Download or read book THE OHIO RIVER VALLEY CO2 STORAGE PROJECT PRELIMINARY ASSESSMENT OF DEEP SALINE RESERVOIRS AND COAL SEAMS written by Michael J. Mudd and published by . This book was released on 2003 with total page 173 pages. Available in PDF, EPUB and Kindle. Book excerpt: This report describes the geologic setting for the Deep Saline Reservoirs and Coal Seams in the Ohio River Valley CO{sub 2} Storage Project area. The object of the current project is to site and design a CO{sub 2} injection facility. A location near New Haven, WV, has been selected for the project. To assess geologic storage reservoirs at the site, regional and site-specific geology were reviewed. Geologic reports, deep well logs, hydraulic tests, and geologic maps were reviewed for the area. Only one well within 25 miles of the site penetrates the deeper sedimentary rocks, so there is a large amount of uncertainty regarding the deep geology at the site. New Haven is located along the Ohio River on the border of West Virginia and Ohio. Topography in the area is flat in the river valley but rugged away from the Ohio River floodplain. The Ohio River Valley incises 50-100 ft into bedrock in the area. The area of interest lies within the Appalachian Plateau, on the western edge of the Appalachian Mountain chain. Within the Appalachian Basin, sedimentary rocks are 3,000 to 20,000 ft deep and slope toward the southeast. The rock formations consist of alternating layers of shale, limestone, dolomite, and sandstone overlying dense metamorphic continental shield rocks. The Rome Trough is the major structural feature in the area, and there may be some faults associated with the trough in the Ohio-West Virginia Hinge Zone. The area has a low earthquake hazard with few historical earthquakes. Target injection reservoirs include the basal sandstone/Lower Maryville and the Rose Run Sandstone. The basal sandstone is an informal name for sandstones that overlie metamorphic shield rock. Regional geology indicates that the unit is at a depth of approximately 9,100 ft below the surface at the project site and associated with the Maryville Formation. Overall thickness appears to be 50-100 ft. The Rose Run Sandstone is another potential reservoir. The unit is located approximately 1,100 ft above the basal sandstone and is 100-200 ft thick. The storage capacity estimates for a 20-mile radius from the injection well ranged from 39-78 million tons (Mt) for each formation. Several other oil and gas plays have hydraulic properties conducive for injection, but the formations are generally only 5-50 ft thick in the study area. Overlying the injection reservoirs are thick sequences of dense, impermeable dolomite, limestone, and shale. These layers provide containment above the potential injection reservoirs. In general, it appears that the containment layers are much thicker and extensive than the injection intervals. Other physical parameters for the study area appear to be typical for the region. Anticipated pressures at maximum depths are approximately 4,100 psi based on a 0.45 psi/ft pressure gradient. Temperatures are likely to be 150 F. Groundwater flow is slow and complex in deep formations. Regional flow directions appear to be toward the west-northwest at less than 1 ft per year within the basal sandstone. Vertical gradients are downward in the study area. A review of brine geochemistry indicates that formation fluids have high salinity and dissolved solids. Total dissolved solids ranges from 200,000-325,000 mg/L in the deep reservoirs. Brine chemistry is similar throughout the different formations, suggesting extensive mixing in a mature basin. Unconsolidated sediments in the Ohio River Valley are the primary source of drinking water in the study area.

Download or read book NOVEL CONCEPTS RESEARCH IN GEOLOGIC STORAGE OF CO2 PHASE III THE OHIO RIVER VALLEY CO2 STORAGE PROJECT written by and published by . This book was released on 2005 with total page 9 pages. Available in PDF, EPUB and Kindle. Book excerpt: 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 CO2 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 CO2 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 CO2 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.

