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The Third Sustainable Earth Sciences Conference and Exhibition
- Conference date: October 13-15, 2015
- Location: Celle, Germany
- Published: 13 October 2015
41 - 48 of 48 results
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Feasibility Study on Seismic and CSEM Monitoring of CO2 Injection Based on Laboratory Acoustic and Resistivity Measurement
Authors J. Park, G. Sauvin, M. Soldal and B. BohloliSummaryIn this work, we apply a set of acoustic velocity and electrical resistivity measured during CO2 core flooding laboratory test in order to explore the sensitivity of field-scale data through a synthetic 1D model. We demonstrate the feasibility of monitoring CO2 injection into subsurface by geophysical means. So far, seismic and CSEM data were considered into the scope of work. In near future, we may also integrate gravity data.
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Solubility of Nitrogen and Oxygen Gas in Aqueous NaCl Solutions for Elevated Temperatures and Pressures
More LessSummaryCompressed air energy storage (CAES) is considered a possible option for storing energy from renewable production. Using geological porous formations for compressed air energy storage is viable. The solubility of compressed air in the highly mineralized formation water determines the total amount of dissolved gas and the magnitude of possible water-rock interactions. An accurate model for compressed air solubility under different temperature, pressure and salinity conditions is thus required to study the induced effects of compressed air energy storage in porous formations. Based on the principles of thermodynamics, we established the compressed air solubility model and expressed it as a polynomial formula, which consists of Henry’s constant, Poynting Factor, fugacity coefficient and activity coefficient, as well as partial pressure of each component in gas phase. By parameterization, we can directly use the model to work out solubility conveniently under various given conditions. For the model, the appropriate ranges of temperature, pressure and solution concentration are 273–373 K, 0.1–50 MPa, 0–5 mol/l of NaCl concentration. We have established a computer program for the model, which is also coupled with OpenGeoSys for reservoir simulation purposes and can thus be used in future work on CAES induced geochemical effects.
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No Short-term Attenuation of Methane Leaked into Shallow Aquifers - An Experimental Study
More LessSummaryA major concern about underground methane storage facilities culminates around effects of accidental leakages into shallow aquifers, especially if these are used for drinking water production. Amongst the biogeochemical reactions expected to follow such a leakage, sulfide generation is known to damage water supplies the most. Reduction of sulfate by methane oxidation also occurs in seafloor environments, which is much better known by both field and experimental studies.
Investigating the hydrogeochemical consequences in a shallow aquifer caused by a potential methane intrusion makes parametrization of models describing such processes possible. These findings should be considered at leakage monitoring and risk assessment of subsurface methane operations.
Flow-through column experiments were used to test different sediments percolated by different, methane-enriched groundwaters. These one-year-long experiments showed no significant oxidation of methane by oxygen, nitrate or sulfate, meaning that methane oxidation is inhibited in the studied system and time scale.
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Particle Swarm Optimization Inversion of Self Potential Anomaly for Detecting Coal Fires, a Case Study - Jharia Coal Field
Authors B.B. Singh, V. Srivardhan, S.K. Pal, S.K. Kanagaraju, S. Kumar and J. VaishSummaryDetection of coal fires at an early stage is very important for its control and mitigation operations. Coal fires induce fractures and cracks in the subsurface which accelerate the rate of combustion. In this work we demonstrate the usage of a novel approach in detecting coal fires and delineating these fractures using Self-Potential surveys and Particle Swarm Optimization inversion. The study area is take in the East Basuria colliery, Jharia Coal Field, Jharkhand, India and inversion results are compared with litho logs drilled in the region. The inversion scheme was tested on synthetic SP response in the presence of random noise. For the case study the causative source was modelled as inclined sheet like anomalies for SP survey undertaken in the region. The results demonstrate the robust performance of the algorithm and illustrates the usage of this novel approach in detecting coal fires for control and mitigation operations.
