Residual and Solubility trapping during Geological CO2 storage : Numerical and Experimental studies

OpenAIRE

Rasmusson, Maria

2018-01-01

Geological storage of carbon dioxide (CO2) in deep saline aquifers mitigates atmospheric release of greenhouse gases. To estimate storage capacity and evaluate storage safety, knowledge of the trapping mechanisms that retain CO2 within geological formations, and the factors affecting these is fundamental. The objective of this thesis is to study residual and solubility trapping mechanisms (the latter enhanced by density-driven convective mixing), specifically in regard to their dependency on ...

Rates of CO2 Mineralization in Geological Carbon Storage.

Science.gov (United States)

Zhang, Shuo; DePaolo, Donald J

2017-09-19

Geologic carbon storage (GCS) involves capture and purification of CO 2 at industrial emission sources, compression into a supercritical state, and subsequent injection into geologic formations. This process reverses the flow of carbon to the atmosphere with the intention of returning the carbon to long-term geologic storage. Models suggest that most of the injected CO 2 will be "trapped" in the subsurface by physical means, but the most risk-free and permanent form of carbon storage is as carbonate minerals (Ca,Mg,Fe)CO 3 . The transformation of CO 2 to carbonate minerals requires supply of the necessary divalent cations by dissolution of silicate minerals. Available data suggest that rates of transformation are highly uncertain and difficult to predict by standard approaches. Here we show that the chemical kinetic observations and experimental results, when they can be reduced to a single cation-release time scale that describes the fractional rate at which cations are released to solution by mineral dissolution, show sufficiently systematic behavior as a function of pH, fluid flow rate, and time that the rates of mineralization can be estimated with reasonable certainty. The rate of mineralization depends on both the abundance (determined by the reservoir rock mineralogy) and the rate at which cations are released from silicate minerals by dissolution into pore fluid that has been acidified with dissolved CO 2 . Laboratory-measured rates and field observations give values spanning 8 to 10 orders of magnitude, but when they are evaluated in the context of a reservoir-scale reactive transport simulation, this range becomes much smaller. The reservoir scale simulations provide limits on the applicable conditions under which silicate mineral dissolution and subsequent carbonate mineral precipitation are likely to occur (pH 4.5 to 6, fluid flow velocity less than 5 m/year, and 50-100 years or more after the start of injection). These constraints lead to estimates of

Geological Storage of CO2. Site Selection Criteria; Almacenamiento Geologico de CO2. Criterios de Selecci0n de Emplazamientos

Energy Technology Data Exchange (ETDEWEB)

Ruiz, C; Martinez, R; Recreo, F; Prado, P; Campos, R; Pelayo, M; Losa, A de la; Hurtado, A; Lomba, L; Perez del Villar, L; Ortiz, G; Sastre, J; Zapatero, M A; Suarez, I; Arenillas, A

2007-09-18

In year 2002 the Spanish Parliament unanimously passed the ratification of the Kyoto Protocol, signed December 1997, compromising to limiting the greenhouse gas emissions increase. Later on, the Environment Ministry submitted the Spanish National Assignment Emissions Plan to the European Union and in year 2005 the Spanish Greenhouse Gas market started working, establishing taxes to pay in case of exceeding the assigned emissions limits. So, the avoided emissions of CO2 have now an economic value that is promoting new anthropogenic CO2 emissions reduction technologies. Carbon Capture and Storage (CCS) are among these new technological developments for mitigating or eliminate climate change. CO2 can be stored in geological formations such as depleted oil or gas fields, deep permeable saline water saturated formations and unmailable coal seams, among others. This report seeks to establish the selection criteria for suitable geological formations for CO2 storage in the Spanish national territory, paying attention to both the operational and performance requirements of these storage systems. The report presents the physical and chemical properties and performance of CO2 under storage conditions, the transport and reaction processes of both supercritical and gaseous CO2, and CO2 trapping mechanisms in geological formations. The main part of the report is devoted to geological criteria at watershed, site and formation scales. (Author) 100 refs.

Public Acceptance for Geological CO2-Storage

Science.gov (United States)

Schilling, F.; Ossing, F.; Würdemann, H.; Co2SINK Team

2009-04-01

Public acceptance is one of the fundamental prerequisites for geological CO2 storage. In highly populated areas like central Europe, especially in the vicinity of metropolitan areas like Berlin, underground operations are in the focus of the people living next to the site, the media, and politics. To gain acceptance, all these groups - the people in the neighbourhood, journalists, and authorities - need to be confident of the security of the planned storage operation as well as the long term security of storage. A very important point is to show that the technical risks of CO2 storage can be managed with the help of a proper short and long term monitoring concept, as well as appropriate mitigation technologies e.g adequate abandonment procedures for leaking wells. To better explain the possible risks examples for leakage scenarios help the public to assess and to accept the technical risks of CO2 storage. At Ketzin we tried the following approach that can be summed up on the basis: Always tell the truth! This might be self-evident but it has to be stressed that credibility is of vital importance. Suspiciousness and distrust are best friends of fear. Undefined fear seems to be the major risk in public acceptance of geological CO2-storage. Misinformation and missing communication further enhance the denial of geological CO2 storage. When we started to plan and establish the Ketzin storage site, we ensured a forward directed communication. Offensive information activities, an information centre on site, active media politics and open information about the activities taking place are basics. Some of the measures were: - information of the competent authorities through meetings (mayor, governmental authorities) - information of the local public, e.g. hearings (while also inviting local, regional and nation wide media) - we always treated the local people and press first! - organizing of bigger events to inform the public on site, e.g. start of drilling activities (open

