共查询到20条相似文献,搜索用时 31 毫秒
1.
Peter H. Israelsson Aaron C. Chow E. Eric Adams 《International Journal of Greenhouse Gas Control》2010,4(2):262-271
This paper evaluates the expected environmental impact of several promising schemes for ocean carbon sequestration by direct injection of CO2, and serves as a major update to the assessment by Auerbach et al. (1997) and Caulfield et al. (1997) of water quality impacts and the induced mortality to zooplankton. Three discharge approaches are considered, each designed to maximize dilution over the water column: a point release of negatively buoyant CO2 hydrate particles from a moving ship; a stationary point release of CO2 hydrate particles forming a sinking plume; and a long, bottom-mounted diffuser discharging buoyant liquid CO2 droplets. Two of these scenarios take advantage of the enhanced dilution offered by CO2 hydrate particles, and are based on recent laboratory and field studies on the formation and behavior of such particles. Overall, results suggest that it is possible with present or near present technology to engineer discharge configurations that achieve sufficient dilution to largely avoid acute impacts. In particular, the moving ship hydrate discharge is identified as the most promising due to its operational flexibility. In addition to lethal effects, sub-lethal and ecosystem effects are discussed qualitatively, though not analyzed quantitatively. Our main conclusion is that ocean carbon sequestration by direct injection should not be dismissed as a climate change mitigation strategy on the basis of environmental impact alone. Rather, it can be considered as a viable option for further study, especially in regions where geologic sequestration proves impractical. 相似文献
2.
Yoshio Masuda Yasuhiro Yamanaka Yoshikazu Sasai Michimasa Magi Takashi Ohsumi 《International Journal of Greenhouse Gas Control》2009,3(1):67-76
Site selection in CO2 ocean sequestration is examined based on the idea that a site where injected CO2 is efficiently diluted is favourable in reducing/avoiding biological impacts. Simulations of CO2 injection into several sites by an eddy-resolving oceanic general circulation model (OGCM) show that the maximum CO2 concentration differs by a factor of 10 among sites. The distribution of eddy activity is the most important causative factor producing the geographical differences in CO2 dilution. Based on the relationship between the maximum CO2 concentration and eddy activity, we estimated the distribution of the maximum CO2 injection rate by a proposed method, which does not cause chronic impacts on biota. Around Japan, extensive ocean volume has the potential to dilute 20 million tonnes per year without chronic impacts, and some areas can be injected with 80 million tonnes per year. 相似文献
3.
Jens T. Birkholzer Quanlin Zhou Chin-Fu Tsang 《International Journal of Greenhouse Gas Control》2009,3(2):181-194
Large volumes of CO2 captured from carbon emitters (such as coal-fired power plants) may be stored in deep saline aquifers as a means of mitigating climate change. Storing these additional fluids may cause pressure changes and displacement of native brines, affecting subsurface volumes that can be significantly larger than the CO2 plume itself. This study aimed at determining the three-dimensional region of influence during/after injection of CO2 and evaluating the possible implications for shallow groundwater resources, with particular focus on the effects of interlayer communication through low-permeability seals. To address these issues quantitatively, we conducted numerical simulations that provide a basic understanding of the large-scale flow and pressure conditions in response to industrial-scale CO2 injection into a laterally open saline aquifer. The model domain included an idealized multilayered groundwater system, with a sequence of aquifers and aquitards (sealing units) extending from the deep saline storage formation to the uppermost freshwater aquifer. Both the local CO2-brine flow around the single injection site and the single-phase water flow (with salinity changes) in the region away from the CO2 plume were simulated. Our simulation results indicate considerable pressure buildup in the storage formation more than 100 km away from the injection zone, whereas the lateral distance migration of brine is rather small. In the vertical direction, the pressure perturbation from CO2 storage may reach shallow groundwater resources only if the deep storage formation communicates with the shallow aquifers through sealing units of relatively high permeabilities (higher than 10?18 m2). Vertical brine migration through a sequence of layers into shallow groundwater bodies is extremely unlikely. Overall, large-scale pressure changes appear to be of more concern to groundwater resources than changes in water quality caused by the migration of displaced saline water. 相似文献
4.
