[PDF] Geochemical Investigation And Quantification Of Potential Co2 Storage Within The Arbuckle Aquifer Kansas eBook

Author : Brent D. Campbell
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Page : pages
File Size : 40,26 MB
Release : 2015
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With the ever-rising atmospheric concentrations of CO2 there arises a need to either reduce emissions or develop technology to store or utilize the gas. Geologic carbon storage is a potential solution to this global problem. This work is a part of the U.S. Department of Energy small-scale pilot studies investigating different areas for carbon storage within North America, with Kansas being one of them. This project is investigating the feasibility for CO2 storage within the hyper-saline Arbuckle aquifer in Kansas. The study incorporates the investigation of three wells that have been drilled to basement; one well used as a western calibration study (Cutter), and the other two as injection and monitoring wells (Wellington 1-28 and 1-32). Future injection will occur at the Wellington field within the Arbuckle aquifer at a depth of 4,900-5,050 ft. This current research transects the need to understand the lateral connectivity of the aquifers, with Cutter being the focus of this study. Three zones are of interest: the Mississippian pay zone, a potential baffle zone, and the Arbuckle injection zone. Cored rock analyses and analyzed formation water chemistry determined that at Wellington there exists a zone that separated the vertical hydrologic flow units within the Arbuckle. This potential low porosity baffle zone within the Arbuckle could help impede the vertical migration of the buoyant CO2 gas after injection. Geochemical analysis from formation water within Cutter indicates no vertical separation of the hydrologic units and instead shows a well-mixed zone. The lateral distance between Cutter and Wellington is approximately 217 miles. A well-mixed zone would allow the CO2 plume to migrate vertically and potentially into potable water sources. Formation brine from Cutter was co-injected with supercritical CO2 into a cored rock from within the Arbuckle (7,098 ft.). Results show that the injected CO2 preferentially preferred a flow pathway between the chert nodules and dolomite. Post reaction formation chemistry of the brine showed the greatest reactivity occurring with redox sensitive species. Reactivity of these species could indicate that they will only be reactive on the CO2 plumes front, and show little to no reactivity within the plume.

Author : Robinson Barker
Publisher :
Page : pages
File Size : 16,90 MB
Release : 2012
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In response to increasing concerns over release of anthropogenic greenhouse gases the Arbuckle saline aquifer in south-central Kansas has been proposed as a potential site for geologic storage for CO2. Two wells (KGS 1-32 and 1-28) have been drilled to provide data for site specific determination of the storage potential of the Arbuckle. Cores from specific depths within Arbuckle (4164`-5130`) were utilized for study and flow-through experiments. Examination of formation rocks by thin section studies, SEM, XRD and CT scans was carried out to characterize the mineralogy of the core. Dominant mineralogy throughout the formation is dolomite with large chert nodules and occasional zones with pyrite and argillaceous minerals. Carbonate-silica contacts contain extensive heterogeneity with sulfide minerals and argillaceous material in between. Extensive vugs and microfractures are common. This study focuses on three zones of interest: the Mississippian pay zone (3670`-3700`), a potential baffle in Arbuckle (4400`-4550`) and the proposed CO2 injection zone (4900`-5050`). Drill stem tests and swabbed brine samples collected from 13 depths throughout the aquifer reveal a saline brine (~50,000-190,000 TDS) dominated by Na, Ca2 and Cl−. Elemental ratios of major cations with Cl− demonstrate a typical saline aquifer system. Cl/Br ratios reveal mixing between primary and secondary brines within the aquifer. Ca/Cl and Mg/Cl ratios suggest effect of dolomitization within the brines. [delta]18O and [delta]2H isotopes and Li/Cl ratios in the brine suggest the separation of upper and lower Arbuckle by a baffle zone. Swabbed waters provide Fe speciation data and reveal the importance of it in the system. Laboratory experiments carried out at 40°C and 2100 psi using formation core plug and collected brine identify reaction pathways to be anticipated when supercritical CO2 is injected. Results showed fluctuating chemistries of elements with Ca2+, Mg2+, Na+ and Cl− increasing during the first 15 hours, while Fe, S, and SO42− decrease. For the next 15 hours a reverse trend of the same elements were observed. Alkalinity and pH show inverse relationship throughout the experiment. We conclude that dominant reactions will occur between brine, CO2 and dolomite, calcite, chert, pyrite and argillaceous minerals. There is no perceived threat to freshwater resources in Kansas due to CO2 injection.

Author : U.S. Department of the Interior
Publisher : CreateSpace
Page : 56 pages
File Size : 34,74 MB
Release : 2014-03-04
Category : Reference
ISBN : 9781496120540

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A geochemical reconnaissance investigation of the Arbuckle-Simpson aquifer in south-central Oklahoma was initiated in 2004 to characterize the ground-water quality at an aquifer scale, to describe the chemical evolution of ground water as it flows from recharge areas to discharge in wells and springs, and to determine the residence time of ground water in the aquifer. Thirty-six water samples were collected from 32 wells and springs distributed across the aquifer for chemical analysis of major ions, trace elements, isotopes of oxygen and hydrogen, dissolved gases, and age-dating tracers.