Capture and Geological Storage of CO2

International Nuclear Information System (INIS)

Kerr, T.; Brockett, S.; Hegan, L.; Barbucci, P.; Tullius, K.; Scott, J.; Otter, N.; Cook, P.; Hill, G.; Dino, R.; Aimard, N.; Giese, R.; Christensen, N.P.; Munier, G.; Paelinck, Ph.; Rayna, L.; Stromberg, L.; Birat, J.P.; Audigane, P.; Loizzo, M.; Arts, R.; Fabriol, H.; Radgen, P.; Hartwell, J.; Wartmann, S.; Drosin, E.; Willnow, K.; Moisan, F.

2009-01-01

To build on the growing success of the first two international symposia on emission reduction and CO 2 capture and geological storage, held in Paris in 2005 and again in 2007, IFP, ADEME and BRGM organised a third event on the same topic the 5-6 November 2009. This time, the focus was on the urgency of industrial deployment. Indeed, the IPCC 4. assessment report indicates that the world must achieve a 50 to 85% reduction in CO 2 emissions by 2050 compared to 2000, in order to limit the global temperature increase to around 2 deg. C. Moreover, IPCC stresses that a 'business as usual' scenario could lead to a temperature increase of between 4 deg. C to 7 deg. C across the planet. The symposium was organized in 4 sessions: Session I - Regulatory framework and strategies for enabling CCS deployment: - CCS: international status of political, regulatory and financing issues (Tom Kerr, IEA); - EC regulatory framework (Scott Brockett, European Commission, DG ENV); - Canada's investments towards implementation of CCS in Canada (Larry Hegan, Office of Energy Research and Development - Government of Canada); - A power company perspective (Pietro Barbucci, ENEL); - EC CCS demonstration network (Kai Tullius, European Commission, DG TREN); - Strategies and policies for accelerating global CCS deployment (Jesse Scott, E3G); - The global CCS Institute, a major initiative to facilitate the rapid deployment of CCS (Nick Otter, GCCSI); Session II - From pilot to demonstration projects: - Otway project, Australia (David Hilditch, CO2 CRC); - US regional partnerships (Gerald Hill, Southeast Regional Carbon Sequestration Partnership - SECARB); - CCS activities in Brazil (Rodolfo Dino, Petrobras); - Lessons learnt from Ketzin CO2Sink project in Germany (Ruediger Giese, GFZ); - CO 2 storage - from laboratory to reality (Niels-Peter Christensen, Vattenfall); - Valuation and storage of CO 2 : A global project for carbon management in South-East France (Gilles Munier, Geogreen); Session III

Interactions between CO2, saline water and minerals during geological storage of CO2

International Nuclear Information System (INIS)

Hellevang, Helge

2006-06-01

The topic of this thesis is to gain a better understanding of interactions between injected CO 2 , aqueous solutions and formation mineralogies. The main focus is concerned with the potential role mineral reactions play in safe long term storage of CO 2 . The work is divided into an experimental part concentrated on the potential of dawsonite (NaAl(OH) 2 CO 3 ) as a permanent storage host of CO 2 , and the development of a new geochemical code ACCRETE that is coupled with the ATHENA multiphase flow simulator. The thesis is composed of two parts: (I) the first part introducing CO 2 storage, geochemical interactions and related work; and (II) the second part that consists of the papers. Part I is composed as follows: Chapter 2 gives a short introduction to geochemical reactions considered important during CO 2 storage, including a thermodynamic framework. Chapter 3 presents objectives of numerical work related to CO 2 -water-rock interactions including a discussion of factors that influence the outcome of numerical simulations. Chapter 4 presents the main results from paper A to E. Chapter 5 give some details about further research that we propose based on the present work and related work in the project. Several new activities have emerged from research on CO 2 -water-rock interaction during the project. Several of the proposed activities are already initiated. Papers A to F are then listed in Part II of the thesis after the citation list. The thesis presents the first data on the reaction kinetics of dawsonite at different pH (Paper A), and comprehensive numerical simulations, both batch- and large scale 3D reactive transport, that illustrate the role different carbonates have for safe storage of CO 2 in geological formations (Papers C to F). The role of dawsonite in CO 2 storage settings is treated throughout the study (Papers A to E) After the main part of the thesis (Part I and II), two appendices are included: Appendix A lists reactions that are included in the

Gas-water-rock interactions induced by reservoir exploitation, CO2 sequestration, and other geological storage

International Nuclear Information System (INIS)

Lecourtier, J.

