The absorption mass transfer coefficient was 1.2 (sec)-1, exceeding the initial target of 1.0 (sec)-1. This mass transfer coefficient is over one order of magnitude greater than that of conventional gas/liquid contacting equipment. The economic evaluation based on field tests data indicates that the CO2 capture cost associated with membrane contactor technology is $54.69 (Yr 2011$)/tonne of CO2 captured when using aMDEA as a solvent. It is projected that the DOE’s 2025 cost goal of $40 (Yr 2011$)/tonne of CO2 captured can be met by decreasing membrane module cost and by utilizing advanced CO2 capture solvents. In the second stage of the field test, an advanced solvent, Hitachi’s H3-1 was utilized. The use of H3-1 solvent increased mass transfer coefficient by 17% as compared to aMDEA solvent. The high mass transfer coefficient of H3-1 solvent combined with much more favorable solvent regeneration requirements, indicate that the projected savings achievable with membrane contactor process can be further improved. H3-1 solvent will be used in the next pilot-scale development phase. The integrated absorption/regeneration process design and high performance membrane contactors developed in the current bench-scale program will be used as the base technology for future pilot-scale development.

  12. Center for Nanoscale Control of Geologic CO2 (EFRC) - Research...

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    Summary The objective of the DOE Energy Frontier Research Center (EFRC) for Nanoscale Control of Geologic CO2 (NCGC) is to use new investigative tools, combined with experiments...

  13. The geomechanics of CO2 storage in deep sedimentary formations

    E-Print Network [OSTI]

    Rutqvist, J.

    2013-01-01T23:59:59.000Z

    The geomechanics of CO 2 storage in deep sedimentaryThis paper provides a review of the geomechanics andmodeling of geomechanics associated with geologic carbon

  14. Summary Report on CO2 Geologic Sequestration & Water Resources Workshop

    E-Print Network [OSTI]

    Varadharajan, C.

    2013-01-01T23:59:59.000Z

    CO 2 Geological Storage and Ground Water Resources U.S.and Ground Water Protection Council (GWPC) State and Federal Statutes Storage,

  15. Advanced Post-Combustion CO2 Capture Prepared for the

    E-Print Network [OSTI]

    Advanced Post-Combustion CO2 Capture Prepared for the Clean Air Task Force under a grant from...................................................................................... 3 2. Current Status of Post-Combustion Capture

  16. accelerating co2 emissions: Topics by E-print Network

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    based on the empirical relationship between CO2 per capita emissions (due to fossil fuel combustion and cement production) and corresponding HDI. In order to project per capita...

  17. Consumption-based accounting of CO2 emissions

    E-Print Network [OSTI]

    Davis, S. J; Caldeira, K.

    2010-01-01T23:59:59.000Z

    Soviet Union (Ukraine, Kazakhstan, Belarus, and Russia),kg CO 2 /$GDP FSS Ukraine Kazakhstan Iran East Asia BelarusAsia China South Africa Kazakhstan Malaysia Russia Thailand

  18. The geomechanics of CO2 storage in deep sedimentary formations

    E-Print Network [OSTI]

    Rutqvist, J.

    2013-01-01T23:59:59.000Z

    strain and microseismicity, well integrity, caprock sealingstrain and microseismicity, well integrity, caprock sealingactions. 7 WELLBORE INTEGRITY The well design of a deep CO 2

  19. Summary Report on CO2 Geologic Sequestration & Water Resources Workshop

    E-Print Network [OSTI]

    Varadharajan, C.

    2013-01-01T23:59:59.000Z

    Efforts Investigating Water Extraction •! LLNL –! Active CObenefits of various water extraction, treatment, and reuseof CO 2 storage and water extraction scenarios –! Technical

  20. Influence of capillary pressure on CO2 storage and monitoring

    E-Print Network [OSTI]

    gabriela

    solutions to mitigate the greenhouse effect. We are interested in analyzing the influence of capillary pressure on CO2 in- jection, storage and monitoring in saline ...

  1. Micromodel Investigations of CO2 Exsolution from Carbonated Water...

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    of CO2 Exsolution from Carbonated Water in Sedimentary Rocks. Abstract: In this study, carbon dioxide exsolution from carbonated water is directly observed under reservoir...

  2. CO2 exposure at pressure impacts metabolism and stress responses...

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    in the model sulfate-reducing bacterium Desulfovibrio vulgaris Abstract: Geologic carbon dioxide (CO2) sequestration drives physical and geochemical changes in deep...

  3. Enhanced Geothermal Systems (EGS) with CO2as Heat Transmission...

    Broader source: Energy.gov (indexed) [DOE]

    Program eere.energy.gov * The project started in FY10 * Collaboration between LBNL (Pruess) and INL (Redden) - Berkeley leads modeling, CO 2 -brine flow and heat...

  4. Quantum Alloys Offer Prospects for CO2 Management Technologies...

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    radical new catalysts capable of converting CO2 emissions into fuels, chemicals, and plastics. Their unique discovery involves shrinking gold into a system consisting of just 25...

  5. atmospheric co2 content: Topics by E-print Network

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    Of Physics Version 4 Gerlich and Ralf D. Tscheuschner Abstract The atmospheric greenhouse effect, an idea that many authors Of The Atmospheric CO2 Greenhouse Effects . . . 3...

  6. atmospheric co2 concentrations: Topics by E-print Network

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    Of Physics Version 4 Gerlich and Ralf D. Tscheuschner Abstract The atmospheric greenhouse effect, an idea that many authors Of The Atmospheric CO2 Greenhouse Effects . . . 3...

  7. atmospheric co2 concentration: Topics by E-print Network

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    Of Physics Version 4 Gerlich and Ralf D. Tscheuschner Abstract The atmospheric greenhouse effect, an idea that many authors Of The Atmospheric CO2 Greenhouse Effects . . . 3...

  8. atmospheric co2 laser: Topics by E-print Network

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    Of Physics Version 4 Gerlich and Ralf D. Tscheuschner Abstract The atmospheric greenhouse effect, an idea that many authors Of The Atmospheric CO2 Greenhouse Effects . . . 3...

  9. atmospheric co2 measurements: Topics by E-print Network

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    Of Physics Version 4 Gerlich and Ralf D. Tscheuschner Abstract The atmospheric greenhouse effect, an idea that many authors Of The Atmospheric CO2 Greenhouse Effects . . . 3...

  10. atmospheric co2 variations: Topics by E-print Network

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    Of Physics Version 4 Gerlich and Ralf D. Tscheuschner Abstract The atmospheric greenhouse effect, an idea that many authors Of The Atmospheric CO2 Greenhouse Effects . . . 3...

  11. atmospheric co2 mixing: Topics by E-print Network

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    Of Physics Version 4 Gerlich and Ralf D. Tscheuschner Abstract The atmospheric greenhouse effect, an idea that many authors Of The Atmospheric CO2 Greenhouse Effects . . . 3...

  12. A shallow subsurface controlled release facility in Bozeman, Montana, USA, for testing near surface CO2 detection techniques and transport models

    SciTech Connect (OSTI)

    Spangler, L.H.; Dobeck, L.M.; Nehrir, A.; Humphries, S.; Barr, J.; Keith, C.; Shaw, J.; Rouse, J.; Cunningham, A.; Benson, S.; Repasky, K.S.; Lewicki, J.; Wells, A.; Diehl, R.; Strazisar, B.; Fessenden, J.; Rahn, T.; Amonette, J.; Barr, J.; Pickles, W.; Jacobson, J.; Silver, E.; Male, E.; Rauch, H.; Gullickson, K.; Trautz, R.; Kharaka, Y.; Birkholzer, J.T.; Wielopolski, L.; Oldenburg, C.M.

    2009-10-20T23:59:59.000Z

    A controlled field pilot has been developed in Bozeman, Montana, USA, to study near surface CO2 transport and detection technologies. A slotted horizontal well divided into six zones was installed in the shallow subsurface. The scale and CO2 release rates were chosen to be relevant to developing monitoring strategies for geological carbon storage. The field site was characterized before injection, and CO2 transport and concentrations in saturated soil and the vadose zone were modeled. Controlled releases of CO2 from the horizontal well were performed in the summers of 2007 and 2008, and collaborators from six national labs, three universities, and the U.S. Geological Survey investigated movement of CO2 through the soil, water, plants, and air with a wide range of near surface detection techniques. An overview of these results will be presented.

  13. ORNL/CDIAC-160 Climatological Distributions of pH, pCO2, Total CO2, Alkalinity,

    E-Print Network [OSTI]

    ORNL/CDIAC-160 NDP-094 Climatological Distributions of pH, pCO2, Total CO2, Alkalinity, and CaCO3, Alkalinity, and CaCO3 Saturation in the Global Surface Ocean. ORNL/CDIAC-160, NDP-094. Carbon Dioxide, total CO2 concentration (TCO2), and the degree of CaCO3 saturation for the global surface ocean waters

  14. ELECTRONIC FUEL INJECTION DIESEL LOCOMOTIVES

    E-Print Network [OSTI]

    Jagannatham, Aditya K.

    ELECTRONIC FUEL INJECTION FOR DIESEL LOCOMOTIVES 13 August, 2011 Diesel Loco Modernisation Works, Patiala #12;ELECTRONIC FUEL INJECTION FOR DIESEL LOCOMOTIVES A Milestone in Green Initiatives by Indian Diesel Locomotive equipped with "Electronic Fuel Injection (EFI)" was turned out by the Diesel Loco

  15. A Theoretical Study of CO2 Anions on Anatase (101) Surface. ...

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    CO2 Anions on Anatase (101) Surface. A Theoretical Study of CO2 Anions on Anatase (101) Surface. Abstract: Binding configurations of CO2 and CO2 - on perfect and oxygen-deficient...

  16. Inducinga CO2 leak into ashallow aquifer (CO2FieldLab EUROGIA+ project): Monitoring the CO2 plume in groundwaters.

    E-Print Network [OSTI]

    Paris-Sud XI, Université de

    (saline aquifer, depleted oil/gas reservoir), aquifers are ubiquitousin the overlying sedimentary pile in case of unwanted CO2leakages from a storage site. Independently from the nature of the reservoir

  17. Solid molecular basket sorbent for CO2 capture from gas streams with low CO2 concentration at ambient conditions

    SciTech Connect (OSTI)

    Wang, Xiaoxing [Pennsylvania State University; Ma, Xiaoliang [Pennsylvania State University; Schwartz, Viviane [ORNL; Clark, Jason C [ORNL; Overbury, Steven {Steve} H [ORNL; Zhao, Shuqi [Pennsylvania State University, University Park, PA; Xu, Xiaochun [Pennsylvania State University; Song, Chunshan [Pennsylvania State University

    2012-01-01T23:59:59.000Z

    In this paper, a solid molecular basket sorbent, 50 wt% PEI/SBA-15 was studied for CO2 capture from gas streams with low CO2 concentration at ambient conditions. The sorbent was able to effectively and selectively capture CO2 from a gas stream containing 1% CO2 at 75 C, with a breakthrough and saturation capacity of 63.1 and 66.7 mg/g, respectively, and a selectivity of 14 for CO2/CO and 185 for CO2/Ar. The sorption performance of the sorbent was influenced greatly by the operating temperature. The CO2-TPD study showed that the sorbent could be regenerated at mild conditions (50-110 C) and was stable in the cyclical operations for at least 20 cycles. Furthermore, the possibility for CO2 capture from air using the PEI/SBA-15 sorbent was studied by FTIR and proved by TPD. A capacity of 22.5 mg/g was attained at 75 C via TPD method using a simulated air with 400 ppmv CO2 in N2.

  18. Leakage and Sepage of CO2 from Geologic Carbon Sequestration Sites: CO2 Migration into Surface Water

    E-Print Network [OSTI]

    Oldenburg, Curt M.; Lewicki, Jennifer L.

    2005-01-01T23:59:59.000Z

    from geologic carbon sequestration sites: unsaturated zoneCO 2 from Geologic Carbon Sequestration Sites, Vadose Zoneseepage from geologic carbon sequestration sites may occur.

  19. Single photon ionization of van der Waals clusters with a soft x-ray laser: ,,CO2...n and ,,CO2...n,,H2O...m

    E-Print Network [OSTI]

    Rocca, Jorge J.