Author : Robert Allen Swain
Publisher :
Page : 148 pages
File Size : 48,24 MB
Release : 2015
Category : Aquifers
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"The feasibility of sequestering CO2 in saline aquifers of Lamotte Formation sandstone was investigated at wells located near Thomas Hill power plant, Moberly, MO and Sioux City Power Plant in Florissant, MO. Governing factors of using aquifers for CO2 disposal include water salinity, potential for carbonic acid buffering, rate of precipitation of carbonate minerals following CO2 introduction into the host aquifer, and the integrity of the Davis and Derby-DoeRun shale as a trap rock to prevent migration of the CO2 phase and carbonic acid into the overlying potable Ozark Aquifer. Both in situ and laboratory methods were used to determine formation water composition and reactivity of rock samples under accelerated H2O + CO2 experiment conditions. Major element cations and anions were determined for the aquifer water as well as ions released from altered rock samples. X-Ray Diffraction (XRD) determined clay phases present in reservoir and trap rocks, and Scanning Electron Microscopy-Energy Dispersive Spectroscopy (SEM-EDS) was used to examine rock samples before and after CO2 reactions. Salinity of each target aquifer had total dissolved solid (TDS) concentrations over 40,000 mg/kg, above the EPA limit of 10,000 mg/kg to qualify as a class VI injection site. Upon exposure to CO2 + H2O in a high pressure and temperature environment, some samples displayed visible iron alteration and precipitation of spherical carbonate phases of undetermined identity. Davis samples showed variable reactivity with carbonic acid, buffering from a baseline pH of 3.90 up to pH 6.88. The slowest buffer was to pH 6.04 over 205 days, and had average Ca and Mg releases of 418 and 135 ppm, respectively. Further research is needed to test the integrity of the Davis Formation as a viable seal"--Abstract, page iii.

Author :
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Page : pages
File Size : 14,93 MB
Release : 2008
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One promising approach to reduce greenhouse gas emissions is injecting CO2 into suitable geologic formations, typically depleted oil/gas reservoirs or saline formations at depth larger than 800 m. Proper site selection and management of CO2 storage projects will ensure that the risks to human health and the environment are low. However, a risk remains that CO2 could migrate from a deep storage formation, e.g. via local high-permeability pathways such as permeable faults or degraded wells, and arrive in shallow groundwater resources. The ingress of CO2 is by itself not typically a concern to the water quality of an underground source of drinking water (USDW), but it will change the geochemical conditions in the aquifer and will cause secondary effects mainly induced by changes in pH, in particular the mobilization of hazardous inorganic constituents present in the aquifer minerals. Identification and assessment of these potential effects is necessary to analyze risks associated with geologic sequestration of CO2. This report describes a systematic evaluation of the possible water quality changes in response to CO2 intrusion into aquifers currently used as sources of potable water in the United States. Our goal was to develop a general understanding of the potential vulnerability of United States potable groundwater resources in the event of CO2 leakage. This goal was achieved in two main tasks, the first to develop a comprehensive geochemical model representing typical conditions in many freshwater aquifers (Section 3), the second to conduct a systematic reactive-transport modeling study to quantify the effect of CO2 intrusion into shallow aquifers (Section 4). Via reactive-transport modeling, the amount of hazardous constituents potentially mobilized by the ingress of CO2 was determined, the fate and migration of these constituents in the groundwater was predicted, and the likelihood that drinking water standards might be exceeded was evaluated. A variety of scenarios and aquifer conditions was considered in a sensitivity evaluation. The scenarios and conditions simulated in Section 4, in particular those describing the geochemistry and mineralogy of potable aquifers, were selected based on the comprehensive geochemical model developed in Section 3.