2005-01-01

Here is given a summary of the opening address of the IFP International Workshop: 'gas-water-rock interactions induced by reservoir exploitation, CO 2 sequestration, and other geological storage' (18-20 November 2003). 'This broad topic is of major interest to the exploitation of geological sites since gas-water-mineral interactions determine the physicochemical characteristics of these sites, the strategies to adopt to protect the environment, and finally, the operational costs. Modelling the phenomena is a prerequisite for the engineering of a geological storage, either for disposal efficiency or for risk assessment and environmental protection. During the various sessions, several papers focus on the great achievements that have been made in the last ten years in understanding and modelling the coupled reaction and transport processes occurring in geological systems, from borehole to reservoir scale. Remaining challenges such as the coupling of mechanical processes of deformation with chemical reactions, or the influence of microbiological environments on mineral reactions will also be discussed. A large part of the conference programme will address the problem of mitigating CO 2 emissions, one of the most important issues that our society must solve in the coming years. From both a technical and an economic point of view, CO 2 geological sequestration is the most realistic solution proposed by the experts today. The results of ongoing pilot operations conducted in Europe and in the United States are strongly encouraging, but geological storage will be developed on a large scale in the future only if it becomes possible to predict the long term behaviour of stored CO 2 underground. In order to reach this objective, numerous issues must be solved: - thermodynamics of CO 2 in brines; - mechanisms of CO 2 trapping inside the host rock; - geochemical modelling of CO 2 behaviour in various types of geological formations; - compatibility of CO 2 with oil-well cements

Feasibility of CO{sub 2} geological storage in the Xingou oil field, Jianghan Basin, China

Energy Technology Data Exchange (ETDEWEB)

Peng, Sanxi [School of Environmental Studies, China University of Geosciences, Wuhan, 430074 (China); Changsha Engineering and Research Institute Ltd. of Nonferrous Metallurgy, Changsha, 410001 (China); Shana, Huimei; Li, Yilian [School of Environmental Studies, China University of Geosciences, Wuhan, 430074 (China); Yang, Zhen; Zhong, Zhaohong [Changsha Engineering and Research Institute Ltd. of Nonferrous Metallurgy, Changsha, 410001 (China)

2013-07-01

Geological storage of CO{sub 2} as an effective way of reducing CO{sub 2} output to the atmosphere receives growing attention worldwide. To evaluate the feasibility of this technique in the Xingou oil field of Jianghan Basin in China, 2D and 3D models of CO{sub 2} geological storage were established using TOUGH2 software. Results showed that CO{sub 2} gas can be stored in the deepest reservoir through continuous injection over 50 years, and will remain effectively confined within the space under the second cap-rock during its diffusion over 500 years. Compared with 2D models, 3D models showed that the diffusion process of CO{sub 2} gas in the reservoir will create a mushroom-shaped zone of influence. (authors)

Numerical simulation of CO2 geological storage in saline aquifers – case study of Utsira formation

Energy Technology Data Exchange (ETDEWEB)

Zhang, Zheming; Agarwal, Ramesh K. [Department of Mechanical Engineering and Materials Science, Washington University, St. Louis, MO 63130 (United States)

2013-07-01

CO2 geological storage (CGS) is one of the most promising technologies to address the issue of excessive anthropogenic CO2 emissions in the atmosphere due to fossil fuel combustion for electricity generation. In order to fully exploit the storage potential, numerical simulations can help in determining injection strategies before the deployment of full scale sequestration in saline aquifers. This paper presents the numerical simulations of CO2 geological storage in Utsira saline formation where the sequestration is currently underway. The effects of various hydrogeological and numerical factors on the CO2 distribution in the topmost hydrogeological layer of Utsira are discussed. The existence of multiple pathways for upward mobility of CO2 into the topmost layer of Utsira as well as the performance of the top seal are also investigated.

Numerical Simulation of Natural Convection in Heterogeneous Porous media for CO2 Geological Storage

NARCIS (Netherlands)

Ranganathan, P.; Farajzadeh, R.; Bruining, J.; Zitha, P.L.J.

2012-01-01

We report a modeling and numerical simulation study of density-driven natural convection during geological CO2 storage in heterogeneous formations. We consider an aquifer or depleted oilfield overlain by gaseous CO2, where the water density increases due to CO2 dissolution. The heterogeneity of the

Southern Adriatic sea as a potential area for CO2 geological storage

International Nuclear Information System (INIS)

Volpi, V.; Forlin, F.; Donda, F.; Civile, D.; Facchin, L.; Sauli, L.; Merson, B.; Sinza-Mendieta, K.; Shams, A.

2015-01-01

The Southern Adriatic Sea is one of the five prospective areas for CO 2 storage being evaluated under the three year (FP7) European SiteChar project dedicated to the characterization of European CO 2 storage sites. The potential reservoir for CO 2 storage is represented by a carbonate formation, the wackstones and packstones of the Scaglia Formation (Upper Cretaceous-Paleogene). In this paper, we present the geological characterization and the 3D modeling that led to the identification of three sites, named Grazia, Rovesti and Grifone, where the Scaglia Formation, with an average thickness of 50 m, reveals good petrophysical characteristics and is overlain by an up to 1 200 thick cap-rock. The vicinity of the selected sites to the Enel - Federico II power plant (one of the major Italian CO 2 emitter) where a pilot plant for CO 2 capture has been already started in April 2010, represents a good opportunity to launch the first Carbon Capture and Storage (CCS) pilot project in Italy and to apply this technology at industrial level, strongly contributing at the same time at reducing the national CO 2 emissions. (authors)

Simplified models of rates of CO2 mineralization in Geologic Carbon Storage

Science.gov (United States)

DePaolo, D. J.; Zhang, S.