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3D Characterization of Saline Underground Formations with Investigative Geophysical Methods
Authors C. Hartmann, S. Uchtmann and D. OrlowskySummaryThe utilisation of the earths’ ground as one of the fundamental resources is one of the mankinds responsibility to secure sustainable conditions for human life on earth. There is an increasing demand for finding new natural resources as well as developing large natural underground capacities for the sustainable storage of these resources. Underground storage capacities may be furthermore used for other storage purposes: radioactive waste, carbon dioxide (CO2), water and energy (e.g. hydrothermal, gravitational).
For a more optimized utilization of saline formations as a location for new storage capacities new cavern structures need to be established in areas closer to lateral boundaries of the salt formation. Thus, the success of the development of new storage capacities highly depends on the quantity and quality of detailed structural information and the generation of a most realistic geological model.
New geophysical investigation technologies allow an integrated exploration of the inside and outside of complex saline formations such as salt domes. Salt formations are a favourable environment for numerous storage facilities. Two geophysical investigation technologies will be presented that appear to be significantly competent for the assessment of saline underground formations: 3D seismic reflection method, and 3D borehole ground penetrating radar (GPR) technique.
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CO2 Storage Potential of the Norwegian Continental Shelf
Authors M. Bjorheim, F. Riis, J.M. Mujezinovic and E. HallandSummaryA CO2 storage atlas of the Norwegian Continental Shelf (NCS) was elaborated by the Norwegian Petroleum Directorate (NPD) on request from the Ministry of Petroleum and Energy in the period 2011 to 2013 (npd.no).
The atlas documents the distribution and properties of the main aquifers, which are evaluated to have an interesting storage potential for CO2. The procedure for compiling the atlas was to screen all reservoir formations between 700 and 3500 m depth. In order to avoid conflict of interests with the petroleum industry, studies of CO2 injection into saline aquifers were mainly restricted to areas where the generation and migration of hydrocarbons is considered to be limited.
The results/ atlas material is now available on an interactive map called CO2 FactMap. This application gives you the possibility to explore the assessment result, and is also suited for mobile devices.
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Mapping of CO2 Storage Possibilities on The Norwegian Continental Shelf
More LessSummaryThe Norwegian Petroleum Directorate (NPD) has mapped and evaluated possible storage sites on the Norwegian Continental Shelf (NCS). The evaluation is published in three CO2 Storage Atlases: Norwegian part of the North Sea (2011), the Norwegian Sea (2013) and the Barents Sea (2013) (Halland et al.). The study is based on detailed work on all relevant geological formations and hydrocarbon fields on the NCS. In total 27 geological formations have been individually assessed and grouped into saline aquifers. In addition, several mapped and dry-drilled structures and abandoned hydrocarbon fields have been evaluated. The largest storage capacities are mapped in the mature part of the North Sea, where several saline aquifers and basins are evaluated. Compared with the areas in the North Sea and the Norwegian Sea, the Barents Sea areas is an immature petroleum province, with high exploration activity.
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Experimental Tests and Modeling of Mudstone Cap-rock Behavior in H2s-Co2-Brine Systems
Authors K. Labus, K. Suchodolska and P. BujokSummaryAcid gas interactions with rocks are currently of interest due to greenhouse effect abatement, enhanced oil and gas recovery and energized fluid fracturing of unconventional formations. We performed a study, enabling the hydrochemical models, calibrated on the basis of experiments, considering the impact of CO2 and, H2S and their mixture on low permeability rocks, representative for the Upper Silesian Coal Basin (Poland and Czech Republic). Rock samples were placed in the autoclave filled with brine, and acid gas, to reproduce water-rock-gas interactions at the PVT regime of possible storage site. SEM microscopy and EDX spectroscopy of reacted samples revealed significant changes in their structure and composition. Dissolution of skeletal grains, was the most distinct in carbonates and chlorite, and led to the increase of cap-rocks porosity. Geochemical modeling, based on the experimental results, allowed for assessment of volume and amount of secondary minerals during simulated reactions in 10 000 years of storage, and amounts of gases sequestered. Maximum calculated mineral-trapping capacity for the cap-rocks, calculated based on the results of kinetic modeling, reached 28.2 kgCO2/m3 for pure CO2 injection model, 20.8 kgCO2/m3 and 5,8 kg H2S /m3 for CO2+ H2S co-injection, 5,9 kg H2S /m3 for pure H2S model.
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