Download or read book NOVEL CONCEPTS RESEARCH IN GEOLOGIC STORAGE OF CO2 written by and published by . This book was released on 2005 with total page 10 pages. Available in PDF, EPUB and Kindle. Book excerpt: As part of the Department of Energy's (DOE) initiative on developing new technologies for storage of carbon dioxide in geologic reservoirs, Battelle has been awarded a project to investigate the feasibility of CO2 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. In addition to the DOE, the project is being sponsored by American Electric Power (AEP), BP, The Ohio Coal Development Office (OCDO) of the Ohio Department of Development, and Schlumberger. The main objective of the project is 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 CO2 disposal in deep saline formations and potentially in nearby deep coal seams. This work supports the overall project objective of demonstrating that CO2 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. The current technical progress report summarizes activities completed for the October through December 2004 period of the project. As discussed in the report, the technical activities focused on initial injection well design, completion of the site characterization report, assessment of monitoring technologies, shipment of coal samples for testing the capture system to Mitsubishi Heavy Industry, and presentation of project progress at several venues. In addition, proposals to DOE for continued funding of the project activities under the current contract and potentially a new contract for development of regional framework were being evaluated and processed.

Download or read book NOVEL CONCEPTS RESEARCH IN GEOLOGIC STORAGE OF CO2 PHASE III written by and published by . This book was released on 2005 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: As part of the Department of Energy's (DOE) initiative on developing new technologies for storage of carbon dioxide in geologic reservoirs, Battelle has been investigating the feasibility of CO2 sequestration in the deep saline reservoirs in the Ohio River Valley region. In addition to the DOE, the project is being sponsored by American Electric Power (AEP), BP, The Ohio Coal Development Office (OCDO) of the Ohio Air Quality Development Authority, and Schlumberger. The main objective of the project is to demonstrate that CO2 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 CO2 disposal in deep saline formations. The current technical progress report summarizes activities completed for the July through September 2005 period of the project. As discussed in the report, the field activities focused on preparations for reservoir testing in the Copper Ridge ''B-zone'' in the AEP No. 1 well. In addition work continued on development of injection well design options, engineering assessment of CO2 capture systems, reservoir simulations, work on a Class V Underground Injection Control permit, and assessment of monitoring technologies as they apply to the project site. Overall, the current design feasibility phase project is proceeding according to plans.

Download or read book The Ohio River Valley CO2 Storage Project AEP Mountaineer Plan West Virginia written by and published by . This book was released on 2009 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: This report includes an evaluation of deep rock formations with the objective of providing practical maps, data, and some of the issues considered for carbon dioxide (CO2) storage projects in the Ohio River Valley. Injection and storage of CO2 into deep rock formations represents a feasible option for reducing greenhouse gas emissions from coal-burning power plants concentrated along the Ohio River Valley area. This study is sponsored by the U.S. Department of Energy (DOE) National Energy Technology Laboratory (NETL), American Electric Power (AEP), BP, Ohio Coal Development Office, Schlumberger, and Battelle along with its Pacific Northwest Division. An extensive program of drilling, sampling, and testing of a deep well combined with a seismic survey was used to characterize the local and regional geologic features at AEP's 1300-megawatt (MW) Mountaineer Power Plant. Site characterization information has been used as part of a systematic design feasibility assessment for a first-of-a-kind integrated capture and storage facility at an existing coal-fired power plant in the Ohio River Valley region--an area with a large concentration of power plants and other emission sources. Subsurface characterization data have been used for reservoir simulations and to support the review of the issues relating to injection, monitoring, strategy, risk assessment, and regulatory permitting. The high-sulfur coal samples from the region have been tested in a capture test facility to evaluate and optimize basic design for a small-scale capture system and eventually to prepare a detailed design for a capture, local transport, and injection facility. The Ohio River Valley CO2 Storage Project was conducted in phases with the ultimate objectives of demonstrating both the technical aspects of CO2 storage and the testing, logistical, regulatory, and outreach issues related to conducting such a project at a large point source under realistic constraints. The site characterization phase was completed, laying the groundwork for moving the project towards a potential injection phase. Feasibility and design assessment activities included an assessment of the CO2 source options (a slip-stream capture system or transported CO2); development of the injection and monitoring system design; preparation of regulatory permits; and continued stakeholder outreach.

Download or read book NOVEL CONCEPTS RESEARCH IN GEOLOGIC STORAGE OF CO2 PHASE III written by Neeraj Gupta and published by . This book was released on 2006 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: As part of the Department of Energy's (DOE) initiative on developing new technologies for storage of carbon dioxide in geologic reservoirs, Battelle has been investigating the feasibility of CO{sub 2} sequestration in the deep saline reservoirs in the Ohio River Valley region. In addition to the DOE, the project is being sponsored by American Electric Power (AEP), BP, The Ohio Coal Development Office (OCDO) of the Ohio Air Quality Development Authority, Schlumberger, and Battelle. 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. The current technical progress report summarizes activities completed for the January-March 2006 period of the project. As discussed in the following report, the main accomplishments were analysis of Copper Ridge ''B-zone'' reservoir test results from the AEP No. 1 well and design and feasibility support tasks. Reservoir test results indicate injection potential in the Copper Ridge ''B-zone'' may be significantly higher than anticipated for the Mountaineer site. Work continued on development of injection well design options, engineering assessment of CO{sub 2} capture systems, permitting, and assessment of monitoring technologies as they apply to the project site. In addition, organizational and scheduling issues were addressed to move the project toward an integrated carbon capture and storage system at the Mountaineer site. Overall, the current design feasibility phase project is proceeding according to plans.

Download or read book Novel Concepts Research in Geologic Storage of CO2 written by Neeraj Gupta and published by . This book was released on 2006 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: As part of the Department of Energy's (DOE) initiative on developing new technologies for the storage of carbon dioxide (CO{sub 2}) in geologic reservoirs, Battelle has been investigating the feasibility of CO{sub 2} sequestration in the deep saline reservoirs of the Ohio River Valley region. In addition to the DOE, the project is being sponsored by American Electric Power (AEP), BP, Ohio Coal Development Office (OCDO) of the Ohio Air Quality Development Authority, Schlumberger, and Battelle. 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 order to determine their potential use for conducting a long-term test of CO{sub 2} disposal in deep saline formations. The current technical progress report summarizes activities completed for the July-September 2006 period of the project. As discussed in the following report, the main accomplishments were reservoir modeling for the Copper Ridge ''B-zone'' and design and feasibility support tasks. Work continued on the development of injection well design options, engineering assessment of CO2 capture systems, permitting, and assessment of monitoring technologies as they apply to the project site. In addition, an integrated risk analysis of the proposed system was completed. Finally, slipstream capture construction issues were evaluated with AEP to move the project toward an integrated carbon capture and storage system at the Mountaineer site. Overall, the current design feasibility phase project is proceeding according to plans.

Download or read book The Ohio River Valley CO2 Storage Project AEP Mountaineer Plant West Virginia Numerical Simulation and Risk Assessment Report written by and published by . This book was released on 2008 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: A series of numerical simulations of carbon dioxide (CO2) injection were conducted as part of a program to assess the potential for geologic sequestration in deep geologic reservoirs (the Rose Run and Copper Ridge formations), at the American Electric Power (AEP) Mountaineer Power Plant outside of New Haven, West Virginia. The simulations were executed using the H2O-CO2-NaCl operational mode of the Subsurface Transport Over Multiple Phases (STOMP) simulator (White and Oostrom, 2006). The objective of the Rose Run formation modeling was to predict CO2 injection rates using data from the core analysis conducted on the samples. A systematic screening procedure was applied to the Ohio River Valley CO2 storage site utilizing the Features, Elements, and Processes (FEP) database for geological storage of CO2 (Savage et al., 2004). The objective of the screening was to identify potential risk categories for the long-term geological storage of CO2 at the Mountaineer Power Plant in New Haven, West Virginia. Over 130 FEPs in seven main classes were assessed for the project based on site characterization information gathered in a geological background study, testing in a deep well drilled on the site, and general site conditions. In evaluating the database, it was apparent that many of the items were not applicable to the Mountaineer site based its geologic framework and environmental setting. Nine FEPs were identified for further consideration for the site. These FEPs generally fell into categories related to variations in subsurface geology, well completion materials, and the behavior of CO2 in the subsurface. Results from the screening were used to provide guidance on injection system design, developing a monitoring program, performing reservoir simulations, and other risk assessment efforts. Initial work indicates that the significant FEPs may be accounted for by focusing the storage program on these potential issues. The screening method was also useful in identifying unnecessary items that were not significant given the site-specific geology and proposed scale of the Ohio River Valley CO2 Storage Project. Overall, the FEP database approach provides a comprehensive methodology for assessing potential risk for a practical CO2 storage application. An integrated numerical fate and transport model was developed to enable risk and consequence assessment at field scale. Results show that such an integrated modeling effort would be helpful in meeting the project objectives (such as site characterization, engineering, permitting, monitoring and closure) during different stages. A reservoir-scale numerical model was extended further to develop an integrated assessment framework which can address the risk and consequence assessment, monitoring network design and permitting guidance needs. The method was used to simulate sequestration of CO2 in moderate quantities at the Mountaineer Power Plant. Results indicate that at the relatively low injection volumes planned for pilot scale demonstration at this site, the risks involved are minor to negligible, owing to a thick, low permeability caprock and overburden zones. Such integrated modeling approaches coupled with risk and consequence assessment modeling are valuable to project implementation, permitting, monitoring as well as site closure.

Download or read book Geological Storage of CO2 in Deep Saline Formations written by Auli Niemi and published by Springer. This book was released on 2017-02-24 with total page 567 pages. Available in PDF, EPUB and Kindle. Book excerpt: This book offers readers a comprehensive overview, and an in-depth understanding, of suitable methods for quantifying and characterizing saline aquifers for the geological storage of CO2. It begins with a general overview of the methodology and the processes that take place when CO2 is injected and stored in deep saline-water-containing formations. It subsequently presents mathematical and numerical models used for predicting the consequences of CO2 injection. This book provides descriptions of relevant experimental methods, from laboratory experiments to field scale site characterization and techniques for monitoring spreading of the injected CO2 within the formation. Experiences from a number of important field injection projects are reviewed, as are those from CO2 natural analog sites. Lastly, the book presents relevant risk management methods. Geological storage of CO2 is widely considered to be a key technology capable of substantially reducing the amount of CO2 released into the atmosphere, thereby reducing the negative impacts of such releases on the global climate. Around the world, projects are already in full swing, while others are now being initiated and executed to demonstrate the technology. Deep saline formations are the geological formations considered to hold the highest storage potential, due to their abundance worldwide. To date, however, these formations have been relatively poorly characterized, due to their low economic value. Accordingly, the processes involved in injecting and storing CO2 in such formations still need to be better quantified and methods for characterizing, modeling and monitoring this type of CO2 storage in such formations must be rapidly developed and refined.