《International Journal of Greenhouse Gas Control》2007,1(2):271-279
CO2 capture and storage (CCS) technology is expected to play an important role in the efforts directed toward long-term CO2 emission reduction. This paper analyzes the cost of the geological storage of CO2 in Japan in order to consider future research, development and deployment (RD&D); these would be based on the information of the obtained cost structure. According to the analysis results, the costs, particularly those of the transportation by pipeline and of CO2 injection, strongly depend on the scale of the facilities. Therefore, the distance of the transportation of CO2 should be minimized in the case of small-scale storage, particularly in Japan. In addition, the potential injection rate per well is another key factor for the injection cost. Based on the analyzed cost, the injection cost of the geological storage of CO2 in Japan for individual storage sites is estimated, and the cost–potential curve is obtained. A mixed-integer programming model has been developed to take into account these characteristics of the CCS technology and its adverse effects arising from the scale of economy with regard to the transportation and injection cost for the geological storage of CO2. The model is designed to evaluate CCS and other CO2 mitigation technologies in the energy systems of Japan. With all these adverse effects due to the scale of economy, the geological storage of CO2 will be one of the important options for CO2 emission reduction in Japan. 相似文献
5.
Mehdi Zeidouni Mehran Pooladi-Darvish David Keith 《International Journal of Greenhouse Gas Control》2009,3(5):600-611
Carbon dioxide sequestration in deep saline aquifers is a means of reducing anthropogenic atmospheric emissions of CO2. Among various mechanisms, CO2 can be trapped in saline aquifers by dissolution in the formation water. Vaporization of water occurs along with the dissolution of CO2. Vaporization can cause salt precipitation, which reduces porosity and impairs permeability of the reservoir in the vicinity of the wellbore, and can lead to reduction in injectivity. The amount of salt precipitation and the region in which it occurs may be important in CO2 storage operations if salt precipitation significantly reduces injectivity. Here we develop an analytical model, as a simple and efficient tool to predict the amount of salt precipitation over time and space. This model is particularly useful at high injection velocities, when viscous forces dominate.First, we develop a model which treats the vaporization of water and dissolution of CO2 in radial geometry. Next, the model is used to predict salt precipitation. The combined model is then extended to evaluate the effect of salt precipitation on permeability in terms of a time-dependent skin factor. Finally, the analytical model is corroborated by application to a specific problem with an available numerical solution, where a close agreement between the solutions is observed. We use the results to examine the effect of assumptions and approximations made in the development of the analytical solution. For cases studied, salt saturation was a few percent. The loss in injectivity depends on the degree of reduction of formation permeability with increased salt saturation. For permeability-reduction models considered in this work, the loss in injectivity was not severe. However, one limitation of the model is that it neglects capillary and gravity forces, and these forces might increase salt precipitation at the bottom of formation particularly when injection rate is low. 相似文献
6.
Evaluation of large-scale CO2 storage on fresh-water sections of aquifers: An example from the Texas Gulf Coast Basin 总被引:1,自引:0,他引:1
Large-scale injections of CO2 into subsurface saline aquifers have been proposed to remediate climate change related to buildup of green house gases in the atmosphere. The pressure buildup caused by such injections may impact a volume of the basin significantly larger than the CO2 plume itself. In areas with hydrological settings similar to the Gulf Coast Basin, the perturbation of the flow-field in deep parts of the basin could result in brines or brackish water being pushed up-dip into unconfined sections of the same formations or into the capture zone of fresh-water wells. The premise of the current study is that the details of multiple-phase flow processes necessary to model the near field evolution of the CO2 plume are not necessary to describe the impact of the pressure anomaly on up-dip aquifers. This paper quantitatively explores conditions under which shallow groundwater would be impacted by up-dip displacement of brines, utilizing an existing carefully calibrated flow model. Modeling an injection of water, arguably equivalent to 50 million tons of CO2/year for 50 years resulted in an average water-table rise of 1 m, with minor increase in stream baseflow and larger increase in ground water evapotranspiration, but no significant change in salinity. 相似文献
7.
