Download or read book A Site Characterization Study for CO2 Injection Into the Oriskany Formation written by William Carr and published by . This book was released on 2023 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: The Oriskany Sandstone, defined as a quartz arenite aquifer formation, is located throughout the Appalachian Basin, with primary oil and gas production in New York, Pennsylvania, Ohio, and West Virginia. For years, it has been used as a hydrocarbon production and gas storage formation due to its favorable petrophysical properties. The structural complexity of the Oriskany is mainly present along the Appalachian Mountain range due to the stresses involved during their orogeny. Because of this, structural and stratigraphic influence of the formation causes regions of low permeability and porosity, thus leading to unfavorable conditions for both oil and gas production and injection. This study looks to focus on the Oriskany Sandstone region to explore the feasibility of CO2 sequestration. With the imperative to reduce CO2 emissions throughout the world, especially within the United States, there is a shift in focus from production of oil and gas to the use of the subsurface for carbon sequestration. Proof of long-term safety and efficiency is key to development of CO2 sequestration projects and requires proper coring, logging, and seismic analysis for deployment of well plans within specified regions. Techniques for tracking the CO2 and pressure plumes are necessary. This study focuses on analyzing the limited information available for a region of the Oriskany formation and synthesizes a reservoir model to define the feasibility of the Oriskany formation as a sequestration site in North Central Pennsylvania. The low values of permeability and porosity in the region lead to the consideration of hydraulic fracturing to attempt to expand the contact area into the reservoir. The significance of this study, which uses seismic, log, and geostatistical analysis to populate the reservoir simulator, determines the injectability of the formation and its storage capacity. Provided the limited data to characterize the formation in the vicinity of an existing well, a range of analyses was conducted, which include Bayesian analysis to populate a reservoir model with petrophysical properties and sensitivity analysis with respect to well injection capabilities. These analyses provide a wide range of results to compare when more data becomes available to better understand the formation at the location of the well. In addition, economics are considered, including the influence of monitoring wells and the influence of abandoned wells in the vicinity of the injection well. With an ammonia plant acting as the source of CO2, producing approximately 3,200 tons of CO2 per day, various injection cycles and fracturing scenarios are analyzed, resulting in anywhere from 6% to 25% dissolution into the formation brines, a key component when attempting to trap the CO2 over a long term. Although the current study's analysis of this area of the Oriskany may not be suited for CO2 sequestration, further evaluation of the effects of natural fractures, heavily present within this area, needs to be performed before a final decision is made.

Download or read book Site Characterization for CO2 Geologic Storage and Vice Versa The Frio Brine Pilot as a Case Study written by Christine Doughty and published by . This book was released on 2006 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: Careful site characterization is critical for successfulgeologic sequestration of CO2, especially for sequestration inbrine-bearing formations that have not been previously used for otherpurposes. Traditional site characterization techniques such asgeophysical imaging, well logging, core analyses, interference welltesting, and tracer testing are all valuable. However, the injection andmonitoring of CO2 itself provides a wealth of additional information. Rather than considering a rigid chronology in which CO2 sequestrationoccurs only after site characterization is complete, we recommend thatCO2 injection and monitoring be an integral part of thesite-characterization process. The advantages of this approach arenumerous. The obvious benefit of CO2 injection is to provide informationon multi-phase flow properties, which cannot be obtained from traditionalsitecharacterization techniques that examine single-phase conditions. Additionally, the low density and viscosity of CO2 compared to brinecauses the two components to flow through the subsurface differently, potentially revealing distinct features of the geology. Finally, tounderstand sequestered CO2 behavior in the subsurface, there is nosubstitute for studying the movement of CO2 directly. Making CO2injection part of site characterization has practical benefits as well. The infrastructure for surface handling of CO2 (compression, heating, local storage) can be developed, the CO2 injection process can bedebugged, and monitoring techniques can be field-tested. Prior to actualsequestration, small amounts of CO2 may be trucked in. Later, monitoringaccompanying the actual sequestration operations may be used tocontinually refine and improve understanding of CO2 behavior in thesubsurface.

Download or read book CO2 Injection and Reservoir Characterization written by Kelli A. McGuire and published by . This book was released on 2009 with total page 115 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Silurian Clinton Sandstone Reservoir Characterization for Evaluation of CO2 EOR Potential in the East Canton Oil Field Ohio written by and published by . This book was released on 2009 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: 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.