2017-12-01

Geologic carbon storage (GCS) reverses the flow of carbon to the atmosphere, returning the carbon to long-term geologic storage. Models suggest that most of the injected CO2 will be "trapped" in the subsurface by physical means, but the most risk-free and permanent form of carbon storage is as carbonate minerals (Ca,Mg,Fe)CO3. The transformation of CO2 to carbonate minerals requires supply of divalent cations by dissolution of silicate minerals. Available data suggest that rates of transformation are difficult to predict. We show that the chemical kinetic observations and experimental results, when reduced to a single timescale that describes the fractional rate at which cations are released to solution by mineral dissolution, show sufficiently systematic behavior that the rates of mineralization can be estimated with reasonable certainty. Rate of mineralization depends on both the abundance (determined by the reservoir rock mineralogy) and the rate at which cations are released by dissolution into pore fluid that has been acidified with dissolved CO2. Laboratory-measured rates and field observations give values spanning 8 to 10 orders of magnitude, but when evaluated in the context of reservoir-scale reactive transport simulations, this range becomes much smaller. Reservoir scale simulations indicate that silicate mineral dissolution and subsequent carbonate mineral precipitation occur at pH 4.5 to 6, fluid flow velocity less than 5m/yr, and 50-100 years or more after the start of injection. These constraints lead to estimates of 200 to 2000 years for conversion of 60-90% of injected CO2 when the reservoir rock has a sufficient volume fraction of divalent cation-bearing silicate minerals (ca. 20%), and confirms that when reservoir rock mineralogy is not favorable the fraction of CO2 converted to carbonate minerals is minimal over 104 years. A sufficient amount of reactive minerals represents the condition by which the available cations per volume of rock plus pore

Nanoscale Chemical Processes Affecting Storage Capacities and Seals during Geologic CO2 Sequestration.

Science.gov (United States)

Jun, Young-Shin; Zhang, Lijie; Min, Yujia; Li, Qingyun

2017-07-18

Geologic CO 2 sequestration (GCS) is a promising strategy to mitigate anthropogenic CO 2 emission to the atmosphere. Suitable geologic storage sites should have a porous reservoir rock zone where injected CO 2 can displace brine and be stored in pores, and an impermeable zone on top of reservoir rocks to hinder upward movement of buoyant CO 2 . The injection wells (steel casings encased in concrete) pass through these geologic zones and lead CO 2 to the desired zones. In subsurface environments, CO 2 is reactive as both a supercritical (sc) phase and aqueous (aq) species. Its nanoscale chemical reactions with geomedia and wellbores are closely related to the safety and efficiency of CO 2 storage. For example, the injection pressure is determined by the wettability and permeability of geomedia, which can be sensitive to nanoscale mineral-fluid interactions; the sealing safety of the injection sites is affected by the opening and closing of fractures in caprocks and the alteration of wellbore integrity caused by nanoscale chemical reactions; and the time scale for CO 2 mineralization is also largely dependent on the chemical reactivities of the reservoir rocks. Therefore, nanoscale chemical processes can influence the hydrogeological and mechanical properties of geomedia, such as their wettability, permeability, mechanical strength, and fracturing. This Account reviews our group's work on nanoscale chemical reactions and their qualitative impacts on seal integrity and storage capacity at GCS sites from four points of view. First, studies on dissolution of feldspar, an important reservoir rock constituent, and subsequent secondary mineral precipitation are discussed, focusing on the effects of feldspar crystallography, cations, and sulfate anions. Second, interfacial reactions between caprock and brine are introduced using model clay minerals, with focuses on the effects of water chemistries (salinity and organic ligands) and water content on mineral dissolution and

The carbon dioxide capture and geological storage; Le captage et le stockage geologique de CO{sub 2}

Energy Technology Data Exchange (ETDEWEB)

NONE

2006-06-15

This road-map proposes by the Group Total aims to inform the public on the carbon dioxide capture and geological storage. One possible means of climate change mitigation consists of storing the CO{sub 2} generated by the greenhouse gases emission in order to stabilize atmospheric concentrations. This sheet presents the CO{sub 2} capture from lage fossil-fueled combustion installations, the three capture techniques and the CO{sub 2} transport options, the geological storage of the CO{sub 2} and Total commitments in the domain. (A.L.B.)