Numerical modelling of multiphase flow is an essential tool to ensure the viability of long-term and safe CO2 storage in geological formations. Uncertainties arising from the heterogeneity of the formation and lack of knowledge of formation properties need to be assessed in order to create a model that can reproduce the data available from monitoring. In this study, we investigated the impact of unknown spatial variability in the petrophysical properties within a sandy channel facies of a fluviatile storage formation using stochastic methods in a Monte Carlo approach. The stochastic method has been applied to the Ketzin test site (CO2SINK), and demonstrates that the deterministic homogeneous model satisfactorily predicts the first CO2 arrival time at the Ketzin site. The equivalent permeability was adjusted to the injection pressure and is in good agreement with the hydraulic test. It has been shown that with increasing small-scale heterogeneity, the sharpness of the CO2 front decreases and a greater volume of the reservoir is affected, which is also seen in an increased amount of dissolved CO2. Increased anisotropy creates fingering effects, which result in higher probabilities for earlier arrival times. Generally, injectivity decreases with increasing heterogeneity. 相似文献
8.
Brian R. Ellis Lauren E. Crandell Catherine A. Peters 《International Journal of Greenhouse Gas Control》2010,4(3):575-582
Co-injection of sulfur dioxide during geologic carbon sequestration can cause enhanced brine acidification. The magnitude and timescale of this acidification will depend, in part, on the reactions that control acid production and on the extent and rate of SO2 dissolution from the injected CO2 phase. Here, brine pH changes were predicted for three possible SO2 reactions: hydrolysis, oxidation, or disproportionation. Also, three different model scenarios were considered, including models that account for diffusion-limited release of SO2 from the CO2 phase. In order to predict the most extreme acidification potential, mineral buffering reactions were not modeled. Predictions were compared to the case of CO2 alone which would cause a brine pH of 4.6 under typical pressure, temperature, and alkalinity conditions in an injection formation. In the unrealistic model scenario of SO2 phase equilibrium between the CO2 and brine phases, co-injection of 1% SO2 is predicted to lead to a pH close to 1 with SO2 oxidation or disproportionation, and close to 2 with SO2 hydrolysis. For a scenario in which SO2 dissolution is diffusion-limited and SO2 is uniformly distributed in a slowly advecting brine phase, SO2 oxidation would lead to pH values near 2.5 but not until almost 400 years after injection. In this scenario, SO2 hydrolysis would lead to pH values only slightly less than those due to CO2 alone. When SO2 transport is limited by diffusion in both phases, enhanced brine acidification occurs in a zone extending only 5 m proximal to the CO2 plume, and the effect is even less if the only possible reaction is SO2 hydrolysis. In conclusion, the extent to which co-injected SO2 can impact brine acidity is limited by diffusion-limited dissolution from the CO2 phase, and may also be limited by the availability of oxidants to produce sulfuric acid. 相似文献
9.
Typical top-down regional assessments of CO2 storage feasibility are sufficient for determining the maximum volumetric capacity of deep saline aquifers. However, they do not reflect the regional economic feasibility of storage. This is controlled, in part, by the number and type of injection wells that are necessary to achieve regional CO2 storage goals. In contrast, the geomechanics-based assessment workflow that we present in this paper follows a bottom-up approach for evaluating regional deep saline aquifer CO2 storage feasibility. The CO2 storage capacity of an aquifer is a function of its porous volume as well as its CO2 injectivity. For a saline aquifer to be considered feasible in this assessment it must be able to store a specified amount of CO2 at a reasonable cost per ton of CO2. The proposed assessment workflow has seven steps that include (1) defining the storage project and goals, (2) characterizing the geology and developing a geomechanical model of the aquifer, (3) constructing 3D aquifer models, (4) simulating CO2 injection, (5,6) evaluating CO2 injection and storage feasibility (with and without injection well stimulation), and (7) determining whether it is economically feasible to proceed with the storage project. The workflow was applied to a case study of the Rose Run sandstone aquifer in the Eastern Ohio River Valley, USA. We found that it is feasible in this region to inject 113 Mt CO2/year for 30 years at an associated well cost of less than US $1.31/t CO2, but only if injectivity enhancement techniques such as hydraulic fracturing and injection induced micro-seismicity are implemented. 相似文献
10.