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 2018-07-21 with total page 0 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 Site Characterization to Perform a CO 2 Injection Experiment in a Shallow Aquifer for Testing the Feasibility of Geoelectrical Process Monitoring written by Hendrik Lamert and published by . This book was released on 2013 with total page 172 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Geochemical Impact of Super critical C02 Injection Into the St Peter Sandstone Formation Within the Illinois Basin written by Richard Michael Thomas and published by . This book was released on 2014 with total page 134 pages. Available in PDF, EPUB and Kindle. Book excerpt: Deep injection of waste CO2 and fluids from regional energy plants into the St. Peter Formation of the Illinois Basin, could effectively provide long term deep geologic storage. This research aims to explore the viability of this proposed injection. There are some basic criteria that must be met to effectively store waste in a geologic reservoir. First, the reservoir must have sufficient porosity and permeability for both injectivity and for migration of the injected fluid through the reservoir. Second, the reservoir must be overlain by some form of impermeable seal or cap layer(s). Third, the reservoir should be sufficiently isolated from interaction with surface and near surface water. Finally, the formation must contain enough storage volume to handle significant amounts of injected material. Massive sandstone formations that host large saline aquifers have the potential to serve as high capacity storage sites. Much of the research targeting the potential suitability and storage capacity attributes of these formations has been promising, but reproducibility of the results has been less than ideal. Some of this variability has been attributed to petrological differences in the sandstone reservoirs that are not readily evident when studying the target formation over a geographically significant area. Based on the criteria, a promising candidate for injection and storage is the St. Peter Sandstone of the Illinois Basin. This study investigates the viability of liquefied CO2 storage within the St. Peter Sandstone on a micro scale. Initial porosity and permeability of the formation plug samples ranged from 16% to 19% and 26 to 981 millidarcies (mD), respectively. The wide difference in permeability is attributed to variations in strength of the cement, in this case quartz overgrowth in the sandstone. This preliminary evidence indicates that the storage capacity of the formation will remain constant or increase depending on injection location, suggesting that the St. Peter Formation will lend itself well to future storage.

Download or read book Characterization of Pliocene and Miocene Formations in the Wilmington Graben Offshore Los Angeles for Large Scale Geologic Storage of CO2 written by and published by . This book was released on 2014 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: Geomechanics Technologies has completed a detailed characterization study of the Wilmington Graben offshore Southern California area for large-scale CO2 storage. This effort has included: an evaluation of existing wells in both State and Federal waters, field acquisition of about 175 km (109 mi) of new seismic data, new well drilling, development of integrated 3D geologic, geomechanics, and fluid flow models for the area. The geologic analysis indicates that more than 796 MMt of storage capacity is available within the Pliocene and Miocene formations in the Graben for midrange geologic estimates (P50). Geomechanical analyses indicate that injection can be conducted without significant risk for surface deformation, induced stresses or fault activation. Numerical analysis of fluid migration indicates that injection into the Pliocene Formation at depths of 1525 m (5000 ft) would lead to undesirable vertical migration of the CO2 plume. Recent well drilling however, indicates that deeper sand is present at depths exceeding 2135 m (7000 ft), which could be viable for large volume storage. For vertical containment, injection would need to be limited to about 250,000 metric tons per year per well, would need to be placed at depths greater than 7000ft, and would need to be placed in new wells located at least 1 mile from any existing offset wells. As a practical matter, this would likely limit storage operations in the Wilmington Graben to about 1 million tons per year or less. A quantitative risk analysis for the Wilmington Graben indicate that such large scale CO2 storage in the area would represent higher risk than other similar size projects in the US and overseas.

Download or read book Modeling of Geomechanical Proceses During Injection in Amultilayered Reservoir caprock System and Implications on Sitecharacterization written by Jens Birkholzer and published by . This book was released on 2006 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: In this paper we present results of a numerical simulationof the potential for fault reactivation and hydraulic fracturingassociated with CO2 injection in a multilayered reservoir-caprock system, and discuss its implications on site characterization. The numericalsimulation is performed using the coupled processes simulator TOUGH-FLAC(Rutqvist et al. 2002, Rutqvist and Tsang, 2003), and is an extension ofearlier numerical studies of a single caprock system (Rutqvist and Tsang,2002). In this study, CO2 is injected for 30 years in a 200 meter thickpermeable saline water formation located at 1600 meters depth (Figure 1). The injection formation is overlaid by several layers of caprocks, whichare intersected by a permeable fault zone allowing upward migration ofthe CO2 within the multilayered system (see Table 1 for materialproperties). The potential for fault slip or fracturing are calculated, based on the time-dependent evolution and local distribution of fluidpressure and the three-dimensional stress field, including importantporo-elastic stresses. The numerical results are discussed with respect tothe site-characterization strategy that would be recommended forevaluation of maximum sustainable injection pressure at an industrial CO2injection site.