    Single photon ionization of van der Waals clusters with a soft x-ray laser: ,,CO2...n and ,,CO2...n 2006; published online 20 October 2006 Pure neutral CO2 n clusters and mixed CO2 n H2O m clustersV. The distribution of pure CO2 n clusters decreases roughly exponentially with increasing cluster size. During

  20. Greener Solvent Selection and Solvent Recycling for CO2 Capture Economically removing CO2 from the flue gases of coal-fired power plants would alleviate concerns

    E-Print Network [OSTI]

    Ben-Arie, Jezekiel

    to remove CO2 from dilute gas streams because they have very high affinity for CO2. Unfortunately high solvents that balance high affinity for CO2 with ease of solvent recovery and reuse. Because the numberGreener Solvent Selection and Solvent Recycling for CO2 Capture Economically removing CO2 from

  1. An integrated experimental and numerical study: Developing a reaction transport model that couples chemical reactions of mineral dissolution/precipitation with spatial and temporal flow variations in CO2/brine/rock systems

    Broader source: Energy.gov [DOE]

    Project objectives: Generate and characterize mineral dissolution/precipitation reactions in supercritical CO2/brine/rock systems under pressure-temperature-chemistry conditions resembling CO2injection into EGS. Characterize three-dimensional spatial and temporal distributions of rock structures subject to mineral dissolution/precipitation processes by X-ray tomography, SEM imaging, and Microprobe analysis.

  2. Analysis of Potential Energy Saving and CO2 Emission Reduction of Home Appliances and Commercial Equipments in China

    E-Print Network [OSTI]

    Zhou, Nan

    2011-01-01T23:59:59.000Z

    Others* Air Conditioner Frozen Scenario Total CO2 EmissionsCO2 Emissions (million tonnes CO2)Improvement Scenario Total CO2 Emissions *Others include:

  3. Development of Novel CO2 Adsorbents for Capture of CO2 from Flue Gas

    Office of Scientific and Technical Information (OSTI)

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative1 First Use of Energy for All Purposes (Fuel and Nonfuel), 2002; Level: National5Sales for4,645 3,625 1,006 492 742EnergyOnItem Not Found Item Not Found The itemAIR57451 CleanFOR IMMEDIATE RELEASENovel CO 2

  4. Intercomparison of simulation models for CO2 disposal in underground storage reservoirs

    E-Print Network [OSTI]

    Pruess, Karsten; Tsang, Chin-Fu; Law, David; Oldenburg, Curt

    2001-01-01T23:59:59.000Z

    oil recovery (EOR) using CO2 requires an understanding ofexperience with using CO2 for EOR projects (SPE, 1999), and

  5. Quantifying Regional Economic Impacts of CO2 Intensity Targets in China

    E-Print Network [OSTI]

    Zhang, Da

    2012-09-01T23:59:59.000Z

    To address rising energy use and CO2 emissions, China’s leadership has enacted energy and CO2 intensity

  6. What Can China Do? China's Best Alternative Outcome for Energy Efficiency and CO2 Emissions

    E-Print Network [OSTI]

    G. Fridley, David

    2010-01-01T23:59:59.000Z

    CO2 mitigation potential and costs in China's electricityCO2 mitigation potential and costs in China's electricity

  7. A Mechanistic Model for CO2 Sequestration in Tiffany Coal Bed Methane Field

    SciTech Connect (OSTI)

    Liang, J.; Raterman, K.T.; Robertson, E.P.

    2003-05-01T23:59:59.000Z

    The objective of this project is to develop mechanistic models specific to CO2 sequestration in BP's Tiffany coal bed methane (CBM) field. In this study, the original field model was modified to match the field performance of a 5-spot pattern in the northern part of the Tiffany Field where BP plans to perform a micro-pilot test. The modified model consists of one high-permeability fast layer sandwiched between two low-permeability slow layers. In this mechanistic model, the fast layer represents well-cleated and fractured coal from all geological layers while the slow layers represent coal with little or no fracture development from the same geological layers. The model successfully matched the performance of the 5-spot pattern during the enhanced recovery period. However, in order to match nitrogen breakthrough times and nitrogen cut the vertical transmissibility between layers had to be set to zero. During gas injection, nitrogen was allowed to enter all three layers, not just the high-permeability fast layer. However, because the permeabilities of the slow layers were low and there is no communication between the fast and the slow layers, most of the injected nitrogen entered the high-permeability fast layer. This suggests that the future gas injection and CO2 sequestration may be restricted to only one third of the total available pay.

  8. An investigation of reaction parameters on geochemical storage of non-pure CO2 streams in iron oxides-bearing formations

    SciTech Connect (OSTI)

    Garcia, Susana; Liu, Q.; Bacon, Diana H.; Maroto-Valer, M. M.

    2014-08-26T23:59:59.000Z

    Hematite deposit that is the main FeIII-bearing mineral in sedimentary red beds was proposed as a potential host repository for converting CO2 into carbonate minerals such as siderite (FeCO3), when CO2–SO2 gas mixtures are co-injected. This work investigated CO2 mineral trapping using hematite and sensitivity of the reactive systems to different parameters, including particle size, gas composition, temperature, pressure, and solid-to-liquid ratio. Experimental and modelling studies of hydrothermal experiments were conducted, which emulated a CO2 sequestration scenario by injecting CO2-SO2 gas streams into a NaCl-NaOH brine hosted in iron oxide-containing aquifer. This study provides novel information on the mineralogical changes and fluid chemistry derived from the co-injection of CO2-SO2 gas mixtures in hematite deposit. It can be concluded that the amount of siderite precipitate depends primarily on the SO2 content of the gas stream. Increasing SO2 content in the system could promote the reduction of Fe3+ from the hematite sample to Fe2+, which will be further available for its precipitation as siderite. Moreover, siderite precipitation is enhanced at low temperatures and high pressures. The influence of the solid to liquid ratio on the overall carbonation reaction suggests that the conversion increases if the system becomes more diluted.

  9. Original article Responses to elevated atmospheric CO2 concentration

    E-Print Network [OSTI]

    Paris-Sud XI, Université de

    Original article Responses to elevated atmospheric CO2 concentration and nitrogen supply of Quercus* School of Forest Resources and Conservation, University of Florida, 326 Newins-Ziegler Hall, Gainesville. Elevated [CO2] increased biomass production only in the high-N treatment. Fine root/foliage mass ratio

  10. Comprehensive Monitoring of CO2 Sequestration in Subalpine Forest Ecosystems

    E-Print Network [OSTI]

    Han, Richard Y.

    , carbon sequestration, ecosystem, multi-tier, multi-modal, multi-scale, self organized, sensor array to comprehensively monitor ecosystem carbon sequestration. The network consists of CO2, Weather (pressureComprehensive Monitoring of CO2 Sequestration in Subalpine Forest Ecosystems and Its Relation

  11. HYDROMECHANICAL CHARACTERIZATION FOR SITE SELECTION IN CO2 PERMANENT

    E-Print Network [OSTI]

    Politècnica de Catalunya, Universitat

    -BarcelonaTech), Barcelona, Spain 3 Energy City Foundation (CIUDEN), Spanish Government CO2 Geological Storage Programme (Vilarrasa et al., 2011, Energy Procedia) Trees killed by CO2 leakage in Mammoth Mountains (Farrar et al EQUATIONS Mass conservation equation Darcy's law Momentum balance Effective stress Hooke's law (linear

  12. The contribution of CO2 capture and storage

    E-Print Network [OSTI]

    The contribution of CO2 capture and storage to a sustainable energy system Policy brief the prospects of CO2 capture and storage (CCS) technologies in the power sector. Based on the results of 10. The uncertainties, particularly in storage capacities, are large. Using conservative estimates in line with the IPCC

  13. European and Global Perspectives for CO2 Capture and Storage

    E-Print Network [OSTI]

    European and Global Perspectives for CO2 Capture and Storage Heleen Groenenberg, Martine Uyterlinde, ECN Policy Studies, The Netherlands Abstract CO2 capture and storage (CCS) is increasingly mentioned a large point source, compression, transport and subsequent storage in a geological reservoir, the ocean

  14. Ex post evaluations of CO2 based taxes: a survey

    E-Print Network [OSTI]

    Watson, Andrew

    of fossil fuels, and which are introduced with the explicit intention of abating CO2 emissions. This paper and, especially, subsidies, has been called into question. Secondly, the CO2-based taxes themselves and subsidies), it is unlikely that they have been cost-effective (in the sense of attaining their environmental

  15. Distribution of anthropogenic CO2 in the Pacific Ocean

    E-Print Network [OSTI]

    Distribution of anthropogenic CO2 in the Pacific Ocean C. L. Sabine,1 R. A. Feely,2 R. M. Key,3 J] This work presents an estimate of anthropogenic CO2 in the Pacific Ocean based on measurements from the WOCE tracers; 9355 Information Related to Geographic Region: Pacific Ocean; KEYWORDS: Pacific Ocean

  16. arbon dioxide (CO2 atmosphere has increased by

    E-Print Network [OSTI]

    responsive to rising atmospheric CO2 concentration than C3 species. In the southwestern United States substrate for photosynthetic energy acquisition by life, the process of using light energy to combine CO2 surface and scale up to affect the landscape water balance. Thus, through its impacts on plant water use

  17. The Energy and CO2 Emissions Impact of

    E-Print Network [OSTI]

    for developing renewable electricity--wind, solar, and biomass-- would require expansion on an unprecedentedThe Energy and CO2 Emissions Impact of Renewable Energy Development in China Xiliang Zhang, Tianyu://globalchange.mit.edu/ Printed on recycled paper #12;1 The Energy and CO2 Emissions Impact of Renewable Energy Development

  18. Oxidation in Environments with Elevated CO2 Levels

    SciTech Connect (OSTI)

    Gordon H. Holcomb

    2009-05-01T23:59:59.000Z

    Efforts to reduce greenhouse gas emissions from fossil energy power productions focus primarily on either pre- or post-combustion removal of CO2. The research presented here examines corrosion and oxidation issues associated with two types of post-combustion CO2 removal processes—oxyfuel combustion in refit boilers and oxyfuel turbines.

  19. Falsification Of The Atmospheric CO2 Greenhouse Effects

    E-Print Network [OSTI]

    Learned, John

    Falsification Of The Atmospheric CO2 Greenhouse Effects Within The Frame Of Physics Version 4 Gerlich and Ralf D. Tscheuschner Abstract The atmospheric greenhouse effect, an idea that many authors Of The Atmospheric CO2 Greenhouse Effects . . . 3 Contents Abstract 2 1 Introduction 6 1.1 Problem background

  20. Chemical Impact of Elevated CO2on Geothermal Energy Production

    Broader source: Energy.gov [DOE]

    This is a two phase project to assess the geochemical impact of CO2on geothermal energy production by: analyzing the geochemistry of existing geothermal fields with elevated natural CO2; measuring realistic rock-water rates for geothermal systems using laboratory and field-based experiments to simulate production scale impacts.

  1. Variations in 13 C discrimination during CO2 exchange1

    E-Print Network [OSTI]

    exchange. Observed 13 were described well by the classical model of5 Farquhar, O'Leary & Berry (1982 enzymes, as well as to differential diffusivities of 13 CO2 and 12 CO2 in air9 (O'Leary, 1984; Farquhar, O'Leary

  2. CO2 Capture by Absorption with Potassium Carbonate

    E-Print Network [OSTI]

    Rochelle, Gary T.

    CO2 Capture by Absorption with Potassium Carbonate Third Quarterly Report 2005 Quarterly Progress absorption/stripping by developing an alternative solvent, aqueous K2CO3 promoted by piperazine. Modeling.................................................................................................................................. 11 Task 1 ­ Modeling Performance of Absorption/Stripping of CO2 with Aqueous K2CO3 Promoted

  3. CO2 Capture by Absorption with Potassium Carbonate

    E-Print Network [OSTI]

    Rochelle, Gary T.

    CO2 Capture by Absorption with Potassium Carbonate Fourth Quarterly Report 2005 Quarterly Progress absorption/stripping by developing an alternative solvent, aqueous K2CO3 promoted by piperazine. In Campaign.................................................................................................................................... 9 Task 1 ­ Modeling Performance of Absorption/Stripping of CO2 with Aqueous K2CO3 Promoted

  4. International Symposium on Site Characterization for CO2Geological Storage

    SciTech Connect (OSTI)

    Tsang, Chin-Fu

    2006-02-23T23:59:59.000Z

    Several technological options have been proposed to stabilize atmospheric concentrations of CO{sub 2}. One proposed remedy is to separate and capture CO{sub 2} from fossil-fuel power plants and other stationary industrial sources and to inject the CO{sub 2} into deep subsurface formations for long-term storage and sequestration. Characterization of geologic formations for sequestration of large quantities of CO{sub 2} needs to be carefully considered to ensure that sites are suitable for long-term storage and that there will be no adverse impacts to human health or the environment. The Intergovernmental Panel on Climate Change (IPCC) Special Report on Carbon Dioxide Capture and Storage (Final Draft, October 2005) states that ''Site characterization, selection and performance prediction are crucial for successful geological storage. Before selecting a site, the geological setting must be characterized to determine if the overlying cap rock will provide an effective seal, if there is a sufficiently voluminous and permeable storage formation, and whether any abandoned or active wells will compromise the integrity of the seal. Moreover, the availability of good site characterization data is critical for the reliability of models''. This International Symposium on Site Characterization for CO{sub 2} Geological Storage (CO2SC) addresses the particular issue of site characterization and site selection related to the geologic storage of carbon dioxide. Presentations and discussions cover the various aspects associated with characterization and selection of potential CO{sub 2} storage sites, with emphasis on advances in process understanding, development of measurement methods, identification of key site features and parameters, site characterization strategies, and case studies.

  5. EIS-0473: W.A. Parish Post-Combustion CO2 Capture and Sequestration Project (PCCS), Fort Bend County, TX

    Broader source: Energy.gov [DOE]

    This EIS evaluates the environmental impacts of a proposal to provide financial assistance for a project proposed by NRG Energy, Inc (NRG). DOE selected NRG’s proposed W.A. Parish Post-Combustion CO2 Capture and Sequestration Project for a financial assistance award through a competitive process under the Clean Coal Power Initiative Program. NRG would design, construct and operate a commercial-scale carbon dioxide (CO2) capture facility at its existing W.A. Parish Generating Station in Fort Bend County, Texas; deliver the CO2 via a new pipeline to the existing West Ranch oil field in Jackson County, Texas, for use in enhanced oil recovery operations; and demonstrate monitoring techniques to verify the permanence of geologic CO2 storage.

  6. Diffusion of CO2 During Hydrate Formation and Dissolution

    SciTech Connect (OSTI)

    Franklin M. Orr, Jr.

    2002-08-20T23:59:59.000Z

    Experiments were performed to measure the rate of diffusion of CO2 through hydrate films. Hydrate films were created in a capillary tube, and the growth of the hydrate film was measured. Difficulties were encountered in creating hydrate repeatedly, and some non-uniform growth of the films was observed. Sufficient observations were obtained to demonstrate that hydrate growth occurs preferentially on the hydrate/water side of the interface, rather than at the hydrate/CO2 interface. Diffusion coefficients were estimated from observations of the rate of growth of the hydrate film along with estimates of the solubility of CO2 in water and of the concentration gradient across the hydrate layer. The experimental observations indicate that hydrate formation occurs much more rapidly at the hydrate water interface than at the hydrate/CO2 interface. Any growth of hydrate at the CO2/hydrate interface was too slow to be observed at the time scale of the experiments. That observation is consistent with the idea that CO2 can move more easily through the hydrate, presumably by hopping between hydrate cages, than water can move through the hydrate, presumably by lattice hopping. Estimated diffusion coefficients were in the range 1-3E-06 cm2/sec. Those values are about an order of magnitude lower than the diffusion coefficient for CO2 in liquid water, but four orders of magnitude larger than the value for diffusion of CO2 in a solid. The rate of diffusion through the hydrate controls both the creation of new hydrate at the hydrate/water interface and the rate at which CO2 dissolves in the liquid water and diffuses away from the hydrate layer. Formation of a hydrate layer reduces the rate at which CO2 dissolves in liquid water.

  7. Enhanced geothermal systems (EGS) with CO2 as heat transmission fluid--A scheme for combining recovery of renewable energy with geologic storage of CO2

    E-Print Network [OSTI]

    Pruess, K.

    2010-01-01T23:59:59.000Z

    Could Sequestration of CO2 be Combined with the DevelopmentTOUGH2 Code for Studies of CO2 Storage in Saline Aquifers,and J. Ennis- King. CO2-H2O Mixtures in the Geological

  8. Odors that Modify CO2 Receptor Activity in Insects and Their Effect on Innate CO2-Mediated Behavior and Neuronal Plasticity

    E-Print Network [OSTI]

    Turner, Stephanie

    2010-01-01T23:59:59.000Z

    Intermediates in Insect CO2 Sensory Systems. Science Certel,2007). The molecular basis of CO2 reception in Drosophila.J. (2004). Floral CO2 Reveals Flower Profitability to Moths.

  9. Ris Energy Report 6 CO2 capture and storage 2 6.1 What is CO2 capture and storage?

    E-Print Network [OSTI]

    2 Gas, oil Air O2 H2 Raw material Gas, ammonia, steel Air/O2 Steam Figure 15: the three main to produce more Co2 per unit of product than a plant without CCS (upper bar). With ef- fective Co2 removal mines. The last two of these, known re- spectively as enhanced oil recovery (EOR) and enhanced coal bed

  10. GAS HYDRATE EQUILIBRIA FOR CO2-N2 AND CO2-CH4 GAS MIXTURES, EXPERIMENTS AND MODELLING

    E-Print Network [OSTI]

    Paris-Sud XI, Université de

    steelmaking plants, gas or coal power plants, chemical plants or natural gas production plants. Facing are by definition localized at the plants, like e.g. steelmaking plants, gas or coal power plants, chemical plants be in the order of several cubic meters of CO2 per second. In power plants, the concentration of CO2 is generally

  11. Predicting PVT data for CO2brine mixtures for black-oil simulation of CO2 geological storage

    E-Print Network [OSTI]

    Santos, Juan

    Predicting PVT data for CO2­brine mixtures for black-oil simulation of CO2 geological storage efficiency of the black-oil approach promote application of black-oil simulation for large-scale geological into geological formations has been considered as a potential method to mitigate climate change. Accurate

  12. Measurements of fluxes of water vapour, CO2 and pCO2 are obtained from a coastal site in

    E-Print Network [OSTI]

    Measurements of fluxes of water vapour, CO2 and pCO2 are obtained from a coastal site in Sweden study national reports UK The first eleven SOLAS projects supported by the Natural Environment Research the atmosphere, including biological interactions affecting DMS production and the role of upwelling in trace gas

  13. Gas Hydrate Equilibria for CO2-N2 and CO2-CH4 gas mixtures Experimental studies and Thermodynamic Modelling

    E-Print Network [OSTI]

    Paris-Sud XI, Université de

    Gas Hydrate Equilibria for CO2-N2 and CO2-CH4 gas mixtures ­ Experimental studies and Thermodynamic of experimental data on the phase equilibrium of gas hydrates in the presence of binary gas mixtures comprising CO of the gas phase as well as the hydrate phase without the need to sample the hydrate. The experimental

  14. PVTx properties of the CO2H2O and CO2H2ONaCl systems below 647 K: Assessment of experimental data

    E-Print Network [OSTI]

    Polly, David

    PVTx properties of the CO2­H2O and CO2­H2O­NaCl systems below 647 K: Assessment of experimental-composition (PVTx) properties for the CO2­H2O and CO2­H2O­NaCl systems. This paper presents a comprehensive review. Keywords: CO2 sequestration; PVTx properties; Volume; Density; Thermodynamic modeling 1. Introduction CO2­H

  15. CO2 Capture with Liquid-to-Solid Absorbents: CO2 Capture Process Using Phase-Changing Absorbents

    SciTech Connect (OSTI)

    None

    2010-10-01T23:59:59.000Z

    IMPACCT Project: GE and the University of Pittsburgh are developing a unique CO2 capture process in which a liquid absorbent, upon contact with CO2, changes into a solid phase. Once in solid form, the material can be separated and the CO2 can be released for storage by heating. Upon heating, the absorbent returns to its liquid form, where it can be reused to capture more CO2. The approach is more efficient than other solventbased processes because it avoids the heating of extraneous solvents such as water. This ultimately leads to a lower cost of CO2 capture and will lower the additional cost to produce electricity for coal-fired power plants that retrofit their facilities to include this technology.

  16. Combustion-Assisted CO2 Capture Using MECC Membranes

    SciTech Connect (OSTI)

    Sherman, Steven R [ORNL; Gray, Dr. Joshua R. [Savannah River National Laboratory (SRNL), Aiken, S.C.; Brinkman, Dr. Kyle S. [Savannah River National Laboratory (SRNL), Aiken, S.C.; Huang, Dr. Kevin [University of South Carolina, Columbia

    2012-01-01T23:59:59.000Z

    Mixed Electron and Carbonate ion Conductor (MECC) membranes have been proposed as a means to separate CO2 from power plant flue gas. Here a modified MECC CO2 capture process is analyzed that supplements retentate pressurization and permeate evacuation as a means to create a CO2 driving force with a process assisted by the catalytic combustion of syngas on the permeate side of the membrane. The combustion reactions consume transported oxygen, making it unavailable for the backwards transport reaction. With this change, the MECC capture system becomes exothermic, and steam for electricity production may be generated from the waste heat. Greater than 90% of the CO2 in the flue gas may be captured, and a compressed CO2 product stream is produced. A fossil-fueled power plant using this process would consume 14% more fuel per unit electricity produced than a power plant with no CO2 capture system, and has the potential to meet U.S. DOE s goal that deployment of a CO2 capture system at a fossil-fueled power plant should not increase the cost of electricity from the combined facility by more than 30%.

  17. Relationship between satellite-derived vegetation indices and aircraft-based CO2 measurements

    SciTech Connect (OSTI)

    Cihlar, J.; Caramori, P.H.; Schuepp, P.H.; Desjardins, R.L.; Macpherson, J.I. (Canada Centre for Remote Sensing, Ottawa (Canada) McGill Univ., Montreal (Canada) Agriculture Canada, Centre for Land and Biological Resources Research, Ottawa (Canada) National Research Council of Canada, Inst. for Aerospace Research, Ottawa (Canada))

    1992-11-01T23:59:59.000Z

    The objective of this study was to analyze the relationship between satellite-derived vegetation indices and CO2 uptake, as an initial step in exploring the possibility of using a satellite-derived vegetation index as a measure of net photosynthesis. The study area included the First International Satellite Land Surface Climatology Project (ISLSCP) Field Experiment (FIFE) site located on the Konza prairie and adjacent area as well as a transect between Manhattan and Salina. One third of the transect exhibited vegetation and terrain characteristics similar to those on the FIFE site, whereas cultivated land predominated in the remaining portion of the 75-km-long flight line. In June, July, August, and October 1987, several CO2 data sets were obtained using the National Research Council of Canada's Twin Otter research aircraft. The normalized difference vegetation index (NDVI) and the simple ratio (SR) were computed from NOAA AVHRR data acquired as part of FIFE. Aircraft and satellite data were processed to obtain spatially coincident and locally representative flux values. Results show a linear relationship between NDVI and CO2 uptake during a single day; however, a nonlinear relationship emerged when all data sets were combined. The data from FIFE and the regional transect were consistent for one date but differed for other periods. Overall, about 60 percent of total variability in CO2 flux was accounted for by the NDVI and 74 percent by the SR. 14 refs.

  18. Et notat til "det elektriske CO2 projekt". Med udgangspunkt i de studerendes CO2 tips analyseres CO2 emissionen i de forskellige belysningssituationer. De forskellige tips ses p projektets hjemmeside

    E-Print Network [OSTI]

    1 Et notat til "det elektriske CO2 projekt". Med udgangspunkt i de studerendes CO2 tips analyseres CO2 emissionen i de forskellige belysningssituationer. De forskellige tips ses på projektets hjemmeside www.co2tips.dk Indholdsfortegnelse EL-FORBRUG TIL BELYSNING I HUSHOLDNINGER

  19. Methanogenic Conversion of CO2 Into CH4

    SciTech Connect (OSTI)

    Stevens, S.H., Ferry, J.G., Schoell, M.

    2012-05-06T23:59:59.000Z

    This SBIR project evaluated the potential to remediate geologic CO2 sequestration sites into useful methane gas fields by application of methanogenic bacteria. Such methanogens are present in a wide variety of natural environments, converting CO2 into CH4 under natural conditions. We conclude that the process is generally feasible to apply within many of the proposed CO2 storage reservoir settings. However, extensive further basic R&D still is needed to define the precise species, environments, nutrient growth accelerants, and economics of the methanogenic process. Consequently, the study team does not recommend Phase III commercial application of the technology at this early phase.

  20. Co2(CO)8 Mediated PausonKhand Reaction (PKR)

    E-Print Network [OSTI]

    Stoltz, Brian M.

    1 Co2(CO)8 Mediated Pauson­Khand Reaction (PKR) Nathan Bennett May 11, 2009 R1 R2 R5 R6R4 R3 + Co2(CO)8 Promoter / Solvent CO atmosphere O R1 R2 R6 R5 R3 R4 X n R R' (n = 1-3) X = O, NR'', CR''2 Co2(CO)8 Promoter / Solvent CO atmosphere X n R O R' Pauson-Khand Reaction (PKR) General Information R1 R

  1. ENHANCED PRACTICAL PHOTOSYNTHETIC CO2 MITIGATION

    SciTech Connect (OSTI)

    Dr. Gregory Kremer; Dr. David J. Bayless; Dr. Morgan Vis; Dr. Michael Prudich; Dr. Keith Cooksey; Dr. Jeff Muhs

    2001-07-25T23:59:59.000Z

    This quarterly report documents significant achievements in the Enhanced Practical Photosynthetic CO{sub 2} Mitigation project during the period from 4/03/2001 through 7/02/2001. Most of the achievements are milestones in our efforts to complete the tasks and subtasks that constitute the project objectives. Note that this version of the quarterly technical report is a revision to add the reports from subcontractors Montana State and Oak Ridge National Laboratories The significant accomplishments for this quarter include: Development of an experimental plan and initiation of experiments to create a calibration curve that correlates algal chlorophyll levels with carbon levels (to simplify future experimental procedures); Completion of debugging of the slug flow reactor system, and development of a plan for testing the pressure drop of the slug flow reactor; Design and development of a new bioreactor screen design which integrates the nutrient delivery drip system and the harvesting system; Development of an experimental setup for testing the new integrated drip system/harvesting system; Completion of model-scale bioreactor tests examining the effects of CO{sub 2} concentration levels and lighting levels on Nostoc 86-3 growth rates; Completion of the construction of a larger model-scale bioreactor to improve and expand testing capabilities and initiation of tests; Substantial progress on construction of a pilot-scale bioreactor; and Preliminary economic analysis of photobioreactor deployment. Plans for next quarter's work are included in the conclusions. A preliminary economic analysis is included as an appendix.

  2. A quantitative comparison of the cost of employing EOR-coupled CSS supplemented with secondary DSF storage for two large CO2 point sources

    SciTech Connect (OSTI)

    Davidson, Casie L.; Dahowski, Robert T.; Dooley, James J.

    2011-04-18T23:59:59.000Z

    This paper explores the impact of the temporally dynamic demand for CO2 for enhanced hydrocarbon recovery with CO2 storage. Previous evaluations of economy-wide CO2 capture and geologic storage (CCS) deployment have typically applied a simplifying assumption that 100% of the potential storage capacity for a given formation is available on the first day of the analysis, and that the injection rate impacts only the number of wells required to inject a given volume of fluid per year, making it a cost driver rather than a technical one. However, as discussed by Dahowski and Bachu [1], storing CO2 in a field undergoing CO2 flooding for enhanced oil recovery (EOR) is subject to a set of constraints to which storage in DSFs is not, and these constraints combined with variable demand for CO2 may strongly influence the ability of an EOR field to serve as a baseload storage formation for commercial scale CCS projects undertaken as a means of addressing climate change mitigation targets. This analysis assumes that CCS is being undertaken in order to reduce CO2 emissions from the industrial sources evaluated and that there is enough of a disincentive associated with venting CO2 to the atmosphere that any CO2 not used within the EOR field will be stored in a suitable nearby deep saline formation (DSF). The authors have applied a CO2 demand profile to two cases chosen to illustrate the differences in cost impacts of employing EOR-based CCS as a part of a given source’s CCS portfolio. The first scenario is a less-than-ideal case in which a single EOR field is used for storage and all CO2 not demanded by the EOR project is stored in a DSF; the second scenario is designed to optimize costs by minimizing storage in the DSF and maximizing lower-cost EOR-based storage. Both scenarios are evaluated for two facilities emitting 3 and 6 MtCO2/y, corresponding to a natural gas processing facility and an IGCC electric power plant, respectively. Annual and lifetime average CO2 transport and storage costs are presented, and the impact of added capture and compression costs on overall project economics is examined.

  3. Recovery Act: Innovative CO2 Sequestration from Flue Gas Using Industrial Sources and Innovative Concept for Beneficial CO2 Use

    SciTech Connect (OSTI)

    Dando, Neal; Gershenzon, Mike; Ghosh, Rajat

    2012-07-31T23:59:59.000Z

    field testing of a biomimetic in-duct scrubbing system for the capture of gaseous CO2 coupled with sequestration of captured carbon by carbonation of alkaline industrial wastes. The Phase 2 project, reported on here, combined efforts in enzyme development, scrubber optimization, and sequestrant evaluations to perform an economic feasibility study of technology deployment. The optimization of carbonic anhydrase (CA) enzyme reactivity and stability are critical steps in deployment of this technology. A variety of CA enzyme variants were evaluated for reactivity and stability in both bench scale and in laboratory pilot scale testing to determine current limits in enzyme performance. Optimization of scrubber design allowed for improved process economics while maintaining desired capture efficiencies. A range of configurations, materials, and operating conditions were examined at the Alcoa Technical Center on a pilot scale scrubber. This work indicated that a cross current flow utilizing a specialized gas-liquid contactor offered the lowest system operating energy. Various industrial waste materials were evaluated as sources of alkalinity for the scrubber feed solution and as sources of calcium for precipitation of carbonate. Solids were mixed with a simulated sodium bicarbonate scrubber blowdown to comparatively examine reactivity. Supernatant solutions and post-test solids were analyzed to quantify and model the sequestration reactions. The best performing solids were found to sequester between 2.3 and 2.9 moles of CO2 per kg of dry solid in 1-4 hours of reaction time. These best performing solids were cement kiln dust, circulating dry scrubber ash, and spray dryer absorber ash. A techno-economic analysis was performed to evaluate the commercial viability of the proposed carbon capture and sequestration process in full-scale at an aluminum smelter and a refinery location. For both cases the in-duct scrubber technology was compared to traditional amine- based capture. Incorporation of the laboratory results showed that for the application at the aluminum smelter, the in-duct scrubber system is more economical than traditional methods. However, the reverse is true for the refinery case, where the bauxite residue is not effective enough as a sequestrant, combined with challenges related to contaminants in the bauxite residue accumulating in and fouling the scrubber absorbent. Sensitivity analyses showed that the critical variables by which process economics could be improved are enzyme concentration, efficiency, and half-life. At the end of the first part of the Phase 2 project, a gate review (DOE Decision Zero Gate Point) was conducted to decide on the next stages of the project. The original plan was to follow the pre-testing phase with a detailed design for the field testing. Unfavorable process economics, however, resulted in a decision to conclude the project before moving to field testing. It is noted that CO2 Solutions proposed an initial solution to reduce process costs through more advanced enzyme management, however, DOE program requirements restricting any technology development extending beyond 2014 as commercial deployment timeline did not allow this solution to be undertaken.

  4. Center for Nanoscale Control of Geologic CO2 (EFRC) - Staff

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    Manager (Energy Sciences Area, LBNL) An organization chart of the Center for Nanoscale Control of Geologic CO2 Research Teams: Thrust 1: Fractured Shale Ian Bourg, Thrust 1 Lead,...

  5. co2-use-reuse | netl.doe.gov

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    provide economic benefits for fossil fuel-fired power plants or industrial processes. CO2 utilization through enhanced oil recovery (EOR) could also be pursued as a means to...

  6. Canada’s Bitumen Industry Under CO2 Constraints

    E-Print Network [OSTI]

    Chen, Y.-H. Henry

    We investigate the effects of implementing CO2 emissions reduction policies on Canada’s oil sands industry, the largest of its kind in the world. The production of petroleum products from oils sands involves extraction of ...

  7. atmospheric co2 enrichment: Topics by E-print Network

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 Next Page Last Page Topic Index 1 Soil carbon sequestration in a pine forest after 9 years of atmospheric CO2 enrichment...

  8. High Co2 Emissions Through Porous Media- Transport Mechanisms...

    Open Energy Info (EERE)

    to estimate the total magmatic or metamorphic CO2 released from such areas. To assess the performance of accumulation chamber systems at fluxes one to three orders of magnitude...

  9. Implications of "peak oil" for atmospheric CO2 and climate

    E-Print Network [OSTI]

    Kharecha, P A

    2007-01-01T23:59:59.000Z

    Peaking of global oil production may have a large effect on future atmospheric CO2 amount and climate change, depending upon choices made for subsequent energy sources. We suggest that, if estimates of oil and gas reserves by the Energy Information Administration are realistic, it is feasible to keep atmospheric CO2 from exceeding approximately 450 ppm, provided that future exploitation of the huge reservoirs of coal and unconventional fossil fuels incorporates carbon capture and sequestration. Existing coal-fired power plants, without sequestration, must be phased out before mid-century to achieve this limit on atmospheric CO2. We also suggest that it is important to "stretch" oil reserves via energy efficiency, thus avoiding the need to extract liquid fuels from coal or unconventional fossil fuels. We argue that a rising price on carbon emissions is probably needed to keep CO2 beneath the 450 ppm ceiling.

  10. Electron Transfer Dynamics in Photocatalytic CO2 Conversion ...

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    etc.) to slowly convert stored CO2 into more useful products such as methane and methanol. Photocatalysis is the acceleration of a light-induced reaction in the presence of a...

  11. International Symposium on Site Characterization for CO2 Geological Storage

    E-Print Network [OSTI]

    Tsang, Chin-Fu

    2006-01-01T23:59:59.000Z

    quantitative models enables linking risk to the failure of a specific component, for ex- ample using sensitivity analysis.analysis of the Risks associated to well leakage: aquifer contamination and CO 2 release. Quantitative

  12. THERMOCATALYTIC CO2-FREE PRODUCTION OF HYDROGEN FROM HYDROCARBON FUELS

    E-Print Network [OSTI]

    for the process efficiency. However these impurities may result in contamination of hydrogen by CO, CO2 and H2S which should be removed from the product gas using methanation and H2S scrubbing steps, respectively. 11

  13. Modeling the release of CO2 in the deep ocean

    E-Print Network [OSTI]

    Liro, Christopher R.

    1991-01-01T23:59:59.000Z

    The idea of capturing and disposing of carbon dioxide (CO2) from the flue gas of fossil fuel-fired power plants has recently received attention as a possible mitigation strategy to counteract potential global warming due ...

  14. System-level modeling for geological storage of CO2

    E-Print Network [OSTI]

    Zhang, Yingqi; Oldenburg, Curtis M.; Finsterle, Stefan; Bodvarsson, Gudmundur S.

    2006-01-01T23:59:59.000Z

    CO 2 escapes the reservoir through the abandoned well. Theof the abandoned well and the gas reservoir is calculated by4 reservoir 1.e-12 1.e-14 8.4e-4 Fracture or abandoned well

  15. International Symposium on Site Characterization for CO2 Geological Storage

    E-Print Network [OSTI]

    Tsang, Chin-Fu

    2006-01-01T23:59:59.000Z

    in depleted or abandoned oil and gas reservoirs; how- ever,abandoned wells represent a potentially direct route from reservoirabandoned in the 1930s with no barrier installed after it encountered a natural CO 2 reservoir

  16. International Symposium on Site Characterization for CO2 Geological Storage

    E-Print Network [OSTI]

    Tsang, Chin-Fu

    2006-01-01T23:59:59.000Z

    in depleted or abandoned oil and gas reservoirs; how- ever,oil well abandoned in the 1930s with no barrier installed after it encountered a natural CO 2 reservoir

  17. The geomechanics of CO2 storage in deep sedimentary formations

    E-Print Network [OSTI]

    Rutqvist, J.

    2013-01-01T23:59:59.000Z

    such as depleted oil and gas reservoirs, unminable coaltakes place in depleted oil or gas reservoirs (IAE, 2003).of CO 2 in depleted oil and gas reservoirs. J Can Pet

  18. International Symposium on Site Characterization for CO2 Geological Storage

    E-Print Network [OSTI]

    Tsang, Chin-Fu

    2006-01-01T23:59:59.000Z

    IN DEPLETED AND NEAR- DEPLETED OIL RESERVOIRS V. A. KuuskraaDEPLETED AND NEAR-DEPLETED OIL RESERVOIRS Vello A. Kuuskraaof CO 2 in a depleted oil reservoir: an overview,

  19. CO2 MONITORING FOR DEMAND CONTROLLED VENTILATION IN COMMERCIAL BUILDINGS

    E-Print Network [OSTI]

    Fisk, William J.

    2010-01-01T23:59:59.000Z

    Transactions 105(2). Emmerich, S. J. and A. K. Persily (Fisk and de Almeida 1998; Emmerich and Persily 2001), CO 2Fisk and de Almeida 1998; Emmerich and Persily 2001; Apte

  20. Bees, Balloons, Pollen Used as Novel CO2 Monitoring Approach

    Broader source: Energy.gov [DOE]

    Researchers at the Office of Fossil Energy's National Energy Technology Laboratory have discovered an innovative way to use bees, pollen, and helium-filled balloons to verify that no carbon dioxide (CO2) leaks from carbon sequestration sites.

  1. DOE Manual Studies 11 Major CO2 Geologic Storage Formations

    Broader source: Energy.gov [DOE]

    A comprehensive study of 11 geologic formations suitable for permanent underground carbon dioxide (CO2) storage is contained in a new manual issued by the U.S. Department of Energy.

  2. Novel CO2-Thickeners for Improved Mobility Control

    SciTech Connect (OSTI)

    Enick, Dr. Robert M.; Beckman, Dr. Eric J.; Hamilton, Dr. Andrew

    2002-01-15T23:59:59.000Z

    The objective of this contract was to design, synthesize, and characterize thickening agents for dense carbon dioxide and to evaluate their solubility and viscosity-enhancing potential in CO2.

  3. CO2 Emissions Mitigation and Technological Advance: An

    E-Print Network [OSTI]

    PNNL-18075 CO2 Emissions Mitigation and Technological Advance: An Updated Analysis of Advanced/2003) #12;PNNL-18075 CO2 Emissions Mitigation and Technological Advance: An Analysis of Advanced Technology electricity 16.9 29.0 44.7 65.7 89.2 114.3 145.2 174.8 EJ/yr building trad biomass 23.5 29.9 32.1 27.9 22.9 17

  4. CO2 Removal using a Synthetic Analogue of Carbonic Anhydrase

    SciTech Connect (OSTI)

    Harry Cordatos

    2010-09-14T23:59:59.000Z

    Project attempts to develop a synthetic analogue for carbonic anhydrase and incorporate it in a membrane for separation of CO2 from coal power plant flue gas. Conference poster presents result of first 9 months of project progress including concept, basic system architecture and membrane properties target, results of molecular modeling for analogue - CO2 interaction, and next steps of testing analogue resistance to flue gas contaminants.

  5. Evaluating the impact of aquifer layer properties on geomechanical response during CO2 geological sequestration

    SciTech Connect (OSTI)

    Bao, Jie; Xu, Zhijie; Lin, Guang; Fang, Yilin

    2013-04-01T23:59:59.000Z

    Numerical models play an essential role in understanding the facts of carbon dioxide (CO2) geological sequestration in the life cycle of a storage reservoir. We present a series of test cases that reflect a broad and realistic range of aquifer reservoir properties to systematically evaluate and compare the impacts on the geomechanical response to CO2 injection. In this study, a coupled hydro-mechanical model was introduced to simulate the sequestration process, and a quasi-Monte Carlo sampling method was introduced to efficiently sample the value of aquifer properties and geometry parameters. Aquifer permeability was found to be of significant importance to the geomechanical response to the injection. To study the influence of uncertainty of the permeability distribution in the aquifer, an additional series of tests is presented, based on a default permeability distribution site sample with various distribution deviations generated by the Monte Carlo sampling method. The results of the test series show that different permeability distributions significantly affect the displacement and possible failure zone.

  6. Assessment of Energy Efficiency Improvement and CO2 Emission Reduction Potentials in India's Iron and Steel Industry

    E-Print Network [OSTI]

    Morrow III, William R.

    2014-01-01T23:59:59.000Z

    Improvement and CO2 Emission Reduction Potentials in theUS $/GJ- saved) CO2 Emissions Reduction (Mt CO 2 ) CCF RankUS$/GJ- saved) CO2 Emissions Reduction (Mt CO 2 ) * The

  7. Geochemical Impacts of Leaking CO2 from Subsurface Storage Reservoirs to Unconfined and Confined Aquifers

    SciTech Connect (OSTI)

    Qafoku, Nikolla; Brown, Christopher F.; Wang, Guohui; Sullivan, E. C.; Lawter, Amanda R.; Harvey, Omar R.; Bowden, Mark

    2013-04-15T23:59:59.000Z

    Experimental research work has been conducted and is undergoing at Pacific Northwest National Laboratory (PNNL) to address a variety of scientific issues related with the potential leaks of the carbon dioxide (CO2) gas from deep storage reservoirs. The main objectives of this work are as follows: • Develop a systematic understanding of how CO2 leakage is likely to influence pertinent geochemical processes (e.g., dissolution/precipitation, sorption/desorption and redox reactions) in the aquifer sediments. • Identify prevailing environmental conditions that would dictate one geochemical outcome over another. • Gather useful information to support site selection, risk assessment, policy-making, and public education efforts associated with geological carbon sequestration. In this report, we present results from experiments conducted at PNNL to address research issues related to the main objectives of this effort. A series of batch and column experiments and solid phase characterization studies (quantitative x-ray diffraction and wet chemical extractions with a concentrated acid) were conducted with representative rocks and sediments from an unconfined, oxidizing carbonate aquifer, i.e., Edwards aquifer in Texas, and a confined aquifer, i.e., the High Plains aquifer in Kansas. These materials were exposed to a CO2 gas stream simulating CO2 gas leaking scenarios, and changes in aqueous phase pH and chemical composition were measured in liquid and effluent samples collected at pre-determined experimental times. Additional research to be conducted during the current fiscal year will further validate these results and will address other important remaining issues. Results from these experimental efforts will provide valuable insights for the development of site-specific, generation III reduced order models. In addition, results will initially serve as input parameters during model calibration runs and, ultimately, will be used to test model predictive capability and competency. The results from these investigations will provide useful information to support site selection, risk assessment, and public education efforts associated with geological, deep subsurface CO2 storage and sequestration.

  8. Carbon Dioxide Transport and Sorption Behavior in Confined Coal Cores for Enhanced Coalbed Methane and CO2 Sequestration

    SciTech Connect (OSTI)

    Jikich, S.A.; McLendon, T.R.; Seshadri, K.S.; Irdi, G.A.; Smith, D.H.

    2007-11-01T23:59:59.000Z

    Measurements of sorption isotherms and transport properties of CO2 in coal cores are important for designing enhanced coalbed methane/CO2 sequestration field projects. Sorption isotherms measured in the lab can provide the upper limit on the amount of CO2 that might be sorbed in these projects. Because sequestration sites will most likely be in unmineable coals, many of the coals will be deep and under considerable lithostatic and hydrostatic pressures. These lithostatic pressures may significantly reduce the sorption capacities and/or transport rates. Consequently, we have studied apparent sorption and diffusion in a coal core under confining pressure. A core from the important bituminous coal Pittsburgh #8 was kept under a constant, three-dimensional external stress; the sample was scanned by X-ray computer tomography (CT) before, then while it sorbed, CO2. Increases in sample density due to sorption were calculated from the CT images. Moreover, density distributions for small volume elements inside the core were calculated and analyzed. Qualitatively, the computerized tomography showed that gas sorption advanced at different rates in different regions of the core, and that diffusion and sorption progressed slowly. The amounts of CO2 sorbed were plotted vs. position (at fixed times) and vs. time (for various locations in the sample). The resulting sorption isotherms were compared to isotherms obtained from powdered coal from the same Pittsburgh #8 extended sample. The results showed that for this single coal at specified times, the apparent sorption isotherms were dependent on position of the volume element in the core and the distance from the CO2 source. Also, the calculated isotherms showed that less CO2 was sorbed than by a powdered (and unconfined) sample of the coal. Changes in density distributions during the experiment were also observed. After desorption, the density distribution of calculated volume elements differed from the initial distribution, suggesting hysteresis and a possible rearrangement of coal structure due to CO2 sorption.

  9. Inventory of Carbon Dioxide (CO2) Emissions at Pacific Northwest National Laboratory

    SciTech Connect (OSTI)

    Judd, Kathleen S.; Kora, Angela R.; Shankle, Steve A.; Fowler, Kimberly M.

    2009-06-29T23:59:59.000Z

    The Carbon Management Strategic Initiative (CMSI) is a lab-wide initiative to position the Pacific Northwest National Laboratory (PNNL) as a leader in science, technology and policy analysis required to understand, mitigate and adapt to global climate change as a nation. As part of an effort to walk the talk in the field of carbon management, PNNL conducted its first carbon dioxide (CO2) emissions inventory for the 2007 calendar year. The goal of this preliminary inventory is to provide PNNL staff and management with a sense for the relative impact different activities at PNNL have on the lab’s total carbon footprint.

  10. Dynamic micro-mapping of CO2 sorption in coal

    SciTech Connect (OSTI)

    Radlinski, Andrzej Pawell [ORNL; Melnichenko, Yuri B [ORNL; Cheng, Gang [ORNL; Mastalerz, Maria [Indiana Geological Survey

    2009-01-01T23:59:59.000Z

    We have applied X-ray and neutron small-angle scattering techniques (SAXS, SANS and USANS) to study the interaction between fluids and porous media in the particular case of sub- and super-critical CO2 sorption in coal. These techniques are demonstrated to give unique, pore-size-specific insights into the kinetics of CO2 sorption in a wide range of coal pores (nano to meso), and to provide data that may be used to determine the density of the sorbed CO2. We observed densification of the adsorbed CO2 by a factor up to five compared to the free fluid at the same (p,T) conditions. Our results indicate that details of CO2 sorption into coal pores differ greatly between different coals and depend on the amount of mineral matter dispersed in the coal matrix: a purely organic matrix absorbs more CO2 per unit volume than one contaminated with mineral matter, but mineral matter markedly accelerates the sorption kinetics.

  11. CO2 leakage up from a geological storage site to shallow fresh groundwater: CO2-water-rock interaction assessment and

    E-Print Network [OSTI]

    Paris-Sud XI, Université de

    CO2 leakage up from a geological storage site to shallow fresh groundwater: CO2-water repository requires the investigation of the potential CO2 leakage back into fresh groundwater, particularly sensitive monitoring techniques in order to detect potential CO2 leaks and their magnitude as well

  12. ECONOMIC EVALUATION OF CO2 SEQUESTRATION TECHNOLOGIES

    SciTech Connect (OSTI)

    Bert R. Bock; Richard G. Rhudy; David E. Nichols

    2001-07-01T23:59:59.000Z

    In order to plan for potential CO{sub 2} mitigation mandates, utilities need better information on CO{sub 2} mitigation options, especially carbon sequestration options that involve non-utility operations. One of the major difficulties in evaluating CO{sub 2} sequestration technologies and practices, both geologic storage of captured CO{sub 2} and storage in biological sinks, is obtaining consistent, transparent, accurate, and comparable economics. This project is comparing the economics of major technologies and practices under development for CO{sub 2} sequestration, including captured CO{sub 2} storage options such as active oil reservoirs, depleted oil and gas reservoirs, deep aquifers, coal beds, and oceans, as well as the enhancement of biological sinks such as forests and croplands. An international group of experts has been assembled to compare on a consistent basis the economics of this diverse array of CO{sub 2} sequestration options. Designs and data collection are nearly complete for each of the CO{sub 2} sequestration options being compared. Initial spreadsheet development has begun on concepts involving storage of captured CO{sub 2}. No significant problems have been encountered, but some additional outside expertise will be accessed to supplement the team's expertise in the areas of life cycle analysis, oil and gas exploration and production, and comparing CO{sub 2} sequestration options that differ in timing and permanence of CO{sub 2} sequestration. Plans for the next reporting period are to complete data collection and a first approximation of the spreadsheet. We expect to complete this project on time and on budget.

  13. Intracranial Pressure Variation Associated with Changes in End-Tidal CO2

    E-Print Network [OSTI]

    Intracranial Pressure Variation Associated with Changes in End-Tidal CO2 Sunghan Kim, James Mc that the partial pressure of arterial CO2 (PaCO2) can affect cerebral blood flow, cerebral blood volume, and therefore ICP. The end-tidal CO2 (ETCO2) is usually monitored by clinicians as a proxy for PaCO2. We show

  14. Enhanced Practical Photosynthetic CO2 Mitigation

    SciTech Connect (OSTI)

    Gregory Kremer; David J. Bayless; Morgan Vis; Michael Prudich; Keith Cooksey; Jeff Muhs

    2006-01-15T23:59:59.000Z

    This final report highlights significant achievements in the Enhanced Practical Photosynthetic CO{sub 2} Mitigation Project during the period from 10/1/2001 through 01/02/2006. As indicated in the list of accomplishments below, our efforts during this project were focused on the selection of candidate organisms and growth surfaces and initiating long-term tests in the bench-scale and pilot-scale bioreactor test systems. Specific results and accomplishments for the program include: (1) CRF-2 test system: (a) Sampling test results have shown that the initial mass of algae loaded into the Carbon Recycling Facility Version 2 (CRF-2) system can be estimated with about 3% uncertainty using a statistical sampling procedure. (b) The pressure shim header pipe insert design was shown to have better flow for harvesting than the drilled-hole design. (c) The CRF-2 test system has undergone major improvements to produce the high flow rates needed for harvesting (as determined by previous experiments). The main changes to the system are new stainless steel header/frame units, with increased flow capacity and a modified pipe-end-sealing method to improve flow uniformity, and installation and plumbing for a new high flow harvesting pump. Qualitative system tests showed that the harvesting system performed wonderfully, cleaning the growth surfaces within a matter of seconds. (d) Qualitative tests have shown that organisms can be repopulated on a harvested section of a bioreactor screen, demonstrating that continuous bioreactor operation is feasible, with continuous cycles of harvesting and repopulating screens. (e) Final preparations are underway for quantitative, long-term tests in the CRF-2 with weekly harvesting. (2) Pilot-scale test system: (a) The construction of the pilot-scale bioreactor was completed, including the solar collector and light distribution system. Over the course of the project, the solar collector used in the light delivery system showed some degradation, but performed well overall. (b) Testing confirmed that algae can be grown in a sustainable fashion in the pilot bioreactor, even with intermittent availability of sunlight. (c) The pilot-scale tests indicated that algal growth rate followed photon delivery during productivity testing. (3) Organisms and Growth Surfaces: (a) The aeration of growth media with 5% CO{sub 2} in air stimulates cyanobacterial growth 10-20 times over that with air alone. It is possible that the rate of the stimulation of cyanobacterial growth in the CRF will be higher because cyanobacteria will be grown as a biofilm. We plan to increase the concentration to 15% CO{sub 2} in air. (b) Tests have shown a doubling time of the cyanobacterial culture of about 7.5 hours with illumination of about 170 {micro}mol m{sup -2} sec{sup -1}. All lower levels of illumination led to a decrease in the cyanobacterial growth rate. (c) Macroscopical and microscopical observations suggest that the culture of this isolate undergoes significant morphological changes after 60-70 hours of incubation in the batch culture mode. First of all, the culture begins to clump. This clumping could lead to the decrease of effective illumination of culture and may reflect a medium alkalinization. (d) Organization of our collection of the thermophilic cyanobacteria isolated from Yellowstone National Park has resulted in 13 unialgal cultures of thermophilic cyanobacteria. (e) A new species (even probably a new genus) of cyanobacteria, 5.2 s. c. 1, isolated from LaDuke Spring in Great Yellowstone Basin, demonstrates an elevated resistance to some compounds of iron. This might be very important for our project, because plant gases may have elevated amount of iron. Our study of the effect of different concentration of FeCl{sub 3}* 6H{sub 2}O on the growth of the 5.2 s.c.1 isolate showed that iron additions stimulated rather then inhibited the growth of the isolate. Because of this we would recommend this isolate for further experiments. (f) The shape of the Chlorogloeopsis siderophila cells (cyanobacteria) was found to be affected b

  15. Abstract Atmospheric CO2 partial pressure (pCO2) was as low as 18 Pa during the Pleistocene and is projected to

    E-Print Network [OSTI]

    Antonovics, Janis

    Abstract Atmospheric CO2 partial pressure (pCO2) was as low as 18 Pa during the Pleistocene and is projected to increase from 36 to 70 Pa CO2 before the end of the 21st century. High pCO2 often increases the growth and repro- duction of C3 annuals, whereas low pCO2 decreases growth and may reduce or prevent

  16. Impact of Sorption Isotherms on the Simulation of CO2-Enhanced Gas Recovery and Storage Process in Marcellus Shale

    E-Print Network [OSTI]

    Mohaghegh, Shahab

    initiatives to develop carbon management technologies, including geologic sequestration of CO2. At present of how much carbon dioxide or methane can be stored in shale at a given pressure. In this paper, a shale to identify the impact of both methane and carbon dioxide sorption isotherms on cumulative methane production

  17. Joule-Thomson Cooling Due to CO2 Injection into Natural Gas Reservoirs

    E-Print Network [OSTI]

    Oldenburg, Curtis M.

    2006-01-01T23:59:59.000Z

    include the freezing of residual water or the formation ofby the freezing of residual water, formation of hydrates,a depleted reservoir that residual water could freeze and/or

  18. Coupled reservoir-geomechanical analysis of CO2 injection and ground deformations at In Salah, Algeria

    E-Print Network [OSTI]

    Rutqvist, J.

    2010-01-01T23:59:59.000Z

    we use field data and coupled reservoir-geomechanicaldistance change data for monitoring the reservoir during COReservoir monitoring and characterization using satellite geodetic data:

  19. Carbon Storage Partner Completes First Year of CO2 Injection Operations in

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Home Page on Google Bookmark EERE: Alternative Fuels Data Center Home Page onYouTube YouTube Note: Since the YouTube platformBuilding RemovalCSS Letter -SeptemberWorkshopby: Alan Liby,Illinois |

  20. Illinois CO2 Injection Project Moves Another Step Forward | Department of

    Broader source: Energy.gov (indexed) [DOE]

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative1 First Use of Energy for All Purposes (Fuel and Nonfuel), 2002; Level: National5Sales for4,645 3,625 1,006 492 742Energy ChinaofSchaefer To:Department ofOralGovernmentStandardsIdahoby4 AUDIT REPORT1

  1. Carbon Storage Partner Completes First Year of CO2 Injection Operations in

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Home Page on Google Bookmark EERE: Alternative Fuels DataDepartment of Energy Your Density Isn't Your Destiny: Theof Energy Change RequestFirst Report to the PrimePilotAwards |

  2. Ancient Lava Flows Trap CO2 for Long-Term Storage in Big Sky Injection |

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Home Page on Google Bookmark EERE: Alternative Fuels DataDepartment of Energy Your Density Isn't Your Destiny: The Future of1Albuquerque, NMPerformanceof Energy4 * August 2004Anatomy of

  3. Inventory of China's Energy-Related CO2 Emissions in 2008

    E-Print Network [OSTI]

    Fridley, David

    2011-01-01T23:59:59.000Z

    China’s 2008 Thermal Electricity Sector CO 2 Emissions byheat. Share of thermal electricity sector’s CO 2 emissionsheat. Share of thermal electricity sector’s CO 2 emissions

  4. Leakage of CO2 from geologic storage: Role of secondary accumulation at shallow depth

    E-Print Network [OSTI]

    Pruess, K.

    2008-01-01T23:59:59.000Z

    Large Releases from CO2 Storage Reservoirs: Analogs,S.T. Nelson. Natural Leaking CO2-charged Systems as AnalogsY. Sano, and H.U. Schmincke. CO2-rich Gases from Lakes Nyos

  5. On CO2 Behavior in the Subsurface, Following Leakage from a Geologic Storage Reservoir

    E-Print Network [OSTI]

    Pruess, Karsten

    2006-01-01T23:59:59.000Z

    1 - 16, 1987. Skinner, L. CO2 Blowouts: An Emerging Problem,Assessment for Underground CO2 Storage, paper 234, presentedReservoir Performance Risk in CO2 Storage Projects, paper

  6. Regulation, Allocation, and Leakage in Cap-and-Trade Markets for CO2

    E-Print Network [OSTI]

    Bushnell, Jim B; Chen, Yihsu

    2009-01-01T23:59:59.000Z

    and Philippe Quirion. Co2 abatement, competitiveness andDaniel Kahn. Allocation of co2 emissions al- lowances in theA short-run case analysis of co2 leakage and nox and so2

  7. A Theoretical Study of CO2 Anions on Anatase (101) Surface. ...

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    Publications A Theoretical Study of CO2 Anions on Anatase (101) Surface. A Theoretical Study of CO2 Anions on Anatase (101) Surface. Abstract: Binding configurations of CO2 and...

  8. Does low stomatal conductance or photosynthetic capacity enhance growth at elevated CO2 in Arabidopsis thaliana?

    E-Print Network [OSTI]

    Easlon, Hsien M; Carlisle, Eli; McKay, John K; Bloom, Arnold J

    2015-01-01T23:59:59.000Z

    enhance growth at elevated CO 2 ? To whom correspondence mayDoes low g enhance growth at elevated CO 2 ? Does lowenhance growth at elevated CO 2 in Arabidopsis thaliana?

  9. Single-well Low Temperature CO2- based Engineered Geothemal System...

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    Single-well Low Temperature CO2- based Engineered Geothemal System Single-well Low Temperature CO2- based Engineered Geothemal System Single-well Low Temperature CO2- based...

  10. Inventory of China's Energy-Related CO2 Emissions in 2008

    E-Print Network [OSTI]

    Fridley, David

    2011-01-01T23:59:59.000Z

    China's 2008 Total CO 2 Emissions from Energy Consumption:10. China's 2008 Total CO 2 Emissions from Energy: Sectoral16 Table 11. China's 2008 CO 2 Emissions from Energy:

  11. Automobile Fuel; Economy and CO2 Emissions in Industrialized Countries: Troubling Trends through 2005/6

    E-Print Network [OSTI]

    Schipper, Lee

    2008-01-01T23:59:59.000Z

    Energy Savings and CO2 Emissions Implications. J. ofcommitment to reduce CO2 emissions from new passenger carsACEA’s Commitment on CO2 Emission Reductions from Passenger

  12. Regulation, Allocation, and Leakage in Cap-and-Trade Markets for CO2

    E-Print Network [OSTI]

    Bushnell, Jim B; Chen, Yihsu

    2009-01-01T23:59:59.000Z

    Daniel Kahn. Allocation of co2 emissions al- lowances in theRasmussen. Allocation of co2 emissions permits: A generalthe aggregate annual CO2 emissions for each of the key

  13. Potential Energy Savings and CO2 Emissions Reduction of China's Cement Industry

    E-Print Network [OSTI]

    Ke, Jing

    2013-01-01T23:59:59.000Z

    2050 China Energy and CO2 Emissions Report. Science Press,Energy Savings and CO2 Emissions Reduction of China’s CementEnergy Savings and CO2 Emissions Reduction of China’s Cement

  14. Inventory of China's Energy-Related CO2 Emissions in 2008

    E-Print Network [OSTI]

    Fridley, David

    2011-01-01T23:59:59.000Z

    of unadjusted energy-related CO2 emissions is attributed toEMISSIONS- T C EMISSIONS -T CO2 TOTAL Energy EmissionsEMISSIONS- T C EMISSIONS -T CO2 Coal Coke and Other

  15. What Can China Do? China's Best Alternative Outcome for Energy Efficiency and CO2 Emissions

    E-Print Network [OSTI]

    G. Fridley, David

    2010-01-01T23:59:59.000Z

    China Energy and CO2 Emissions Report (CEACER). Beijing:Oil consumption and CO2 emissions in China’s road transport:Growth, Oil Demand and CO2 Emissions through 2050. Report

  16. Challenges and opportunities in accounting for non-energy use CO2 emissions: an editorial comment

    E-Print Network [OSTI]

    Masanet, Eric; Sathaye, Jayant

    2009-01-01T23:59:59.000Z

    carbon dioxide (NEU-CO2) emissions, represent a signi?cantSimply described, NEU-CO2 emissions are generated via twoData permitting, NEU-CO2 emissions arising from energy

  17. Potential Energy Savings and CO2 Emissions Reduction of China's Cement Industry

    E-Print Network [OSTI]

    Ke, Jing

    2013-01-01T23:59:59.000Z

    Energy Savings and CO2 Emissions Reduction of China’s CementEnergy Savings and CO2 Emissions Reduction of China’s Cementenergy savings and CO2 emission reduction potentials are

  18. CO2-selective, Hybrid Membranes by Silation of Alumina

    SciTech Connect (OSTI)

    Luebke, D.R.; Pennline, H.W.

    2007-09-01T23:59:59.000Z

    Hybrid membranes are feasible candidates for the separation of CO2 from gas produced in coal-based power generation since they have the potential to combine the high selectivity of polymer membranes and the high permeability of inorganic membranes. An interesting method for producing hybrid membranes is the silation of an inorganic membrane. In this method, trichloro- or alkoxy-silanes interact with hydroxyl groups on the surface of ?-AlO3 or TiO2, binding organic groups to that surface. By varying the length of these organic groups on the organosilane, it should be possible to tailor the effective pore size of the membrane. Similarly, the addition of “CO2-phillic” groups to the silating agent allows for the careful control of surface affinity and the enhancement of surface diffusion mechanisms. This method of producing hybrid membranes selective to CO2 was first attempted by Hyun [1] who silated TiO2 with phenyltriethoxysilane. Later, Way [2] silated ?-AlO3 with octadecyltrichlorosilane. Both researchers were successful in producing membranes with improved selectivity toward CO2, but permeability was not maintained at a commercially applicable level. XPS data indicated that the silating agent did not penetrate into the membrane pores and separation actually occurred in a thin “polymer-like” surface layer. The present study attempts to overcome the mass transfer problems associated with this technique by producing the desired monolayer coverage of silane, and thus develop a highly-permeable CO2-selective hybrid membrane.

  19. CATALYST CATALYSTADSORBENT ADSORBENT HCS + H2O H2 + CO2

    E-Print Network [OSTI]

    Southern California, University of

    - CO2 Adsorbent Effect of Membrane Properties On HAMR performance 3.190.3883--H2O --54.30.0248Ar --67 CATALYST CATALYSTADSORBENT ADSORBENT C O 2CO2 CO2 CO2 HCS + H2O H2 + CO2 Mork Family Department of Chemical using hydrotalcite-type CO2 adsorbents and nanoporous H2-selective carbon molecular sieve membranes (CMS

  20. Thermal desorption of CH4 retained in CO2 ice

    E-Print Network [OSTI]

    R. Luna; C. Millan; M. Domingo; M. A. Satorre

    2008-01-21T23:59:59.000Z

    CO2 ices are known to exist in different astrophysical environments. In spite of this, its physical properties (structure, density, refractive index) have not been as widely studied as those of water ice. It would be of great value to study the adsorption properties of this ice in conditions related to astrophysical environments. In this paper, we explore the possibility that CO2 traps relevant molecules in astrophysical environments at temperatures higher than expected from their characteristic sublimation point. To fulfil this aim we have carried out desorption experiments under High Vacuum conditions based on a Quartz Crystal Microbalance and additionally monitored with a Quadrupole Mass Spectrometer. From our results, the presence of CH4 in the solid phase above the sublimation temperature in some astrophysical scenarios could be explained by the presence of several retaining mechanisms related to the structure of CO2 ice.

  1. Thermal desorption of CH4 retained in CO2 ice

    E-Print Network [OSTI]

    Luna, R; Domingo, M; Satorre, M A

    2008-01-01T23:59:59.000Z

    CO2 ices are known to exist in different astrophysical environments. In spite of this, its physical properties (structure, density, refractive index) have not been as widely studied as those of water ice. It would be of great value to study the adsorption properties of this ice in conditions related to astrophysical environments. In this paper, we explore the possibility that CO2 traps relevant molecules in astrophysical environments at temperatures higher than expected from their characteristic sublimation point. To fulfil this aim we have carried out desorption experiments under High Vacuum conditions based on a Quartz Crystal Microbalance and additionally monitored with a Quadrupole Mass Spectrometer. From our results, the presence of CH4 in the solid phase above the sublimation temperature in some astrophysical scenarios could be explained by the presence of several retaining mechanisms related to the structure of CO2 ice.

  2. air-sea co2 flux: Topics by E-print Network

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    into the potential behavior and the operational parameters of CO2 sequestration at CO2-EOR s... Dai, Zhenxue; Fessenden-Rahn, Julianna; Middleton, Richard; Pan, Feng; Jia,...

  3. The Influence of a CO2 Pricing Scheme on Distributed Energy Resources in California's Commercial Buildings

    E-Print Network [OSTI]

    Stadler, Michael

    2010-01-01T23:59:59.000Z

    The Influence of a CO2 Pricing Scheme on Distributed Energy5. Regional Results for the CO2 Pricing Scheme no-invest

  4. New Directions: Potential Climate and Productivity Benefits from CO2 Capture in Commercial Buildings

    E-Print Network [OSTI]

    Gall, Elliott T; Nazaroff, William W

    2015-01-01T23:59:59.000Z

    air capture technologies. Although the carbon in metaboliccarbon footprint of commercial build- ings through active CO 2 capture. For dilute CO 2 levels, adsorption technologies

  5. Diesel Passenger Car Technology for Low Emissions and CO2 Compliance...

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    Passenger Car Technology for Low Emissions and CO2 Compliance Diesel Passenger Car Technology for Low Emissions and CO2 Compliance Cost effective reduction of legislated emissions...

  6. Potential Energy Savings and CO2 Emissions Reduction of China's Cement Industry

    E-Print Network [OSTI]

    Ke, Jing

    2013-01-01T23:59:59.000Z

    The CO2 emissions from external production of electricityCO2) emissions from fossil fuel combustion, as well as the consumption of large amount of electricity,

  7. Potential Energy Savings and CO2 Emissions Reduction of China's Cement Industry

    E-Print Network [OSTI]

    Ke, Jing

    2013-01-01T23:59:59.000Z

    dioxide (CO2) emissions from fossil fuel combustion, as wellCO2 emissions (including cement process and fossil fuel combustion

  8. Use of experience curves to estimate the future cost of power plants with CO2 capture

    E-Print Network [OSTI]

    Rubin, Edward S.; Yeh, Sonia; Antes, Matt; Berkenpas, Michael; Davison, John

    2007-01-01T23:59:59.000Z

    2004. Experience curves for power plant emission controlassessments of fossil fuel power plants with CO 2 capturethe future cost of power plants with CO 2 capture Edward S.

  9. Leakage of CO2 from geologic storage: Role of secondary accumulation at shallow depth

    E-Print Network [OSTI]

    Pruess, K.

    2008-01-01T23:59:59.000Z

    adiabatic (= no external heat supply) expansion of CO 2 toCO 2 without external heat supply will cause temperatures toenables more sustained heat supply from the surroundings,

  10. Automobile Fuel; Economy and CO2 Emissions in Industrialized Countries: Troubling Trends through 2005/6

    E-Print Network [OSTI]

    Schipper, Lee

    2008-01-01T23:59:59.000Z

    s Commitment on CO2 Emission Reductions from Passenger Cars.is a small extra reduction in CO2 emissions per km due to a

  11. Fuel injection

    SciTech Connect (OSTI)

    Iiyoshi, A.; Vogoshi, S.

    1983-12-01T23:59:59.000Z

    The Plasma Physics Laboratory and the Dept. of Electrical Engineering report on three types of pellet injectors which have different applications: injection of a pellet into a magnetic bottle for magnetic confinement; injection of a pellet into a vacuum chamber for an inertial confinement experiment; and injection of a pellet into a magnetic bottle where the pellet is ionized by high-power laser irradiation for target plasma production. The requirements of pellet injectors are summarized in a table. Theoretical studies on pellet ablation in hot plasma and ablated particle diffusion are underway.

  12. A Review of Emerging Energy-efficiency and CO2 Emission-reduction Technologies for Cement and Concrete Production

    E-Print Network [OSTI]

    Hasanbeigi, Ali

    2014-01-01T23:59:59.000Z

    efficiency and CO2 Emission-reduction Technologies forefficiency and CO2 Emission- reduction Technologies forefficiency and CO2 Emission-reduction Technologies The

  13. Stoichiometry and temperature sensitivity of methanogenesis and CO2 production from saturated polygonal tundra in Barrow, Alaska

    SciTech Connect (OSTI)

    Roy Chowdhury, Taniya [ORNL; Herndon, Elizabeth M [ORNL; Phelps, Tommy Joe [ORNL; Elias, Dwayne A [ORNL; Gu, Baohua [ORNL; Liang, Liyuan [ORNL; Wullschleger, Stan D [ORNL; Graham, David E [ORNL

    2015-01-01T23:59:59.000Z

    Arctic permafrost ecosystems store ~50% of global belowground carbon (C) that is vulnerable to increased microbial degradation with warmer active layer temperatures and thawing of the near surface permafrost. We used anoxic laboratory incubations to estimate anaerobic CO2 production and methanogenesis in active layer (organic and mineral soil horizons) and permafrost samples from center, ridge and trough positions of water-saturated low-centered polygon in Barrow Environmental Observatory, Barrow AK, USA. Methane (CH4) and CO2 production rates and concentrations were determined at 2, +4, or +8 C for 60 day incubation period. Temporal dynamics of CO2 production and methanogenesis at 2 C showed evidence of fundamentally different mechanisms of substrate limitation and inhibited microbial growth at soil water freezing points compared to warmer temperatures. Nonlinear regression better modeled the initial rates and estimates of Q10 values for CO2 that showed higher sensitivity in the organic-rich soils of polygon center and trough than the relatively drier ridge soils. Methanogenesis generally exhibited a lag phase in the mineral soils that was significantly longer at 2 C in all horizons. Such discontinuity in CH4 production between 2 C and the elevated temperatures (+4 and +8 C) indicated the insufficient representation of methanogenesis on the basis of Q10 values estimated from both linear and nonlinear models. Production rates for both CH4 and CO2 were substantially higher in organic horizons (20% to 40% wt. C) at all temperatures relative to mineral horizons (<20% wt. C). Permafrost horizon (~12% wt. C) produced ~5-fold less CO2 than the active layer and negligible CH4. High concentrations of initial exchangeable Fe(II) and increasing accumulation rates signified the role of iron as terminal electron acceptors for anaerobic C degradation in the mineral horizons.

  14. NOVEL CONCEPTS RESEARCH IN GEOLOGIC STORAGE OF CO2 PHASE III THE OHIO RIVER VALLEY CO2 STORAGE PROJECT

    SciTech Connect (OSTI)

    Neeraj Gupta

    2005-05-26T23:59:59.000Z

    As part of the Department of Energy's (DOE) initiation on developing new technologies for storage of carbon dioxide in geologic reservoir, Battelle has been awarded a project to investigate the feasibility of CO{sub 2} sequestration in the deep saline reservoirs in the Ohio River Valley region. This project is the Phase III of Battelle's work under the Novel Concepts in Greenhouse Gas Management grant. The main objective of the project is to demonstrate that CO{sub 2} sequestration in deep formations is feasible from engineering and economic perspectives, as well as being an inherently safe practice and one that will be acceptable to the public. In addition, the project is designed to evaluate the geology of deep formations in the Ohio River Valley region in general and in the vicinity of AEP's Mountaineer Power Plant in particular, in order to determine their potential use for conducting a long-term test of CO{sub 2} disposal in deep saline formations and potentially in nearby deep coal seams. The current technical progress report summarizes activities completed for the January through March 2005 period of the project. As discussed in the report, the technical activities focused on development of injection well design, preparing a Class V Underground Injection Control permit, assessment of monitoring technologies, analysis of coal samples for testing the capture system by Mitsubishi Heavy Industry, and presentation of project progress at several venues. In addition, related work has progressed on a collaborative risk assessment project with Japan research institute CREIPI and technical application for the Midwest Regional Carbon Sequestration Partnership.

  15. High Fidelity Computational Analysis of CO2 Trapping at Pore Scales

    SciTech Connect (OSTI)

    Kumar, Vinod

    2013-07-13T23:59:59.000Z

    With an alarming rise in carbon dioxide (CO2) emission from anthropogenic sources, CO2 sequestration has become an attractive choice to mitigate the emission. Some popular storage media for CO{sub 2} are oil reservoirs, deep coal-bed, and deep oceanic-beds. These have been used for the long term CO{sub 2} storage. Due to special lowering viscosity and surface tension property of CO{sub 2}, it has been widely used for enhanced oil recovery. The sites for CO{sub 2} sequestration or enhanced oil recovery mostly consist of porous rocks. Lack of knowledge of molecular mobility under confinement and molecule-surface interactions between CO2 and natural porous media results in generally governed by unpredictable absorption kinetics and total absorption capacity for injected fluids, and therefore, constitutes barriers to the deployment of this technology. Therefore, it is important to understand the flow dynamics of CO{sub 2} through the porous microstructures at the finest scale (pore-scale) to accurately predict the storage potential and long-term dynamics of the sequestered CO{sub 2}. This report discusses about pore-network flow modeling approach using variational method and analyzes simulated results this method simulations at pore-scales for idealized network and using Berea Sandstone CT scanned images. Variational method provides a promising way to study the kinetic behavior and storage potential at the pore scale in the presence of other phases. The current study validates variational solutions for single and two-phase Newtonian and single phase non-Newtonian flow through angular pores for special geometries whose analytical and/or empirical solutions are known. The hydraulic conductance for single phase flow through a triangular duct was also validated against empirical results derived from lubricant theory.

  16. Evaluation of the environmental viability of direct injection schemes for ocean carbon sequestration

    E-Print Network [OSTI]

    Israelsson, Peter H. (Peter Hampus), 1973-

    2008-01-01T23:59:59.000Z

    This thesis evaluates the expected impact of several promising schemes for ocean carbon sequestration by direct injection of CO2, and serves as an update to the assessment by Auerbach et al. (1997) and Caulfield et al. ...

  17. THERMOCATALYTIC CO2-FREE PRODUCTION OF HYDROGEN FROM

    E-Print Network [OSTI]

    remain limited .... until some cost effective carbon sequestration option for distributed production production of hydrogen and carbon from hydrocarbon fuels with minimal CO2 emissions. Relevance. It is significantly more challenging to cost effectively sequester these [distributed] smaller volume carbon emissions

  18. CHARACTERIZATION OF MIXED CO2-TBPB HYDRATE FOR REFRIGERATION APPLICATIONS

    E-Print Network [OSTI]

    Paris-Sud XI, Université de

    CHARACTERIZATION OF MIXED CO2-TBPB HYDRATE FOR REFRIGERATION APPLICATIONS Pascal Clain , Anthony storage and distribution in refrigeration applications. Previous studies show that these hydrates are able.s] INTRODUCTION Secondary refrigeration is a method using a neutral fluid for cold distribution in order

  19. Carbonation: An Efficient and Economical Process for CO2 Sequestration

    E-Print Network [OSTI]

    Wisconsin-Milwaukee, University of

    Carbonation: An Efficient and Economical Process for CO2 Sequestration Tarun R Naik1 and Rakesh sequestration. Most of the studies related to the carbonation are limited to its effects on corrosion. The possibility of using carbonation process as a direct means for carbon dioxide sequestration is yet

  20. SecuestrodeCO2enestructurasgeolgicas Modelacin numrica de

    E-Print Network [OSTI]

    Politècnica de Catalunya, Universitat

    Kioto Responsables del 55% de las emisiones se comprometen reducir en 5% el total de emisiones respecto forma diferente A España le corresponde no aumentar en mas de 15% sus emisiones respecto a 1990 En 2006enestructurasgeológicas Una forma de disminuir emisiones: Almacenamiento de CO2 en estructuras geológicas Yacimientos de

  1. Challenges in elevated CO2 experiments on forests

    E-Print Network [OSTI]

    , Bangor, UK 8 Queens College, City University of New York, NY, USA 9 Lund University, Lund, Sweden 10 concentrations in future experiments to better predict the effects of climate change? Plantations and natural. Forest ecosystems under climate change Carbon dioxide (CO2) is the most important greenhouse gas emitted

  2. CO2 as a raw material for chemistry : an

    E-Print Network [OSTI]

    Canet, Léonie

    to chemical products capable of being energy vectors (CH3OH, CH3OCH3, EtOH, ... ) · Access to chemical intermediates from biomass · CO2 accelerates production of biomass · Ex microalgae biofuel, chemicals, .. · Ex energy: 803 kJ/mol ( 192 kcal/mol) #12;Paris, 09/07/20139 Chemical valorisations : an industrial

  3. Reduction of CO2 emissions and utilization of slag

    E-Print Network [OSTI]

    Zevenhoven, Ron

    emissions is 314 #12;CO2 sequestration by mineral carbonation. Con- crete and steel manufacturers produce from carbonate-free slag products (Slag2PCC Plus) Hiilidioksidipäästöjen vähentäminen ja Email: ron.zevenhoven@abo.fi Abstract By producing precipitated calcium carbonate (PCC) from a carbonate

  4. Developing a monitoring and verification plan with reference to the Australian Otway CO2 pilot project

    SciTech Connect (OSTI)

    Dodds, K.; Daley, T.; Freifeld, B.; Urosevic, M.; Kepic, A.; Sharma, S.

    2009-05-01T23:59:59.000Z

    The Australian Cooperative Research Centre for Greenhouse Gas Technologies (CO2CRC) is currently injecting 100,000 tons of CO{sub 2} in a large-scale test of storage technology in a pilot project in southeastern Australia called the CO2CRC Otway Project. The Otway Basin, with its natural CO{sub 2} accumulations and many depleted gas fields, offers an appropriate site for such a pilot project. An 80% CO{sub 2} stream is produced from a well (Buttress) near the depleted gas reservoir (Naylor) used for storage (Figure 1). The goal of this project is to demonstrate that CO{sub 2} can be safely transported, stored underground, and its behavior tracked and monitored. The monitoring and verification framework has been developed to monitor for the presence and behavior of CO{sub 2} in the subsurface reservoir, near surface, and atmosphere. This monitoring framework addresses areas, identified by a rigorous risk assessment, to verify conformance to clearly identifiable performance criteria. These criteria have been agreed with the regulatory authorities to manage the project through all phases addressing responsibilities, liabilities, and to assure the public of safe storage.

  5. ACID GASES IN CO2-RICH SUBSURFACE GEOLOGIC ENVIRONMENTS

    SciTech Connect (OSTI)

    Chialvo, Ariel A [ORNL] [ORNL; Vlcek, Lukas [ORNL] [ORNL; Cole, David [Ohio State University] [Ohio State University

    2013-01-01T23:59:59.000Z

    The analysis of species behavior involving dilute fluid environments has been crucial for the advance of modern solvation thermodynamics through molecular-based formalisms to guide the development of macroscopic regression tools in the description of fluid behavior and correlation of experimental data (Chialvo 2013). Dilute fluid environments involving geologic formations are of great theoretical and practical relevance regardless of the thermodynamic state conditions. The most challenging systems are those involving highly compressible and reactive confined environments, i.e., where small perturbations of pressure and/or temperature can trigger considerable density changes. This in turn can alter significantly the species solvation, their preferential solvation, and consequently, their reactivity with one another and with the surrounding mineral surfaces whose outcome is the modification of the substrate porosity and permeability, and ultimately, the integrity of the mineral substrates. Considering that changes in porosity and permeability resulting from dissolution and precipitation phenomena in confined environments are at the core of the aqueous CO2-mineral interactions, and that caprock integrity (e.g., sealing capacity) depends on these key parameters, it is imperative to gain fundamental understanding of the mineral-fluid interfacial phenomena and fluid-fluid equilibria under mineral confinement at subsurface conditions. In order to undertand the potential effects of acid gases as contaminants of supercritical CO2 streams, in the next section we will discuss the thermodynamic behavior of CO2 fluid systems by addressing two crucial issues in the context of carbon capture, utilization and sequestration (CCUS) technologies: (i) Why should we consider (acid gas) CO2 impurities? and (ii) Why are CO2 fluid - mineral interactions of paramount relevance?

  6. In Situ Study of CO2 and H2O Partitioning Between Na-Montmorillonite and Variably Wet Supercritical Carbon Dioxide

    SciTech Connect (OSTI)

    Loring, John S.; Ilton, Eugene S.; Chen, Jeffrey; Thompson, Christopher J.; Martin, Paul F.; Benezeth, Pascale; Rosso, Kevin M.; Felmy, Andrew R.; Schaef, Herbert T.

    2014-06-03T23:59:59.000Z

    Shale formations play fundamental roles in large-scale geologic carbon sequestration (GCS) aimed primarily to mitigate climate change, and in smaller-scale GCS targeted mainly for CO2-enhanced gas recovery operations. In both technologies, CO2 is injected underground as a supercritical fluid (scCO2), where interactions with shale minerals could influence successful GCS implementation. Reactive components of shales include expandable clays, such as montmorillonites and mixed-layer illite/smectite clays. In this work, we used in situ X-ray diffraction (XRD) and in situ infrared (IR) spectroscopy to investigate the swelling/shrinkage and water/CO2 sorption of a pure montmorillonite, Na-SWy-2, when the clay is exposed to variably hydrated scCO2 at 50 °C and 90 bar. Measured interlayer spacings and sorbed water concentrations at varying levels of scCO2 hydration are similar to previously reported values measured in air at ambient pressure over a range of relative humidities. IR spectra show evidence of both water and CO2 intercalation, and variations in peak shapes and positions suggest multiple sorbed types with distinct chemical environments. Based on the intensity of the asymmetric CO stretching band of the CO2 associated with the Na-SWy-2, we observed a significant increase in sorbed CO2 as the clay expands from a 0W to a 1W state, suggesting that water props open the interlayer so that CO2 can enter. However, as the clay transitions from a 1W to a 2W state, CO2 desorbs sharply. These observations were placed in the context of two conceptual models concerning hydration mechanisms for expandable clays and were also discussed in light of recent theoretical studies on CO2-H2O-clay interactions. The swelling/shrinkage of expandable clays could affect solid volume, porosity, and permeability of shales. Consequently, the results from this work could aid predictions of shale caprock integrity in large-scale GCS, as well as methane transmissivity in enhanced gas recovery operations.

  7. Pore scale modeling of reactive transport involved in geologic CO2 sequestration

    SciTech Connect (OSTI)

    Kang, Qinjin [Los Alamos National Laboratory; Lichtner, Peter C [Los Alamos National Laboratory; Viswanathan, Hari S [Los Alamos National Laboratory; Abdel-fattah, Amr I [Los Alamos National Laboratory

    2009-01-01T23:59:59.000Z

    We apply a multi-component reactive transport lattice Boltzmann model developed in previolls studies to modeling the injection of a C02 saturated brine into various porous media structures at temperature T=25 and 80 C. The porous media are originally consisted of calcite. A chemical system consisting of Na+, Ca2+, Mg2+, H+, CO2(aq), and CI-is considered. The fluid flow, advection and diHusion of aqueous species, homogeneous reactions occurring in the bulk fluid, as weB as the dissolution of calcite and precipitation of dolomite are simulated at the pore scale. The effects of porous media structure on reactive transport are investigated. The results are compared with continuum scale modeling and the agreement and discrepancy are discussed. This work may shed some light on the fundamental physics occurring at the pore scale for reactive transport involved in geologic C02 sequestration.

  8. Rechargeable Li/CO2O2 (2 : 1) battery and Li/CO2 Yali Liu, Rui Wang, Yingchun Lyu, Hong Li* and Liquan Chen

    E-Print Network [OSTI]

    Wang, Wei Hua

    Rechargeable Li/CO2­O2 (2 : 1) battery and Li/CO2 battery Yali Liu, Rui Wang, Yingchun Lyu, Hong Li* and Liquan Chen A Li/CO2­O2 (2 : 1, volume ratio) battery and a Li/CO2 battery with discharging specific capacities of 1808 mA h gÀ1 and 1032 mA h gÀ1 , respectively, are reported. Li2CO3 is the main discharge

  9. The Anthropogenic Perturbation of Atmospheric CO2 and the Climate System

    E-Print Network [OSTI]

    Fortunat, Joos

    of carbon dioxide (CO2), a powerful greenhouse gas (GHG), are redistributed within the climate system

  10. Soil CO2 production and surface flux at four climate observatories in eastern Canada

    E-Print Network [OSTI]

    Soil CO2 production and surface flux at four climate observatories in eastern Canada David Risk the climatic controls on soil respiration. We use subsurface CO2 concentrations, surface CO2 flux and detailed physical monitoring of the subsurface regime to examine physical controls on soil CO2 production. Results

  11. Observations and simulations of synoptic, regional, and local variations in atmospheric CO2

    E-Print Network [OSTI]

    Collett Jr., Jeffrey L.

    Observations and simulations of synoptic, regional, and local variations in atmospheric CO2 Jih] Synoptic events may play an important role in determining the CO2 spatial distribution and temporal 2001, which had the most significant CO2 concentration variation in our case pool. The CO2

  12. Constraint of the CO2 rise by new atmospheric carbon isotopic measurements during the last deglaciation

    E-Print Network [OSTI]

    Chappellaz, Jérôme

    Click Here for Full Article Constraint of the CO2 rise by new atmospheric carbon isotopic increase of atmospheric carbon dioxide (CO2) during the last glacialinterglacial climatic transition remain debated. We analyzed the parallel evolution of CO2 and its stable carbon isotopic ratio (d13 CO2

  13. CO2 Capture and Utilization for Enhanced Oil Poul Jacob Vilhelmsen1

    E-Print Network [OSTI]

    CO2 Capture and Utilization for Enhanced Oil Recovery Poul Jacob Vilhelmsen1 , William Harrar2 Hørsholm Denmark 1 Abstract CO2 is an international theme and the cap-and-trade systems under. A possible technical step to reduce atmospheric emissions is CO2 capture and the utilisation of the CO2

  14. CO2 efflux from Amazonian headwater streams represents a significant fate for deep soil respiration

    E-Print Network [OSTI]

    Lehmann, Johannes

    CO2 efflux from Amazonian headwater streams represents a significant fate for deep soil respiration amounts of CO2 to the atmosphere, while the magnitude of CO2 degassing from small streams remains a major was as terrestrially-respired CO2 dissolved within soils, over 90% of which evaded to the atmosphere within headwater

  15. Edinburgh Research Explorer Can seasonal and interannual variation in landscape CO2 fluxes

    E-Print Network [OSTI]

    Millar, Andrew J.

    Edinburgh Research Explorer Can seasonal and interannual variation in landscape CO2 fluxes be detected by atmospheric observations of CO2 concentrations made at a tall tower? Citation for published in landscape CO2 fluxes be detected by atmospheric observations of CO2 concentrations made at a tall tower

  16. Physical controls on the isotopic composition of soil-respired CO2

    E-Print Network [OSTI]

    Physical controls on the isotopic composition of soil-respired CO2 Nick Nickerson1 and Dave Risk1] Measurement of the isotopic composition of soil and soil-respired CO2 (d13 CO2) has become an invaluable tool in understanding the effects of diffusive transport on soil CO2 isotopic composition, it is crucial

  17. Large CO2 disequilibria in tropical lakes Humberto Marotta,1,2

    E-Print Network [OSTI]

    Wehrli, Bernhard

    Large CO2 disequilibria in tropical lakes Humberto Marotta,1,2 Carlos M. Duarte,2 Sebastian Sobek,3 November 2009. [1] On the basis of a broad compilation of data on pCO2 in surface waters, we show tropical lakes to be, on average, far more supersaturated and variable in CO2 (geometric mean ± SE pCO2 = 1804

  18. Quantum Leaps in CO2 Detection Robert Byrne, Ph.D.

    E-Print Network [OSTI]

    Meyers, Steven D.

    Quantum Leaps in CO2 Detection Robert Byrne, Ph.D. USF chemical oceanographers are making quantum. #12;Quantum Leaps in CO2 Detection Robert Byrne, Ph.D. When deployed on shipboard our shipboard leaps in measuring carbon dioxide (CO2) in the oceans and measuring the interactions of CO2 between

  19. Mathematical models as tools for probing long-term safety of CO2 storage

    E-Print Network [OSTI]

    Pruess, Karsten

    2010-01-01T23:59:59.000Z

    reservoirs, with large capacity for CO 2 storage (Bradshaw and Dance, 2004; Bachu, 2008). Improperly abandoned

  20. Spatial Disaggregation of CO2 Emissions for the State of California

    E-Print Network [OSTI]

    de la Rue du Can, Stephane

    2008-01-01T23:59:59.000Z

    Electricity Generation/CHP Residential Commercial Industrial Agricultural Transportation Percent of county CO2 emissions