Download or read book Leveraging Regional Exploration to Develop Geologic Framework for CO2 Storage in Deep Formations in Midwestern United States written by and published by . This book was released on 2009 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: Obtaining subsurface data for developing a regional framework for geologic storage of CO2 can require drilling and characterization in a large number of deep wells, especially in areas with limited pre-existing data. One approach for achieving this objective, without the prohibitive costs of drilling costly standalone test wells, is to collaborate with the oil and gas drilling efforts in a piggyback approach that can provide substantial cost savings and help fill data gaps in areas that may not otherwise get characterized. This leveraging with oil/gas drilling also mitigates some of the risk involved in standalone wells. This collaborative approach has been used for characterizing in a number of locations in the midwestern USA between 2005 and 2009 with funding from U.S. Department of Energy's National Energy Technology Laboratory (DOE award: DE-FC26-05NT42434) and in-kind contributions from a number of oil and gas operators. The results are presented in this final technical report. In addition to data collected under current award, selected data from related projects such as the Midwestern Regional Carbon Sequestration Partnership (MRCSP), the Ohio River Valley CO2 storage project at and near the Mountaineer Plant, and the drilling of the Ohio Stratigraphic well in Eastern Ohio are discussed and used in the report. Data from this effort are also being incorporated into the MRCSP geologic mapping. The project activities were organized into tracking and evaluation of characterization opportunities; participation in the incremental drilling, basic and advanced logging in selected wells; and data analysis and reporting. Although a large number of opportunities were identified and evaluated, only a small subset was carried into the field stage. Typical selection factors included reaching an acceptable agreement with the operator, drilling and logging risks, and extent of pre-existing data near the candidate wells. The region of study is primarily along the Ohio River Valley corridor in the Appalachian Basin, which underlies large concentrations of CO2 emission sources. In addition, some wells in the Michigan basin are included. Assessment of the geologic and petrophysical properties of zones of interest has been conducted. Although a large number of formations have been evaluated across the geologic column, the primary focus has been on evaluating the Cambrian sandstones (Mt. Simon, Rose Run, Kerbel) and carbonates layers (Knox Dolomite) as well as on the Silurian-Devonian carbonates (Bass Island, Salina) and sandstones (Clinton, Oriskany, Berea). Factors controlling the development of porosity and permeability, such as the depositional setting have been explored. In northern Michigan the Bass Islands Dolomite appears to have favorable reservoir development. In west central Michigan the St. Peter sandstone exhibits excellent porosity in the Hart and Feuring well and looks promising. In Southeastern Kentucky in the Appalachian Basin, the Batten and Baird well provided valuable data on sequestration potential in organic shales through adsorption. In central and eastern Ohio and western West Virginia, the majority of the wells provided an insight to the complex geologic framework of the relatively little known Precambrian through Silurian potential injection targets. Although valuable data was acquired and a number of critical data gaps were filled through this effort, there are still many challenges ahead and questions that need answered. The lateral extent to which favorable potential injection conditions exist in most reservoirs is still generally uncertain. The prolongation of the characterization of regional geologic framework through partnership would continue to build confidence and greatly benefit the overall CO2 sequestration effort.

Download or read book Ohio River Basin Energy Study V II A written by and published by . This book was released on 1977 with total page 584 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Greenhouse Issues written by and published by . This book was released on 2004 with total page 176 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book CO2 Storage in Carboniferous Formations and Abandoned Coal Mines written by Manchao He and published by CRC Press. This book was released on 2011-09-16 with total page 218 pages. Available in PDF, EPUB and Kindle. Book excerpt: Underground geological storage of carbon dioxide (CO2) has considerable potential for mitigating climate change. CO2 can be safely injected and stored at well characterized and properly managed sites. Injecting carbon dioxide in deep geological formations can store it underground for long periods of time. Depleted oil and gas reservoirs, saline aqu

Download or read book Engineering and Economic Assessment of Carbon Dioxide Sequestration in Saline Formations written by and published by . This book was released on 2001 with total page 18 pages. Available in PDF, EPUB and Kindle. Book excerpt: Concern over the potential effects of greenhouse gases such as carbon dioxide (CO2) on global climate has triggered research about ways to mitigate the release of these gases to the atmosphere. A project to study the engineering feasibility and costs of sequestering CO2 in deep, saline reservoirs was completed as part of a U.S. Department of Energy (DOE) program supporting research on novel technologies to mitigate greenhouse gas emissions. Study activities included a review of the status of existing technologies that could be used for CO2 sequestration, development of a preliminary engineering concept for accomplishing the required operations, and estimation of costs for sequestration systems. The primary components of the CO2 sequestration system considered are: · Capture of the CO2 from the flue gas · Preparation of the CO2 for transportation (compression and drying) · Transportation of the CO2 through a pipeline · Injection of the CO2 into a suitable aquifer. Costs are estimated for sequestration of CO2 from two types of power plants: pulverized coal with flue gas desulphurization (PC/FGD) and integrated coal gasification combined cycle (IGCC). The sensitivity of cost to a variety of transportation and injection scenarios was also studied. The results show that the engineering aspects of the major components of CO2 capture and geologic storage are well understood through experience in related industries such as CO2 production, pipeline transport, and subsurface injection of liquids and gases for gas storage, waste disposal, and enhanced oil recovery. Capital costs for capture and compression and the operational cost for compression are the largest cost components.

Download or read book Assessment of CO2 Sequestration and ECBM Potential of U S Coalbeds written by Scott R. Reeves and published by . This book was released on 2003 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: In October, 2000, the U.S. Department of Energy, through contractor Advanced Resources International, launched a multi-year government-industry R & D collaboration called the Coal-Seq project. The Coal-Seq project is investigating the feasibility of CO{sub 2} sequestration in deep, unmineable coalseams, by performing detailed reservoir studies of two enhanced coalbed methane recovery (ECBM) field projects in the San Juan basin. The two sites are the Allison Unit, operated by Burlington Resources, and into which CO{sub 2} is being injected, and the Tiffany Unit, operating by BP America, into which N{sub 2} is being injected (the interest in understanding the N{sub 2}-ECBM process has important implications for CO{sub 2} sequestration via flue-gas injection). The purposes of the field studies are to understand the reservoir mechanisms of CO{sub 2} and N{sub 2} injection into coalseams, demonstrate the practical effectiveness of the ECBM and sequestration processes, an engineering capability to simulate them, and to evaluate sequestration economics. In support of these efforts, laboratory and theoretical studies are also being performed to understand and model multi-component isotherm behavior, and coal permeability changes due to swelling with CO{sub 2} injection. This report describes the results of an important component of the overall project, applying the findings from the San Juan Basin to a national scale to develop a preliminary assessment of the CO{sub 2} sequestration and ECBM recovery potential of U.S. coalbeds. Importantly, this assessment improves upon previous investigations by (1) including a more comprehensive list of U.S. coal basins, (2) adopting technical rationale for setting upper-bound limits on the results, and (3) incorporating new information on CO{sub 2}/CH{sub 4} replacement ratios as a function of coal rank. Based on the results of the assessment, the following conclusions have been drawn: (1) The CO{sub 2} sequestration capacity of U.S. coalbeds is estimated to be about 90 Gt. Of this, about 38 Gt is in Alaska (even after accounting for high costs associated with this province), 14 Gt is in the Powder River basin, 10 Gt is in the San Juan basin, and 8 Gt is in the Greater Green River basin. By comparison, total CO{sub 2} emissions from power generation plants is currently about 2.2 Gt/year. (2) The ECBM recovery potential associated with this sequestration is estimated to be over 150 Tcf. Of this, 47 Tcf is in Alaska (even after accounting for high costs associated with this province), 20 Tcf is in the Powder River basin, 19 Tcf is in the Greater Green River basin, and 16 Tcf is in the San Juan basin. By comparison, total CBM recoverable resources are currently estimated to be about 170 Tcf. (3) Between 25 and 30 Gt of CO{sub 2} can be sequestered at a profit, and 80-85 Gt can be sequestered at costs of less than $5/ton. These estimates do not include any costs associated with CO{sub 2} capture and transportation, and only represent geologic sequestration. (4) Several Rocky Mountain basins, including the San Juan, Raton, Powder River and Uinta appear to hold the most favorable conditions for sequestration economics. The Gulf Coast and the Central Appalachian basin also appear to hold promise as economic sequestration targets, depending upon gas prices. (5) In general, the 'non-commercial' areas (those areas outside the main play area that are not expected to produce primary CBM commercially) appear more favorable for sequestration economics than the 'commercial' areas. This is because there is more in-place methane to recover in these settings (the 'commercial' areas having already been largely depleted of methane).

Download or read book Simulation Framework for Regional Geologic CO sub 2 Storage Along Arches Province of Midwestern United States written by and published by . This book was released on 2012 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: This report presents final technical results for the project Simulation Framework for Regional Geologic CO2 Storage Infrastructure along Arches Province of the Midwest United States. The Arches Simulation project was a three year effort designed to develop a simulation framework for regional geologic carbon dioxide (CO2) storage infrastructure along the Arches Province through development of a geologic model and advanced reservoir simulations of large-scale CO2 storage. The project included five major technical tasks: (1) compilation of geologic, hydraulic and injection data on Mount Simon, (2) development of model framework and parameters, (3) preliminary variable density flow simulations, (4) multi-phase model runs of regional storage scenarios, and (5) implications for regional storage feasibility. The Arches Province is an informal region in northeastern Indiana, northern Kentucky, western Ohio, and southern Michigan where sedimentary rock formations form broad arch and platform structures. In the province, the Mount Simon sandstone is an appealing deep saline formation for CO2 storage because of the intersection of reservoir thickness and permeability. Many CO2 sources are located in proximity to the Arches Province, and the area is adjacent to coal fired power plants along the Ohio River Valley corridor. Geophysical well logs, rock samples, drilling logs, and geotechnical tests were evaluated for a 500,000 km2 study area centered on the Arches Province. Hydraulic parameters and historical operational information was also compiled from Mount Simon wastewater injection wells in the region. This information was integrated into a geocellular model that depicts the parameters and conditions in a numerical array. The geologic and hydraulic data were integrated into a three-dimensional grid of porosity and permeability, which are key parameters regarding fluid flow and pressure buildup due to CO2 injection. Permeability data were corrected in locations where reservoir tests have been performed in Mount Simon injection wells. The geocellular model was used to develop a series of numerical simulations designed to support CO2 storage applications in the Arches Province. Variable density fluid flow simulations were initially run to evaluate model sensitivity to input parameters. Two dimensional, multiple-phase simulations were completed to evaluate issues related to arranging injection fields in the study area. A basin-scale, multiple-phase model was developed to evaluate large scale injection effects across the region. Finally, local scale simulations were also completed with more detailed depiction of the Eau Claire formation to investigate to the potential for upward migration of CO2. Overall, the technical work on the project concluded that injection large-scale injection may be achieved with proper field design, operation, siting, and monitoring. Records from Mount Simon injection wells were compiled, documenting more than 20 billion gallons of injection into the Mount Simon formation in the Arches Province over the past 40 years, equivalent to approximately 60 million metric tons CO2. The multi-state team effort was useful in delineating the geographic variability in the Mount Simon reservoir properties. Simulations better defined potential well fields, well field arrangement, CO2 pipeline distribution system, and operational parameters for large-scale injection in the Arches Province. Multiphase scoping level simulations suggest that injection fields with arrays of 9 to 50+ wells may be used to accommodate large injection volumes. Individual wells may need to be separated by 3 to 10 km. Injection fields may require spacing of 25 to 40 km to limit pressure and saturation front interference. Basin-scale multiple-phase simulations in STOMP reflect variability in the Mount Simon. While simulations suggest a total injection rate of 100 million metric tons per year (approximately to a 40% reduction of CO2 emissions from large p ...

Download or read book Greenhouse Gas Control Technologies written by Edward S. Rubin and published by . This book was released on 2005 with total page 1058 pages. Available in PDF, EPUB and Kindle. Book excerpt: Following the successful publication of the proceedings of 6th Green House Gas Control Technology conference (GHGT-6), Elsevier is proud to publish the proceedings from the 7th conference, held in Vancouver in September 2004. The Greenhouse Gas Control Technologies conference series has established itself as the foremost conference bringing together the international energy community, providing a forum for the discussion of the latest advances in the field of greenhouse gas control technologies.