Download or read book Constraining the Data and Investment Needs for Obtaining a Carbon Dioxide Injection Permit in the United States written by Taylor H. Barnhart and published by . This book was released on 2021 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: To keep global temperature increases below 2 ̊C, utilization of carbon capture and storage (CCS) must proliferate, but the U.S. has only issued two Underground Injection Control (UIC) Class VI permits for carbon dioxide (CO2) storage in saline formations. An impediment to CCS development is uncertainty regarding investment requirements for selecting and characterizing a storage site to obtain an injection permit. A Class VI permit application requires adequate site characterization to ensure that no underground sources of drinking water (USDWs) will be negatively impacted by CO2 storage. Collection of characterization data involves financial expenditures at different project development investment gates. Here these gates are designated as Feasibility, Site(s) Selection, Detailed Characterization, and Permit Preparation. To estimate the potential investments at each gate, a novel approach was developed and applied to 31 case study storage sites in the Southeast Regional CO2 Utilization and Storage Acceleration Partnership (SECARB-USA) region. This approach included development of a data needs framework, which consists of data required under Class VI regulations, data for multiphase fluid flow modeling, and data for development of a site monitoring program. Two site evaluation rubrics were derived from this data needs framework to assess the urgency and availability of data at a site. The cost of site characterization is a function of the data density (data availability) and data urgency of a site. These rubrics were used to assign scores to the 42 data needs in the data needs framework, and the subsequent data need scores were referenced to a characterization activity cost index to estimate the costs at each investment gate for each site. Results indicate that the total characterization cost across the case study sites are nearly identical unless high cost characterization activities, such as conducting a 3-D seismic survey or drilling, coring, and testing a characterization well, are unnecessary because the data already exist. Existence of these data lowers project risk as early investment gates can be passed with lower investments. Other trends in the dataset reinforce the value of stacked storage sites for reducing costs and existing well penetrations for providing subsurface data

Download or read book Characterization of the Mt Simon Sandstone in Southwest Ohio for CO2 Sequestration written by Nicholas Leeper and published by . This book was released on 2012 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: Abstract: CO2 sequestration in deep subsurface environments has been proposed as an innovative strategy to lessen the impact of burning fossil fuels on Earth's atmosphere. In order for CO2 sequestration to be effective, the target formation must have sufficient porosity, permeability, depth and thickness to store CO2. The Mt. Simon Sandstone, a Cambrian arenite to arkosic sandstone in western Ohio may provide appropriate physical and mineralogical properties for effective CO2 sequestration. The goal of this research is to evaluate the Mt. Simon sandstone's volumetric capacities including connected porosity, pore size and pore volume, as well as to determine mineralogy and digenetic processes, to assess the formation's suitability for CO2 sequestration. Samples and measurements were performed on the ODGS 2627 Warren well, and on the ODGS 2843 Armco well to evaluate spatial continuity and vertical heterogeneity. Porosity and pore size distribution measurements were determined using mercury porosimetry and BET gas sorption. Grain size measurements were determined through the use of light microscopy. Results show a porosity range of 1-25%, a connected pore size range of 5-1612 nm, and a decrease in grain size from the base of the Mt. Simon Sandstone through the overlying Eau Claire Formation. Variations in porosity and pore size show that the formation is heterogeneous, changing substantially on a macro scale. Changes in grain size are representative of a transgressive depositional system. Mineralogical characterization of the target Mt. Simon Sandstone and surrounding formations used powder X-ray diffraction, SEM, and polarized light microscopy to show lithologic variations from arenite to feldspathic sandstone, with cementation that included quartz, illite, chlorite, carbonate, iron and titanium oxides, and iron sulfides. Results show heterogeneity in each formation that occurs laterally. Comparison of lithology and pore space reveals that mineralogy and diagenetic processes are the main factors controlling available pore space, and that clean quartz arenite provide the greatest porosity. CO2 storage calculations show that the Warren well location could hold up to 61.0 million metric tons, however this would not provide enough storage space to sustain a long term coal fire power plant.

Download or read book Modeling of Near Surface Leakage and Seepage of CO2 for Risk Characterization written by and published by . This book was released on 2004 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: The injection of carbon dioxide (CO2) into deep geologic carbon sequestration sites entails risk that CO2 will leak away from the primary storage formation and migrate upwards to the unsaturated zone from which it can seep out of the ground. We have developed a coupled modeling framework called T2CA for simulating CO2 leakage and seepage in the subsurface and in the atmospheric surface layer. The results of model simulations can be used to calculate the two key health, safety, and environmental (HSE) risk drivers, namely CO2 seepage flux and nearsurface CO2 concentrations. Sensitivity studies for a subsurface system with a thick unsaturated zone show limited leakage attenuation resulting in correspondingly large CO2 concentrations in the shallow subsurface. Large CO2 concentrations in the shallow subsurface present a risk to plant and tree roots, and to humans and other animals in subsurface structures such as basements or utility vaults. Whereas CO2 concentrations in the subsurface can be high, surfacelayer winds reduce CO2 concentrations to low levels for the fluxes investigated. We recommend more verification and case studies be carried out with T2CA, along with the development of extensions to handle additional scenarios such as calm conditions, topographic effects, and catastrophic surface-layer discharge events.