Yuki Kano Toru Sato Jun Kita Shinichiro Hirabayashi Shigeru Tabeta 《International Journal of Greenhouse Gas Control》2009,3(5):617-625
A numerical study was conducted to predict pCO2 change in the ocean on a continental shelf by the leakage of CO2, which is originally stored in the aquifer under the seabed, in the case that a large fault connects the CO2 reservoir and the seabed by an earthquake or other diastrophism. The leakage rate was set to be 6.025 × 10−4 kg/m2/sec from 2 m × 100 m fault band, which corresponds to 3800 t-CO2/year, referring to the monitored seepage rate from an existing EOR field. The target space in this study was limited to the ocean above the seabed, the depth of which was 200 or 500 m. The computational domain was idealistically rectangular with the seabed fault-band perpendicular to the uniform flow. The CO2 takes a form of bubbles or droplets, depending on the depth of water, and their behaviour and dissolution were numerically simulated during their rise in seawater flow. The advection–diffusion of dissolved CO2 was also simulated. As a result, it was suggested that the leaked CO2 droplets/bubbles all dissolve in the seawater before spouting up to the atmosphere, and that the increase in pCO2 in the seawater was smaller than 500 μ atm. 相似文献
11.
Numerical investigation concerning the impact of CO2 geologic storage on regional groundwater flow 总被引:1,自引:0,他引:1
Hajime Yamamoto Keni Zhang Kenzi Karasaki Atsunao Marui Hitoshi Uehara Noriaki Nishikawa 《International Journal of Greenhouse Gas Control》2009,3(5):586-599
Large-scale storage of carbon dioxide in saline aquifers may cause considerable pressure perturbation and brine migration in deep rock formations, which may have a significant influence on the regional groundwater system. With the help of parallel computing techniques, we conducted a comprehensive, large-scale numerical simulation of CO2 geologic storage that predicts not only CO2 migration, but also its impact on regional groundwater flow. As a case study, a hypothetical industrial-scale CO2 injection in Tokyo Bay, which is surrounded by the most heavily industrialized area in Japan, was considered, and the impact of CO2 injection on near-surface aquifers was investigated, assuming relatively high seal-layer permeability (higher than 10 microdarcy). A regional hydrogeological model with an area of about 60 km × 70 km around Tokyo Bay was discretized into about 10 million gridblocks. To solve the high-resolution model efficiently, we used a parallelized multiphase flow simulator TOUGH2-MP/ECO2N on a world-class high performance supercomputer in Japan, the Earth Simulator. In this simulation, CO2 was injected into a storage aquifer at about 1 km depth under Tokyo Bay from 10 wells, at a total rate of 10 million tons/year for 100 years. Through the model, we can examine regional groundwater pressure buildup and groundwater migration to the land surface. The results suggest that even if containment of CO2 plume is ensured, pressure buildup on the order of a few bars can occur in the shallow confined aquifers over extensive regions, including urban inlands. 相似文献
12.
Mohammad Javaheri Kristian Jessen 《International Journal of Greenhouse Gas Control》2011,5(5):1272-1283
Carbon dioxide (CO2) injection into saline aquifers is one of the promising options to sequester large amounts of CO2 in geological formations. During as well as after injection of CO2 into an aquifer, CO2 migrates towards the top of the formation due to density differences between the formation brine and the injected CO2. The time scales of CO2 migration towards the top of an aquifer and the fraction of CO2 that is trapped as residual gas depends strongly on the driving forces that are acting on the injected CO2.When CO2 migrates to the top of an aquifer, brine may be displaced downwards in a counter-current flow setting particularly during the injection period. A majority of the published work on counter-current flow settings have reported significant reductions in the associated relative permeability functions as compared to co-current measurements. However, this phenomenon has not yet been considered in the simulation of CO2 storage into saline aquifers.In this paper we study the impact of changes in mobility for the two-phase brine/CO2 system as a result of transitions between co- and counter-current flow settings. We have included this effect in a simulator and studied the impact of the related mobility reduction on the saturation distribution and residual saturation of CO2 in aquifers over relevant time scales. We demonstrate that the reduction in relative permeability in the vertical direction changes the plume migration pattern and has an impact on the amount of gas that is trapped as a function of time. This is to our best knowledge the first attempt to integrate counter-current relative permeability into the simulation of injection and subsequent migration of CO2 in aquifers. The results and analysis presented in this paper are directly relevant to all ongoing activities related to the design of large-scale CO2 storage in saline aquifers. 相似文献
13.
Semere Solomon Michael Carpenter Todd Allyn Flach 《International Journal of Greenhouse Gas Control》2008,2(4):502
Enhanced oil recovery (EOR) through CO2 flooding has been practiced on a commercial basis for the last 35 years and continues today at several sites, currently injecting in total over 30 million tons of CO2 annually. This practice is currently exclusively for economic gain, but can potentially contribute to the reduction of emissions of greenhouse gases provided it is implemented on a large scale. Optimal operations in distributing CO2 to CO2-EOR or enhanced gas recovery (EGR) projects (referred to here collectively as CO2-EHR) on a large scale and long time span imply that intermediate storage of CO2 in geological formations may be a key component. Intermediate storage is defined as the storage of CO2 in geological media for a limited time span such that the CO2 can be sufficiently reproduced for later use in CO2-EHR. This paper investigates the technical aspects, key individual parameters and possibilities of intermediate storage of CO2 in geological formations aiming at large scale implementation of carbon dioxide capture and storage (CCS) for deep emission reduction. The main parameters are thus the depth of injection and density, CO2 flow and transport processes, storage mechanisms, reservoir heterogeneity, the presence of impurities, the type of the reservoirs and the duration of intermediate storage. Structural traps with no flow of formation water combined with proper injection planning such as gas-phase injection favour intermediate storage in deep saline aquifers. In depleted oil and gas fields, high permeability, homogeneous reservoirs with structural traps (e.g. anticlinal structures) are good candidates for intermediate CO2 storage. Intuitively, depleted natural gas reservoirs can be potential candidates for intermediate storage of carbon dioxide due to similarity in storage characteristics. 相似文献
14.
Wei Zhang Yilian Li Tianfu Xu Huilin Cheng Yan Zheng Peng Xiong 《International Journal of Greenhouse Gas Control》2009,3(2):161-180
The geological storage of CO2 in deep saline formations is increasing seen as a viable strategy to reduce the release of greenhouse gases to the atmosphere. There are numerous sedimentary basins in China, in which a number of suitable CO2 geologic reservoirs are potentially available. To identify the multi-phase processes, geochemical changes and mineral alteration, and CO2 trapping mechanisms after CO2 injection, reactive geochemical transport simulations using a simple 2D model were performed. Mineralogical composition and water chemistry from a deep saline formation of Songliao Basin were used. Results indicate that different storage forms of CO2 vary with time. In the CO2 injection period, a large amount of CO2 remains as a free supercritical phase (gas trapping), and the amount dissolved in the formation water (solubility trapping) gradually increases. Later, gas trapping decrease, solubility trapping increases significantly due to the migration and diffusion of CO2 plume and the convective mixing between CO2-saturated water and unsaturated water, and the amount trapped by carbonate minerals increases gradually with time. The residual CO2 gas keeps dissolving into groundwater and precipitating carbonate minerals. For the Songliao Basin sandstone, variations in the reaction rate and abundance of chlorite, and plagioclase composition affect significantly the estimates of mineral alteration and CO2 storage in different trapping mechanisms. The effect of vertical permeability and residual gas saturation on the overall storage is smaller compared to the geochemical factors. However, they can affect the spatial distribution of the injected CO2 in the formations. The CO2 mineral trapping capacity could be in the order of 10 kg/m3 medium for the Songliao Basin sandstone, and may be higher depending on the composition of primary aluminosilicate minerals especially the content of Ca, Mg, and Fe. 相似文献
15.