Author : Ian E. Andree
Publisher :
Page : pages
File Size : 29,44 MB
Release : 2017
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Domestic and irrigation well water quality in south-central Kansas is threatened by multiple sources of contamination including CO2-EOR activities, evaporite dissolution and oilfield brine release. This research identifies potential groundwater flow paths for contaminant migration in a concentrated area mixed with oil, injection, irrigation and domestic wells. Groundwater (GW) sampling took place before and after CO2 injections into the Mississippian in to assess temporal changes in water quality in a ~2 mile radius around injection well KGS 2-32. Samples were analyzed for stable isotopes, rare earth elements (REE), major and trace ions, dissolved organic carbon (DOC) with a select few analyzed for dissolved CO2 and hydrocarbons. Results of major ion chemistry reveal an evaporite control on geochemistry in wells screened within the paleoterrace as opposed to the incised valley. Bedrock channeling due to erosional scouring of the paleovalley is speculated to have led to secondary porosity thereby increasing GW flow. Similar stable isotopic and Br/Cl mass ratios between SW-3, Shepherd and Zehr indicate water is similarly sourced; lower total dissolved solids within incised valley could result from dilution from infiltration through overburden sediments. Br/Cl, SO4/Cl, Na/Cl and (Ca+Mg)/Na ratios indicate Shepherd, Zehr and SW-3 are possibly impacted by a recent salt plume movement through this portion of the shallow aquifer. An increase in total dissolved solids and Mg/Ca ratios with temperatures less than 25°C over a 25 to 200 ft. depth interval into the Permian Shale of the uplands could have resulted from increasing calcitization and reduction in effective porosity. Dissolved REEs showed most domestic and surface waters contain similar signatures, indicating similarly sourced water. Additionally, there was no CO2 leakage found within the sampling timeframe and a future leaked plume may be impeded by decreasing porosity from current secondary mineralization processes taking place in the Permian Shale.

Author : Sang Hyon Han
Publisher :
Page : 176 pages
File Size : 30,37 MB
Release : 2015
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The effects of chemical interaction between injected CO2, brine, and formation rocks are often ignored in sequestration studies because chemical reactions are assumed to be localized to carbonate rocks that make up only a small proportion of the potential reservoirs. It is conjectured in this work that long-term exposure of certain types of clays and cement material to CO2-brine mixtures can induce chemical reactions and subsequent alteration of rock properties that can be subsequently detected in time-lapse seismic surveys. This is demonstrated using a case-study structured after the Cranfield field injection site. Geochemical alterations of the reservoir rock are quantified by performing reactive transport simulations and subsequently using rock physics models to translate the altered petrophysical properties into seismic responses. The study quantifies the long-term geochemical effects of CO2 injection on the seismic response and conversely, presents an approach to invert the reservoir regions contacted by the CO2-saturated brine based on the observed seismic response. Time lapse or passive seismic monitoring is an effective method for mapping the progress of the CO2 plume through the subsurface. But, because of the lack of resolution of the seismic information, it is necessary to use the seismic information together with prior geologic knowledge about the surface in order to identify if there is any migration of CO2 into regions that might be deemed sensitive e.g. overlying aquifers or faults. Because of uncertainties in the prior geologic description of the reservoir, the feasibility of implementing a model selection process is explored in this work. The model selection procedure utilizes the observed well data and reference seismic map to select a subset of models. The flow simulation of CO2 injection and forward seismic modeling were repeated for the newly generated reservoir models, and the seismic responses were compared for the reaction and non-reaction cases. The study showed that the effects of geochemical reactions on petrophysical properties and resultant spatial distribution of fluid saturation were visible in the seismic response. Major differences in seismic responses were detected in regions of the reservoir where significant amount of minerals were dissolved and precipitated. These regions were at the top of the reservoir due to the reactions caused by the buoyant CO2 plume. The presence of carbonate facies, even in small proportion, plays an important role in geochemical reactions and their effect is manifested at the seismic scale. The unique model selection methodology presented in this thesis is efficient at detecting the important features in the seismic and injection response that is induced by the geochemical alterations occurring in the reservoir. The results of this time-lapse study can provide new interpretation of events observed in time-lapse seismic data that might lead to a better assessment of leakage pathways and other risks.

Author : Mark W. Thomas
Publisher :
Page : pages
File Size : 43,96 MB
Release : 2010
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ABSTRACT: Geologic sequestration of carbon dioxide (CO2) in a deep, saline aquifer is being proposed for a power-generating facility in Florida as a method to mitigate contribution to global climate change from greenhouse gas (GHG) emissions. The proposed repository is a brine-saturated, dolomitic-limestone aquifer with anhydrite inclusions contained within the Cedar Keys/Lawson formations of Central Florida. Thermodynamic modeling is used to investigate the geochemical equilibrium reactions for the minerals calcite, dolomite, and gypsum with 28 aqueous species for the purpose of determining the sensitivity of mineral precipitation and dissolution to the temperature and pressure of the aquifer and the salinity and initial pH of the brine. The use of different theories for estimating CO2 fugacity, solubility in brine, and chemical activity is demonstrated to have insignificant effects on the predicted results. Nine different combinations of thermodynamic models predict that the geochemical response to CO2 injection is calcite and dolomite dissolution and gypsum precipitation, with good agreement among the quantities estimated. In all cases, CO2 storage through solubility trapping is demonstrated to be a likely process, while storage through mineral trapping is predicted to not occur. Over the range of values examined, it is found that net mineral dissolution and precipitation is relatively sensitive to temperature and salinity, insensitive to CO2 injection pressure and initial pH, and significant changes to porosity will not occur.