Download or read book Geomechanical Characterization of Reservoir Cap Rocks for CO2 Sequestration written by Sudarshan Govindarajan and published by . This book was released on 2012 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: "Geological sequestration of CO2 has been identified as one method to reduce global emissions of CO2 and achieve lower levels of CO2 concentrations in the atmosphere. Geological formations have to be assessed in terms of their capacity, sealing capabilities and economic feasibility before CO2 sequestration can commence. Potential leakage of injected CO2 from the reservoir formation could occur due to natural or injection induced faults or fractures in the reservoir or sealing formations. As part of a potential leakage investigation a geomechanical characterization which refers to the assessment of the in-situ stress conditions, rock strength and stiffness properties of the formations of interest helps to determine the seal integrity before, during and after injection of CO2 into the formation. In this study a rock mechanical testing apparatus was designed and commissioned, and the geological formations of interest were analyzed by conducting rock mechanical testing including Brazilian tensile tests, uniaxial tests and single stage triaxial tests accompanied by sonic velocity tests. Mohr Coulomb and Hoek Brown criteria were used to determine failure characteristics. The study helps establish the safe injection pressure. It was found that the formations had a greater likelihood of undergoing tensile failure than shear failure. Although laboratory tests revealed that the capping rock has a higher tensile strength than the reservoir rock, the combination of in-situ stress and pore pressure conditions makes the cap rock susceptible to failure very close to the tensile failure value of the reservoir rock and hence the injection pressures have to be maintained just below that of the tensile failure value of the reservoir rock"--Abstract, leaf iii

Download or read book Special Issue Site Characterization for Geological Storage of CO2 written by Jens Birkholzer and published by . This book was released on 2008 with total page 4 pages. Available in PDF, EPUB and Kindle. Book excerpt:

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 Geologic Characterization and Modeling for Quantifying CO2 Storage Capacity of the High Island 10 L Field in Texas State Waters Offshore Gulf of Mexico written by Omar Ramirez Garcia and published by . This book was released on 2019 with total page 32 pages. Available in PDF, EPUB and Kindle. Book excerpt: Carbon dioxide capture and storage (CCS) is a promising technology for mitigating climate change by reducing CO2 emissions to the atmosphere and injecting captured industrial emissions into deep geologic formations. Deep subsurface storage in geologic formations is similar to trapping natural hydrocarbons and is one of the key components of CCS technology. The quantification of the available subsurface storage resource is the subject of this research project. This study focuses on site-specific geologic characterization, reservoir modeling, and CO2 storage resource assessment (capacity) of a depleted oil and gas field located on the inner continental shelf of the Gulf of Mexico, the High Island 10L field. lower Miocene sands in the Fleming Group beneath the regional transgressive Amphistegina B shale have extremely favorable geologic properties (porosity, thickness, extent) and are characterized in this study utilizing 3-D seismic and well logs. Key stratigraphic surfaces between maximum flooding surfaces (MFS-9 to MFS-10) demonstrate how marine regression and transgression impact the stacking pattern of the thick sands and overlying seals, influencing the overall potential for CO2 storage. One of the main uncertainties when assessing CO2 storage resources at different scales is to determine the fraction of the pore space within a formation that is practically accessible for storage. The goal of the modeling section of this project is to address the uncertainty related to the static parameters affecting calculations of available pore space by creating facies and porosity geostatistical models based on the spatial variation of the available data. P50 values for CO2 storage capacity range from 37.56 to 40.39 megatonnes (Mt), showing a narrow distribution of values for different realizations of the geostatistical models. An analysis of the pressure build-up effect on storage capacity was also performed, showing a reduction in capacity. This research further validates the impact of the current carbon tax credit program (45Q), applied directly to the storage resources results for the High Island field 10L using a simple NPV approach based on discounted cash flows. Several scenarios are assessed, where the main variables are the duration of the applicability of the tax credit, number of injection wells, and total storage capacity. Results are measured in terms of the cost of capture required for a project to be economic, given previous assumptions.

Download or read book Silurian Clinton Sandstone Reservoir Characterization for Evaluation of CO2 EOR Potential in the East Canton Oil Field Ohio written by Ronald A. Riley and published by . This book was released on 2011 with total page 41 pages. Available in PDF, EPUB and Kindle. Book excerpt: