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Scott M Frailey - One of the best experts on this subject based on the ideXlab platform.
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effect of geologic depositional environment on co2 Storage efficiency
2014Co-Authors: Roland T Okwen, Fang Yang, Scott M FraileyAbstract:Abstract The Storage potential and movement of fluids within a formation is dependent on hydraulic characterization unique to each depositional environment. Storage efficiency (E), the ratio of the injected volume of CO2 to the accessible pore volume, quantifies the CO2 Storage capacity in a geologic depositional environment, providing a means to assess the CO2 Storage Resource of candidate reservoirs. This paper quantifies the ranges for E via numerical modeling for eight depositional environments: deltaic, shelf clastic, shelf carbonate, fluvial deltaic, strandplain, reef, fluvial and alluvial, and turbidite. An important aspect of this work is the development of geologic and geocellular modeling that reflects the uniqueness of each depositional environment. Depositional environments were interpreted from core and geophysical log data; geologic and petrophysical data from oil fields and gas Storage sites were used as constraints in the development of geocellular models, which were upscaled for flow simulations. Evaluation of the effects of geologic structures on Storage efficiency indicates it causes a net increase in efficiency. Fluvial deltaic had the highest E and shelf carbonate had the lowest.
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u s doe methodology for the development of geologic Storage potential for carbon dioxide at the national and regional scale
2011Co-Authors: Angela Goodman, Scott M Frailey, Alexandra J Hakala, Grant S Bromhal, Dawn Deel, Traci Rodosta, Michael Small, Doug Allen, Vyacheslav Romanov, Jim FazioAbstract:Abstract A detailed description of the United States Department of Energy (US-DOE) methodology for estimating CO 2 Storage potential for oil and gas reservoirs, saline formations, and unmineable coal seams is provided. The oil and gas reservoirs are assessed at the field level, while saline formations and unmineable coal seams are assessed at the basin level. The US-DOE methodology is intended for external users such as the Regional Carbon Sequestration Partnerships (RCSPs), future project developers, and governmental entities to produce high-level CO 2 Resource assessments of potential CO 2 Storage reservoirs in the United States and Canada at the regional and national scale; however, this methodology is general enough that it could be applied globally. The purpose of the US-DOE CO 2 Storage methodology, definitions of Storage terms, and a CO 2 Storage classification are provided. Methodology for CO 2 Storage Resource estimate calculation is outlined. The Log Odds Method when applied with Monte Carlo Sampling is presented in detail for estimation of CO 2 Storage efficiency needed for CO 2 Storage Resource estimates at the regional and national scale. CO 2 Storage potential reported in the US-DOE's assessment are intended to be distributed online by a geographic information system in NatCarb and made available as hard-copy in the Carbon Sequestration Atlas of the United States and Canada . US-DOE's methodology will be continuously refined, incorporating results of the Development Phase projects conducted by the RCSPs from 2008 to 2018. Estimates will be formally updated every two years in subsequent versions of the Carbon Sequestration Atlas of the United States and Canada .
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u s department of energy s site screening site selection and initial characterization for Storage of co2 in deep geological formations
2011Co-Authors: Traci Rodosta, Scott M Frailey, John Litynski, Sean Plasynski, Scott T Hickman, Larry MyerAbstract:Abstract The U.S. Department of Energy (DOE) is the lead Federal agency for the development and deployment of carbon sequestration technologies. As part of its mission to facilitate technology transfer and develop guidelines from lessons learned, DOE is developing a series of best practice manuals (BPMs) for carbon capture and Storage (CCS). The “Site Screening, Site Selection, and Initial Characterization for Storage of CO 2 in Deep Geological Formations” BPM is a compilation of best practices and includes flowchart diagrams illustrating the general decision making process for Site Screening, Site Selection, and Initial Characterization. The BPM integrates the knowledge gained from various programmatic efforts, with particular emphasis on the Characterization Phase through pilot-scale CO 2 injection testing of the Validation Phase of the Regional Carbon Sequestration Partnership (RCSP) Initiative. Key geologic and surface elements that suitable candidate Storage sites should possess are identified, along with example Site Screening, Site Selection, and Initial Characterization protocols for large-scale geologic Storage projects located across diverse geologic and regional settings. This manual has been written as a working document, establishing a framework and methodology for proper site selection for CO 2 geologic Storage. This will be useful for future CO 2 emitters, transporters, and Storage providers. It will also be of use in informing local, regional, state, and national governmental agencies of best practices in proper sequestration site selection. Furthermore, it will educate the inquisitive general public on options and processes for geologic CO 2 Storage. In addition to providing best practices, the manual presents a geologic Storage Resource and capacity classification system. The system provides a “standard“to communicate Storage and capacity estimates, uncertainty and project development risk, data guidelines and analyses for adequate site characterization, and guidelines for reporting estimates within the classification based on each project’s status.
Casie L Davidson - One of the best experts on this subject based on the ideXlab platform.
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ccus in china s mitigation strategy insights from integrated assessment modeling
2019Co-Authors: Jill Horing, Robert T Dahowski, Casie L Davidson, Qiang Liu, James A. Edmonds, Bo Liu, Haewon Mcjeon, Jeff Mcleod, Pralit Patel, Leon ClarkeAbstract:Abstract China is the world’s largest energy consumer and carbon dioxide (CO2) emitter. China has committed to limit its greenhouse gas emissions. With its heavy reliance on domestic coal Resources, China faces an enormous challenge of transitioning its economy to a low-carbon energy mix to achieve long-term climate and local air quality goals. Carbon capture, utilization, and Storage (CCUS) is widely recognized as an important option for emissions mitigation. The near-term readiness and cost of CCUS technologies, the sectors and regions of CO2 capture, and the location and adequacy of CO2 Storage sites all affect the application of CCUS in China’s low-carbon development. This study uses GCAM-China, a global integrated assessment model with details for 31 provinces in China, to examine the role of CCUS as part of China’s climate mitigation strategy over the period of its Nationally Determined Contributions as well as in the transition to deeper emissions reductions toward mid-century. The inclusion of new provincial CO2 Storage cost curves gives a more detailed evaluation of where, in terms of geography and sector, and when CCUS deployment in China may take place. The results suggest that the scale of deployment varies depending on socioeconomic development pathways and the level of deployment of other low-carbon technologies. Across provinces and development pathways, early deployment of CCUS occurs within industrial and synthetic fuel production sectors, followed by increased deployment in the power sector by mid-century. Several provinces, such as Shandong, Inner Mongolia, Hebei, and Henan, emerge as particularly important in CCUS deployment, as a result of large CO2 point sources and Storage availability. Results indicate that Storage Resource availability is unlikely to constrain CCUS deployment in most provinces through the end of the century.
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economic evaluation on co2 eor of onshore oil fields in china
2015Co-Authors: Xiaochun Li, Robert T Dahowski, Casie L DavidsonAbstract:Abstract Carbon dioxide enhanced oil recovery (CO 2 -EOR) and sequestration in depleted oil reservoirs is a plausible option for utilizing anthropogenic CO 2 to increase oil production while storing CO 2 underground. Evaluation of the Storage Resources and cost of potential CO 2 -EOR projects is an essential step before the commencement of large-scale deployment of such activities. In this paper, a hybrid techno-economic evaluation method, including a performance model and cost model for onshore CO 2 -EOR projects, has been developed based on previous studies. Total 296 onshore oil fields, accounting for about 70% of total mature onshore oil fields in China, were evaluated by the techno-economic method. The key findings of this study are summarized as follows: (1) deterministic analysis shows there are approximately 1.1 billion tons (7.7 billion barrels) of incremental crude oil and 2.2 billion tons CO 2 Storage Resource for onshore CO 2 -EOR at net positive revenue within the Chinese oil fields reviewed under the given operating strategy and economic assumptions. (2) Sensitivity study highlights that the cumulative oil production and cumulative CO 2 Storage Resource are very sensitive to crude oil price, CO 2 cost, project lifetime, discount rate and tax policy. High oil price, short project lifetime, low discount rate, low CO 2 cost, and low tax policy can greatly increase the net income of the oil enterprise, incremental oil recovery and CO 2 Storage Resource. (3) From this techno-economic evaluation, the major barriers to large-scale deployment of CO 2 -EOR include complex geological conditions, low API of crude oil, high tax policy, and lack of incentives for the CO 2 -EOR project.
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the potential for increased atmospheric co2 emissions and accelerated consumption of deep geologic co2 Storage Resources resulting from the large scale deployment of a ccs enabled unconventional fossil fuels industry in the u s
2009Co-Authors: James J Dooley, Robert T Dahowski, Casie L DavidsonAbstract:Abstract Desires to enhance the energy security of the United States have spurred renewed interest in the development of abundant domestic heavy hydrocarbon Resources including oil shale and coal to produce unconventional liquid fuels to supplement conventional oil supplies. However, the production processes for these unconventional fossil fuels create large quantities of carbon dioxide (CO2) and this remains one of the key arguments against such development. Carbon dioxide capture and Storage (CCS) technologies could reduce these emissions and preliminary analysis of regional CO2 Storage capacity in locations where such facilities might be sited within the U.S. indicates that there appears to be sufficient Storage capacity, primarily in deep saline formations, to accommodate the CO2 from these industries. Nevertheless, even assuming wide-scale availability of cost-effective CO2 capture and geologic Storage Resources, the emergence of a domestic U.S. oil shale or coal-to-liquids (CTL) industry would be responsible for significant increases in CO2 emissions to the atmosphere. The authors present modeling results of two future hypothetical climate policy scenarios that indicate that the oil shale production facilities required to produce 3 MMB/d from the Eocene Green River Formation of the western U.S. using an in situ retorting process would result in net emissions to the atmosphere of between 3000 and 7000 MtCO2, in addition to storing potentially 900–5000 MtCO2 in regional deep geologic formations via CCS in the period up to 2050. A similarly sized, but geographically more dispersed domestic CTL industry could result in 4000–5000 MtCO2 emitted to the atmosphere in addition to potentially 21,000–22,000 MtCO2 stored in regional deep geologic formations over the same period. While this analysis shows that there is likely adequate CO2 Storage capacity in the regions where these technologies are likely to deploy, the reliance by these industries on large-scale CCS could result in an accelerated rate of utilization of the nation's CO2 Storage Resource, leaving less high-quality Storage capacity for other carbon-producing industries including electric power generation.
Jason R Braunberger - One of the best experts on this subject based on the ideXlab platform.
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a comparison of volumetric and dynamic co2 Storage Resource and efficiency in deep saline formations
2015Co-Authors: Charles D Gorecki, Scott C Ayash, Guoxiang Liu, Jason R Braunberger, Neil W DotzenrodAbstract:Abstract A reliable carbon dioxide (CO2) Storage Resource estimation method is crucial if carbon capture and Storage in deep saline formations (DSFs) is to gain widespread deployment for reducing anthropogenic CO2 emissions to the atmosphere. Most of the published methodologies are based on a volumetric calculation and do not consider the effect of site-specific dynamic factors (e.g., injection rate, pressure interference). Several studies suggest these dynamic components may play the dominant role in storing CO2 in DSFs. In this study, CO2 Storage Resource estimates and efficiencies for two deep saline systems were calculated using volumetric and dynamic methodologies. Comparison of the results indicates that dynamic CO2 Storage efficiency is time-dependent. For short injection lengths (∼50 years), an open system has an efficiency similar to a closed system, and volumetric Storage Resource estimates are too high. For long injection time frames (∼2000 years), the dynamic Storage Resource of open systems approaches the volumetric potential. These results suggest that volumetric assessments are reliable provided it is understood that it may take hundreds of wells and/or injection for hundreds of years to reach a formation's effective CO2 Storage Resource potential. Additionally, operational factors such as water extraction can increase CO2 Storage Resource and efficiency.
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a comparison of volumetric and dynamic Storage efficiency in deep saline reservoirs an overview of ieaghg study iea con 13 208
2014Co-Authors: James Craig, Charles D Gorecki, Scott C Ayash, Guoxiang Liu, Jason R BraunbergerAbstract:Abstract Recently, the IEA Greenhouse Gas R&D Programme and U.S. Department of Energy commissioned the Energy & Environmental Research Center to address concerns related to the validity of volumetric techniques for estimating the CO 2 Storage efficiency of saline formations. Two deep saline systems were compared using volumetric and dynamic Storage Resource estimation methods. Results indicate that volumetric estimates are valid and nearly equivalent to dynamic results, provided that boundary conditions are properly considered and a sufficient number of injection wells and duration of injection are used. For short time frames (e.g., 50 years of injection), volumetric estimates may be optimistic.
Qian Zhang - One of the best experts on this subject based on the ideXlab platform.
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regional to reservoir scale evaluation of co2 Storage Resource estimates of coal seams
2017Co-Authors: Qian Zhang, Kevin Ellett, John A Rupp, Maria Mastalerz, Ozgen C KaracanAbstract:Abstract Unmineable coal seams are an important target for investigating the economic viability of carbon capture and Storage technology owing to their potential for simultaneous CO2 Storage and enhanced coalbed methane production. As such, recent developments in integrated system models are aiming to explicitly incorporate coal seam Storage and enhanced methane production into their economic analyses, however, such implementation currently relies on fairly uncertain prospective Resource estimates derived from regional-scale analyses. In this paper, we evaluate the uncertainty of such prospective Resource estimates, both for CO2 Storage and for CO2 utilization potential (i.e., enhanced coalbed methane production from CO2 injection) via comparison to results from more detailed, local-scale reservoir simulations at numerous locations. Reservoir-scale simulations incorporate the dynamic system response to CO2 injection, whereas regional-scale prospective Resource estimates rely on volumetric calculations of original gas-in-place from static geological models combined with assumed recovery factors. Results based on a case study of 12 different locations in the Illinois Basin, USA suggest that prospective Resource estimates for CO2 Storage may be systematically biased towards over-estimation. By developing a set of low-, mid-, and high-range estimates from model simulations, a total of 36 comparisons were made to the prospective Resource estimates, of which 35 showed significantly lower results for the model-based estimates. Model sensitivity testing of variable CO2 injection rates indicated that the requirement to maintain reservoir pressure below the fracture gradient threshold is in part responsible for the lower limit of Storage Resource estimates obtained from the reservoir simulation results versus the prospective Resource methodology which neglects such processes. In terms of enhanced methane recovery, results were far more comparable between the two methods for the low- and mid-range set of estimates, whereas the high-range estimates were still notably larger using the prospective Resource methodology. We conclude that utilizing prospective Resource estimates of enhanced coalbed methane potential in integrated system models appears feasible for the more conservative range of estimates, whereas CO2 Storage estimates of coal seams are likely to produce overly optimistic results in the system model. We also note that for the Illinois Basin case study, both the modelling results and the regional-scale results indicate that a significant amount of additional well drilling beyond the existing coalbed methane infrastructure would need to be conducted in order for coal seams to be a viable alternative to other options in the region such as oil and gas reservoirs and deep saline formations.
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uncertainty in regional scale evaluation of co2 geologic Storage Resources comparison of the illinois basin usa and the ordos basin china
2013Co-Authors: Kevin M Ellett, Qian Zhang, John A Rupp, Cristian R Medina, Guochang Wang, Timothy R CarrAbstract:To meet the ambitious goals of both the United States and China for advancing the deployment of Carbon Capture Utilization and Storage technology will require an improved understanding of the magnitude and geographical distribution of carbon geologic Storage (CGS) Resources. Evaluation of CGS Resources and the fractional component of practical Storage capacity is thus a major focus of research in both nations. In this paper, our purpose is to carefully evaluate the sources of uncertainty that propagate into regional-scale CGS Resource estimates and assess the extent to which uncertainty may be reduced by applying increasingly informed levels of geologic characterization. We achieve this objective by focusing on two geologic basins of great similarity but with varying amounts of data the Illinois Basin in the United States and the Ordos Basin in China. Our investigation focuses on Storage Resource in deep saline formations because large-scale greenhouse gas mitigation is expected to require the use of this CGS Resource. To accurately compare results from different basins and different nations requires applying a common methodology for estimating CGS Resources. In this study we follow the methodology published by the U.S. Department of Energy. Results demonstrate that in both the Illinois and Ordos Basins, review of the open literature is adequate for identifying the saline formations that should be considered as potential targets for geologic Storage (i.e., regionally extensive porous formations having an overlying low permeability seal at a minimum depth of 800 meters). Analysis of such prior work allows for an initial, simple quantification of CGS Resources at regional scales by applying probabilistic-based Storage efficiency factors to generalized maps of bulk formation characteristics. Resource characterization may be improved through more advanced analysis when data are available, however, demonstrating that enhanced characterization leads to a quantifiable reduction in uncertainty appears problematic. This difficulty in demonstrating reduced uncertainty led us to identify some key issues in applying the published Department of Energy (DOE) methodology for Resource estimation. Our primary finding is that the DOE methodology underestimates Storage Resource uncertainty because it does not account for error in the total formation bulk rock pore volume. The methodology uses Storage efficiency factors that account only for uncertainty in the fraction of this total formation pore volume that can effectively store CO2. Thus the uncertainty range for formation Storage Resource is based on just a single realization of the total formation pore volume. To evaluate the significance of this impact we use data from the Mount Simon Sandstone formation in the Illinois Basin to account for this additional uncertainty in a probabilistic manner. The resulting Storage Resource estimates at the 10th and 90th percentile probability range from 18 to 313 gigatonnes, compared to 24 and 253 gigatonnes when following the standard published methodology. Also noteworthy from our analysis of the Mount Simon Sandstone is the fact that our results are significantly larger than the Resource estimates published in the DOE Sequestration Atlas (11 and 151 gigatonnes for the 10th and 90th percentile range). It appears that the range in the published Resource estimate values for the Mount Simon Sandstone may be significantly underestimated not only because of the formation pore volume issue discussed above, but also as a result of over discounting the Resource by applying the published total Storage efficiency factor values to a formation area that was already reduced to a net area. Our results provide insight on some important issues and challenges to applying the DOE methodology in a broader range of CGS Resource characterization analyses. We conclude that further refinement of the DOE methodology is necessary to provide a more robust assessment of the uncertainty that exists in regional-scale CGS Resource estimates.
Charles D Gorecki - One of the best experts on this subject based on the ideXlab platform.
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a comparison of volumetric and dynamic co2 Storage Resource and efficiency in deep saline formations
2015Co-Authors: Charles D Gorecki, Scott C Ayash, Guoxiang Liu, Jason R Braunberger, Neil W DotzenrodAbstract:Abstract A reliable carbon dioxide (CO2) Storage Resource estimation method is crucial if carbon capture and Storage in deep saline formations (DSFs) is to gain widespread deployment for reducing anthropogenic CO2 emissions to the atmosphere. Most of the published methodologies are based on a volumetric calculation and do not consider the effect of site-specific dynamic factors (e.g., injection rate, pressure interference). Several studies suggest these dynamic components may play the dominant role in storing CO2 in DSFs. In this study, CO2 Storage Resource estimates and efficiencies for two deep saline systems were calculated using volumetric and dynamic methodologies. Comparison of the results indicates that dynamic CO2 Storage efficiency is time-dependent. For short injection lengths (∼50 years), an open system has an efficiency similar to a closed system, and volumetric Storage Resource estimates are too high. For long injection time frames (∼2000 years), the dynamic Storage Resource of open systems approaches the volumetric potential. These results suggest that volumetric assessments are reliable provided it is understood that it may take hundreds of wells and/or injection for hundreds of years to reach a formation's effective CO2 Storage Resource potential. Additionally, operational factors such as water extraction can increase CO2 Storage Resource and efficiency.
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a comparison of volumetric and dynamic Storage efficiency in deep saline reservoirs an overview of ieaghg study iea con 13 208
2014Co-Authors: James Craig, Charles D Gorecki, Scott C Ayash, Guoxiang Liu, Jason R BraunbergerAbstract:Abstract Recently, the IEA Greenhouse Gas R&D Programme and U.S. Department of Energy commissioned the Energy & Environmental Research Center to address concerns related to the validity of volumetric techniques for estimating the CO 2 Storage efficiency of saline formations. Two deep saline systems were compared using volumetric and dynamic Storage Resource estimation methods. Results indicate that volumetric estimates are valid and nearly equivalent to dynamic results, provided that boundary conditions are properly considered and a sufficient number of injection wells and duration of injection are used. For short time frames (e.g., 50 years of injection), volumetric estimates may be optimistic.