The potential of geological storage of CO2 in Austria: a techno-economic assessment

Science.gov (United States)

Brüstle, Anna Katharina; Welkenhuysen, Kris; Bottig, Magdalena; Piessens, Kris; Ramirez, Andrea; Swenner, Rudy

2014-05-01

An impressive two-third or about 40GWh/y of electricity in Austria is produced from renewable energy sources, in particular hydro energy. For the remaining part the country depends on fossil fuels, which together with iron & steel production form the most CO2 intensive industries in Austria with a combined emission of just over 20Mt/y. According to the IEA, CO2 capture and geological storage (CCS) can reduce the global CO2 emission until 2050 by 17%. A correct assessment of CCS needs to start with the storage potential. Prior to this study, only general estimates of the theoretical capacity of Austrian reservoirs were available, thus, up until now, the realistic potential for CCS technology has not been assessed. Both for policy and industry, an assessment of the matched capacity is required, which is the capacity that actually will be used in CCS projects. This hurdle can be taken by applying a recently developed methodology (Welkenhuysen et al., 2013). This policy support system (PSS) consists of two parts, PSS Explorer and PSS III simulator. In brief, the methodology is based on expert judgements of potential reservoirs. These assessments can provide the best available data, including the expert's experience and possibly confidential data, without disclosing specific data. The geo-techno-economic calculation scheme PSS Explorer uses the expert input to calculate for each individual reservoir an assessment of the practical capacity (as probability density functions), in function of an acceptable price for storage. This practical capacity can then be used by the techno-economic PSS III simulator to perform advanced source-sink matching until 2050 and thus provide the matched reservoir capacity. The analysed reservoirs are 7 active or abandoned oil and gas reservoirs in Austria. The simulation of the electricity and iron & steel sector of Austria resulted in the estimation of the geological storage potential, taking into account geological, technological and

ULTimateCO2 - State of the art report. Dealing with uncertainty associated with long-term CO2 geological storage

International Nuclear Information System (INIS)

2014-01-01

ULTimateCO2, a four-year collaborative project financed by the 7. Framework Programme and coordinated by BRGM, aims to shed more light on the long-term processes associated with the geological storage of CO 2 . ULTimateCO2 unites 12 partners (research institutes, universities, industrialists) and a varied panel of experts (NGOs, national authority representatives, IEAGHG,...). Based on a multidisciplinary approach, and bringing together laboratory experiments, numerical modelling and natural analogue field studies, ULTimateCO2 will increase our understanding of the long-term effects of CO 2 Capture and Storage (CCS) in terms of hydrodynamics, geochemistry, mechanics of the storage formations and their vicinity. The report contains the partners' pooled knowledge and provides a view of the current state-of-the-art for the issues addressed by this project: - The long-term reservoir trapping efficiency (WP3); - The long-term sealing integrity of faulted and fractured cap-rock (WP4); - The near-well leakage characterisation and chemical processes (WP5); - The long-term behavior of stored CO 2 looking at the basin scale (WP2); - Uncertainty assessment (WP6). Each chapter is divided into two sections: (i) a summary which explains in 'simple words' the main issues and objectives of the WP, and (ii) a current state of the art section which provides a more sound review on the specific studied processes. The aim is to provide answers to pertinent questions from a variety of users, particularly project owners, site operators and national authorities, about their exposure to uncertainty downstream of closure of a CO 2 geological storage site

A methodology for the geological and numerical modelling of CO2 storage in deep saline formations

Science.gov (United States)

Guandalini, R.; Moia, F.; Ciampa, G.; Cangiano, C.

2009-04-01

Several technological options have been proposed to stabilize and reduce the atmospheric concentrations of CO2 among which the most promising are the CCS technologies. The remedy proposed for large stationary CO2 sources as thermoelectric power plants is to separate the flue gas, capturing CO2 and to store it into deep subsurface geological formations. In order to support the identification of potential CO2 storage reservoirs in Italy, the project "Identification of Italian CO2 geological storage sites", financed by the Ministry of Economic Development with the Research Fund for the Italian Electrical System under the Contract Agreement established with the Ministry Decree of march 23, 2006, has been completed in 2008. The project involves all the aspects related to the selection of potential storage sites, each carried out in a proper task. The first task has been devoted to the data collection of more than 6800 wells, and their organization into a geological data base supported by GIS, of which 1911 contain information about the nature and the thickness of geological formations, the presence of fresh, saline or brackish water, brine, gas and oil, the underground temperature, the seismic velocity and electric resistance of geological materials from different logs, the permeability, porosity and geochemical characteristics. The goal of the second task was the set up of a numerical modelling integrated tool, that is the in order to allow the analysis of a potential site in terms of the storage capacity, both from solubility and mineral trapping points of view, in terms of risk assessment and long-term storage of CO2. This tool includes a fluid dynamic module, a chemical module and a module linking a geomechanical simulator. Acquirement of geological data, definition of simulation parameter, run control and final result analysis can be performed by a properly developed graphic user interface, fully integrated and calculation platform independent. The project is then

Assessment of the potential for geological storage of CO2 in the vicinity of Moneypoint, Co. Clare, Ireland

NARCIS (Netherlands)

Farrelly, I.; Loske, B.; Neele, F.; Holdstock, M.