Victor Vilarrasa Diogo Bolster Sebastia Olivella Jesus Carrera 《International Journal of Greenhouse Gas Control》2010,4(6):910-919
Sequestration of carbon dioxide (CO2) in deep saline aquifers has emerged as an option for reducing greenhouse gas emissions to the atmosphere. The large amounts of supercritical CO2 that need to be injected into deep saline aquifers may cause large fluid pressure increases. The resulting overpressure may promote reactivation of sealed fractures or the creation of new ones in the caprock seal. This could lead to escape routes for CO2. In order to assess the probability of such an event, we model an axisymmetric horizontal aquifer–caprock system, including hydromechanical coupling. We study the failure mechanisms, using a viscoplastic approach. Simulations illustrate that, depending on boundary conditions, the least favorable moment takes place at the beginning of injection. Initially, fluid pressure rises sharply because of a reduction in permeability due to desaturation. Once CO2 fills the pores in the vicinity of the injection well and a capillary fringe is fully developed, the less viscous CO2 displaces the brine and the capillary fringe laterally. The overpressure caused by the permeability reduction within the capillary fringe due to desaturation decreases with distance from the injection well. This results in a drop in fluid pressure buildup with time, which leads to a safer situation. Nevertheless, in the presence of low-permeability boundaries, fluid pressure continues to rise in the whole aquifer. This occurs when the radius of influence of the injection reaches the outer boundary. Thus, caprock integrity might be compromised in the long term. 相似文献
16.
Phillip N. Price Curtis M. Oldenburg 《International Journal of Greenhouse Gas Control》2009,3(5):658-663
Geologic carbon sequestration is the injection of anthropogenic CO2 into deep geologic formations where the CO2 is intended to remain indefinitely. If successfully implemented, geologic carbon sequestration will have little or no impact on terrestrial ecosystems aside from the mitigation of climate change. However, failure of a geologic carbon sequestration site, such as large-scale leakage of CO2 into a potable groundwater aquifer, could cause impacts that would require costly remediation measures. Governments are attempting to develop regulations for permitting geologic carbon sequestration sites to ensure their safety and effectiveness. At present, these regulations focus largely on decreasing the probability of failure. In this paper we propose that regulations for the siting of early geologic carbon sequestration projects should emphasize limiting the consequences of failure because consequences are easier to quantify than failure probability. 相似文献
17.
Coralie Chasset Jerker Jarsjö Mikael Erlström Vladimir Cvetkovic Georgia Destouni 《International Journal of Greenhouse Gas Control》2011,5(5):1303-1318
Deep saline aquifers have large capacity for geological CO2 storage, but are generally not as well characterized as petroleum reservoirs. We here aim at quantifying effects of uncertain hydraulic parameters and uncertain stratigraphy on CO2 injectivity and migration, and provide a first feasibility study of pilot-scale CO2 injection into a multilayered saline aquifer system in southwest Scania, Sweden. Four main scenarios are developed, corresponding to different possible interpretations of available site data. Simulation results show that, on the one hand, stratigraphic uncertainty (presence/absence of a thin mudstone/claystone layer above the target storage formation) leads to large differences in predicted CO2 storage in the target formation at the end of the test (ranging between 11% and 98% of injected CO2 remaining), whereas other parameter uncertainty (in formation and cap rock permeabilities) has small impact. On the other hand, the latter has large impact on predicted injectivity, on which stratigraphic uncertainty has small impact. Salt precipitation at the border of the target storage formation affects CO2 injectivity for all considered scenarios and injection rates. At low injection rates, salt is deposited also within the formation, considerably reducing its availability for CO2 storage. 相似文献
18.