2011-01-01

The largest single point CO2 emitter in Ireland, the Moneypoint Power Station (3.95 Mt CO2 per annum), is located in Co. Clare and geologically lies within the Clare Basin. In terms of the economics of transportation of CO2 from Moneypoint, a possible local storage site would be favoured. The study

Mesoscale Assessment of CO2 Storage Potential and Geological Suitability for Target Area Selection in the Sichuan Basin

Directory of Open Access Journals (Sweden)

Yujie Diao

2017-01-01

Full Text Available In China, south of the Yangtze River, there are a large number of carbon sources, while the Sichuan Basin is the largest sedimentary basin; it makes sense to select the targets for CO2 geological storage (CGUS early demonstration. For CO2 enhanced oil and gas, coal bed methane recovery (CO2-EOR, EGR, and ECBM, or storage in these depleted fields, the existing oil, gas fields, or coal seams could be the target areas in the mesoscale. This paper proposed a methodology of GIS superimposed multisource information assessment of geological suitability for CO2 enhanced water recovery (CO2-EWR or only storage in deep saline aquifers. The potential per unit area of deep saline aquifers CO2 storage in Central Sichuan is generally greater than 50 × 104 t/km2 at P50 probability level, with Xujiahe group being the main reservoir. CO2 storage potential of depleted gas fields is 53.73 × 108 t, while it is 33.85 × 108 t by using CO2-EGR technology. This paper recommended that early implementation of CGUS could be carried out in the deep saline aquifers and depleted gas fields in the Sichuan Basin, especially that of the latter because of excellent traps, rich geological data, and well-run infrastructures.

Natural analogue study of CO2 storage monitoring using probability statistics of CO2-rich groundwater chemistry

Science.gov (United States)

Kim, K. K.; Hamm, S. Y.; Kim, S. O.; Yun, S. T.

2016-12-01

For confronting global climate change, carbon capture and storage (CCS) is one of several very useful strategies as using capture of greenhouse gases like CO2 spewed from stacks and then isolation of the gases in underground geologic storage. CO2-rich groundwater could be produced by CO2 dissolution into fresh groundwater around a CO2 storage site. As consequence, natural analogue studies related to geologic storage provide insights into future geologic CO2 storage sites as well as can provide crucial information on the safety and security of geologic sequestration, the long-term impact of CO2 storage on the environment, and field operation and monitoring that could be implemented for geologic sequestration. In this study, we developed CO2 leakage monitoring method using probability density function (PDF) by characterizing naturally occurring CO2-rich groundwater. For the study, we used existing data of CO2-rich groundwaters in different geological regions (Gangwondo, Gyeongsangdo, and Choongchungdo provinces) in South Korea. Using PDF method and QI (quantitative index), we executed qualitative and quantitative comparisons among local areas and chemical constituents. Geochemical properties of groundwater with/without CO2 as the PDF forms proved that pH, EC, TDS, HCO3-, Ca2+, Mg2+, and SiO2 were effective monitoring parameters for carbonated groundwater in the case of CO2leakage from an underground storage site. KEY WORDS: CO2-rich groundwater, CO2 storage site, monitoring parameter, natural analogue, probability density function (PDF), QI_quantitative index Acknowledgement This study was supported by the "Basic Science Research Program through the National Research Foundation of Korea (NRF), which is funded by the Ministry of Education (NRF-2013R1A1A2058186)" and the "R&D Project on Environmental Management of Geologic CO2 Storage" from KEITI (Project number: 2014001810003).

Probabilistic modelling of rock damage: application to geological storage of CO2

International Nuclear Information System (INIS)

Guy, N.

2010-01-01

The storage of CO 2 in deep geological formations is considered as a possible way to reduce emissions of greenhouse gases in the atmosphere. The condition of the rocks constituting the reservoir is a key parameter on which rely both storage safety and efficiency. The objective of this thesis is to characterize the risks generated by a possible change of mechanical and transfer properties of the material of the basement after an injection of CO 2 . Large-scale simulations aiming at representing the process of injection of CO 2 at the supercritical state into an underground reservoir were performed. An analysis of the obtained stress fields shows the possibility of generating various forms of material degradation for high injection rates. The work is devoted to the study of the emergence of opened cracks. Following an analytical and simplified study of the initiation and growth of opened cracks based on a probabilistic model, it is shown that the formation of a crack network is possible. The focus is then to develop in the finite element code Code Aster a numerical tool to simulate the formation of crack networks. A nonlocal model based on stress regularization is proposed. A test on the stress intensity factor is used to describe crack propagation. The initiation of new cracks is modeled by a Poisson-Weibull process. The used parameters are identified by an experimental campaign conducted on samples from an actual geological site for CO 2 storage. The model developed is then validated on numerical cases, and also against experimental results carried out herein. (author)

Geochemical Implications of CO2 Leakage Associated with Geologic Storage: A Review

Energy Technology Data Exchange (ETDEWEB)

Harvey, Omar R.; Qafoku, Nikolla; Cantrell, Kirk J.; Brown, Christopher F.

2012-07-09

Leakage from deep storage reservoirs is a major risk factor associated with geologic sequestration of carbon dioxide (CO2). Different scientific theories exist concerning the potential implications of such leakage for near-surface environments. The authors of this report reviewed the current literature on how CO2 leakage (from storage reservoirs) would likely impact the geochemistry of near surface environments such as potable water aquifers and the vadose zone. Experimental and modeling studies highlighted the potential for both beneficial (e.g., CO2 re sequestration or contaminant immobilization) and deleterious (e.g., contaminant mobilization) consequences of CO2 intrusion in these systems. Current knowledge gaps, including the role of CO2-induced changes in redox conditions, the influence of CO2 influx rate, gas composition, organic matter content and microorganisms are discussed in terms of their potential influence on pertinent geochemical processes and the potential for beneficial or deleterious outcomes. Geochemical modeling was used to systematically highlight why closing these knowledge gaps are pivotal. A framework for studying and assessing consequences associated with each factor is also presented in Section 5.6.

Effects of CO2 gas as leaks from geological storage sites on agro-ecosystems

DEFF Research Database (Denmark)

Patil, Ravi; Colls, Jeremy J; Steven, Michael D

2010-01-01

Carbon capture and storage in geological formations has potential risks in the long-term safety because of the possibility of CO2 leakage. Effects of leaking gas, therefore, on vegetation, soil, and soil-inhabiting organisms are critical to understand. An artificial soil gassing and response...... detection field facility developed at the University of Nottingham was used to inject CO2 gas at a controlled flow rate (1 l min-1) into soil to simulate build-up of soil CO2 concentrations and surface fluxes from two land use types: pasture grassland, and fallow followed by winter bean. Mean soil CO2....... This study showed adverse effects of CO2 gas on agro-ecosystem in case of leakage from storage sites to surface....

CO 2 breakthrough—Caprock sealing efficiency and integrity for carbon geological storage

KAUST Repository

Espinoza, D. Nicolas

2017-10-23

Small pores in high specific surface clay-rich caprocks give rise to high capillary entry pressures and high viscous drag that hinder the migration of buoyant carbon dioxide CO2. We measured the breakthrough pressure and ensuing CO2 permeability through sediment plugs prepared with sand, silt, kaolinite and smectite, and monitored their volumetric deformation using high-pressure oedometer cells. The data show water expulsion and volumetric contraction prior to CO2 breakthrough, followed by preferential CO2 flow thereafter. Our experimental results and data gathered from previous studies highlight the inverse relationship between breakthrough pressure and pore size, as anticipated by Laplace’s equation. In terms of macro-scale parameters, the breakthrough pressure increases as the sediment specific surface increases and the porosity decreases. The breakthrough pressure is usually lower than the values predicted with average pore size estimations; it can reach ∼6.2MPa in argillaceous formations, and 11.2MPa in evaporites. The CO2 permeability after breakthrough is significantly lower than the absolute permeability, but it may increase in time due to water displacement and desiccation. Leakage will be advection-controlled once percolation takes place at most storage sites currently being considered. Diffusive and advective CO2 leaks through non-fractured caprocks will be minor and will not compromise the storage capacity at CO2 injection sites. The “sealing number” and the “stability number” combine the initial fluid pressure, the buoyant pressure caused by the CO2 plume, the capillary breakthrough pressure of the caprock, and the stress conditions at the reservoir depth; these two numbers provide a rapid assessment of potential storage sites. Unexpected CO2 migration patterns emerge due to the inherent spatial variability and structural discontinuities in geological formations; sites with redundant seal layers should be sought for the safe and long

Capture and geological storage of CO{sub 2}. Innovation, industrial stakes and realizations; Captage et stockage geologique du CO{sub 2}. Innovation, enjeux industriels et realisations

Energy Technology Data Exchange (ETDEWEB)

Lavergne, R.; Podkanski, J.; Rohner, H.; Otter, N.; Swift, J.; Dance, T.; Vesseron, Ph.; Reich, J.P.; Reynen, B.; Wright, L.; Marliave, L. de; Stromberg, L.; Aimard, N.; Wendel, H.; Erdol, E.; Dino, R.; Renzenbrink, W.; Birat, J.P.; Czernichowski-Lauriol, I.; Christensen, N.P.; Le Thiez, P.; Paelinck, Ph.; David, M.; Pappalardo, M.; Moisan, F.; Marston, Ph.; Law, M.; Zakkour, P.; Singer, St.; Philippe, Th.; Philippe, Th

2007-07-01

-making industries and their CO{sub 2} capture and storage needs: the ULCOS program; CO{sub 2} capture technologies: road-maps and potential cost abatement; membranes: oxygen production and hydrogen separation; CO2GeoNet: integration of European research for the establishment of confidence in CO{sub 2} geologic storage; CO2SINK, CO{sub 2} geologic storage test at the European pilot site of Ketzin (Germany); storage in aquifers for European industrial projects: AQUA CO2; the US approach: US standards for the qualification of a CO{sub 2} storage in agreement with federal and state regulations; legal and regulatory aspects; societal acceptation; CO{sub 2} capture, geologic storage and carbon market; economic aspects of CO{sub 2} capture and storage; an experience of implementation of 'clean development mechanisms' in an industrial strategy; closing talk. (J.S.)