Monitoring of the microbial community composition in saline aquifers during CO2 storage by fluorescence in situ hybridisation 总被引:1,自引:0,他引:1
Daria Morozova Maren Wandrey Mashal Alawi Martin Zimmer Andrea Vieth Michael Zettlitzer Hilke Würdemann the COSINK Group 《International Journal of Greenhouse Gas Control》2010,4(6):981-989
This study reveals the first analyses of the composition and activity of the microbial community of a saline CO2 storage aquifer. Microbial monitoring during CO2 injection has been reported. By using fluorescence in situ hybridisation (FISH), we have shown that the microbial community was strongly influenced by the CO2 injection. Before CO2 arrival, up to 6 × 106 cells ml−1 were detected by DAPI staining at a depth of 647 m below the surface. The microbial community was dominated by the domain Bacteria that represented approximately 60% to 90% of the total cell number, with Proteobacteria and Firmicutes as the most abundant phyla comprising up to 47% and 45% of the entire population, respectively. Both the total cell counts as well as the counts of the specific physiological groups revealed quantitative and qualitative changes after CO2 arrival. Our study revealed temporal outcompetition of sulphate-reducing bacteria by methanogenic archaea. In addition, an enhanced activity of the microbial population after five months CO2 storage indicated that the bacterial community was able to adapt to the extreme conditions of the deep biosphere and to the extreme changes of these atypical conditions. 相似文献
19.
Corrective measures based on pressure control strategies for CO2 geological storage in deep aquifers
A prerequisite to the wide deployment at an industrial scale of CO2 geological storage is demonstrating that potential risks can be efficiently managed. Corrective measures in case of significant irregularities, such as CO2 leakage, are hence required as advocated by the recent European directive on Carbon Capture and Storage operations. In this regard, the objective of the present paper is to investigate four different corrective measures aiming at controlling the overpressure induced by the injection operations in the reservoir: stopping the CO2 injection and relying on the natural pressure recovery in the reservoir; extracting the stored CO2 at the injection well; extracting brine at a distant well while stopping the CO2 injection, and extracting at a distant well without stopping the CO2 injection. The efficiency of the measures is assessed using multi-phase fluid flow numerical simulations. The application case is the deep carbonate aquifer of the Dogger geological unit in the Paris Basin. A comparative study between the four corrective measures is then carried using a cost-benefit approach. Results show that an efficient overpressure reduction can be achieved by simply shutting-in the well. The overpressure reduction can be significantly accelerated by means of fluid extraction but the adverse consequences are the associated higher costs of the intervention operations. 相似文献
20.
Kornelia Zemke Axel Liebscher Maren Wandrey the COSINKGroup 《International Journal of Greenhouse Gas Control》2010,4(6):990-999
To test the injection behaviour of CO2 into brine-saturated rock and to evaluate the dependence of geophysical properties on CO2 injection, flow and exposure experiments with brine and CO2 were performed on sandstone samples of the Stuttgart Formation representing potential reservoir rocks for CO2 storage. The sandstone samples studied are generally fine-grained with porosities between 17 and 32% and permeabilities between 1 and 100 mD.Additional batch experiments were performed to predict the long-term behaviour of geological CO2 storage. Reservoir rock samples were exposed over a period of several months to CO2-saturated reservoir fluid in high-pressure vessels under in situ temperature and pressure conditions. Petrophysical parameters, porosity and the pore radius distribution were investigated before and after the experiments by NMR (Nuclear Magnetic Resonance) relaxation and mercury injection. Most of the NMR measurements of the tested samples showed a slight increase of porosity and a higher proportion of large pores. 相似文献