Capture and geological storage of CO{sub 2}. Innovation, industrial stakes and realizations; Captage et stockage geologique du CO{sub 2}. Innovation, enjeux industriels et realisations

Energy Technology Data Exchange (ETDEWEB)

Lavergne, R; Podkanski, J; Rohner, H; Otter, N; Swift, J; Dance, T; Vesseron, Ph; Reich, J P; Reynen, B; Wright, L; Marliave, L de; Stromberg, L; Aimard, N; Wendel, H; Erdol, E; Dino, R; Renzenbrink, W; Birat, J P; Czernichowski-Lauriol, I; Christensen, N P; Le Thiez, P; Paelinck, Ph; David, M; Pappalardo, M; Moisan, F; Marston, Ph; Law, M; Zakkour, P; Singer, St; Philippe, Th; Philippe, Th

2007-07-01

and their CO{sub 2} capture and storage needs: the ULCOS program; CO{sub 2} capture technologies: road-maps and potential cost abatement; membranes: oxygen production and hydrogen separation; CO2GeoNet: integration of European research for the establishment of confidence in CO{sub 2} geologic storage; CO2SINK, CO{sub 2} geologic storage test at the European pilot site of Ketzin (Germany); storage in aquifers for European industrial projects: AQUA CO2; the US approach: US standards for the qualification of a CO{sub 2} storage in agreement with federal and state regulations; legal and regulatory aspects; societal acceptation; CO{sub 2} capture, geologic storage and carbon market; economic aspects of CO{sub 2} capture and storage; an experience of implementation of 'clean development mechanisms' in an industrial strategy; closing talk. (J.S.)

Developments since 2005 in understanding potential environmental impacts of CO2 leakage from geological storage

NARCIS (Netherlands)

Jones, D.G.; Beaubien, S.E.; Blackford, J.C.; Foekema, E.M.; Lions, J.; Vittor, de C.; West, J.M.; Widdicombe, S.; Hauton, C.; Queiros, A.M.

2015-01-01

This paper reviews research into the potential environmental impacts of leakage from geological storage of CO2 since the publication of the IPCC Special Report on Carbon Dioxide Capture and Storage in 2005. Possible impacts are considered on onshore (including drinking water aquifers) and offshore

U.S. Department of Energy's site screening, site selection, and initial characterization for storage of CO2 in deep geological formations

Science.gov (United States)

Rodosta, T.D.; Litynski, J.T.; Plasynski, S.I.; Hickman, S.; Frailey, S.; Myer, L.

2011-01-01

The U.S. Department of Energy (DOE) is the lead Federal agency for the development and deployment of carbon sequestration technologies. As part of its mission to facilitate technology transfer and develop guidelines from lessons learned, DOE is developing a series of best practice manuals (BPMs) for carbon capture and storage (CCS). The "Site Screening, Site Selection, and Initial Characterization for Storage of CO2 in Deep Geological Formations" BPM is a compilation of best practices and includes flowchart diagrams illustrating the general decision making process for Site Screening, Site Selection, and Initial Characterization. The BPM integrates the knowledge gained from various programmatic efforts, with particular emphasis on the Characterization Phase through pilot-scale CO2 injection testing of the Validation Phase of the Regional Carbon Sequestration Partnership (RCSP) Initiative. Key geologic and surface elements that suitable candidate storage sites should possess are identified, along with example Site Screening, Site Selection, and Initial Characterization protocols for large-scale geologic storage projects located across diverse geologic and regional settings. This manual has been written as a working document, establishing a framework and methodology for proper site selection for CO2 geologic storage. This will be useful for future CO2 emitters, transporters, and storage providers. It will also be of use in informing local, regional, state, and national governmental agencies of best practices in proper sequestration site selection. Furthermore, it will educate the inquisitive general public on options and processes for geologic CO2 storage. In addition to providing best practices, the manual presents a geologic storage resource and capacity classification system. The system provides a "standard" to communicate storage and capacity estimates, uncertainty and project development risk, data guidelines and analyses for adequate site characterization, and

The influence of open fracture anisotropy on CO2 movement within geological storage complexes

Science.gov (United States)

Bond, C. E.; Wightman, R.; Ringrose, P. S.

2012-12-01

Carbon mitigation through the geological storage of carbon dioxide is dependent on the ability of geological formations to store CO2 trapping it within a geological storage complex. Secure long-term containment needs to be demonstrated, due to both political and social drivers, meaning that this containment must be verifiable over periods of 100-105 years. The effectiveness of sub-surface geological storage systems is dependent on trapping CO2 within a volume of rock and is reliant on the integrity of the surrounding rocks, including their chemical and physical properties, to inhibit migration to the surface. Oil and gas reservoir production data, and field evidence show that fracture networks have the potential to act as focused pathways for fluid movement. Fracture networks can allow large volumes of fluid to migrate to the surface within the time scales of interest. In this paper we demonstrate the importance of predicting the effects of fracture networks in storage, using a case study from the In Salah CO2 storage site, and show how the fracture permeability is closely controlled by the stress regime that determines the open fracture network. Our workflow combines well data of imaged fractures, with a discrete fracture network (DFN) model of tectonically induced fractures, within the horizon of interest. The modelled and observed fractures have been compared and combined with present day stress data to predict the open fracture network and its implications for anisotropic movement of CO2 in the sub-surface. The created fracture network model has been used to calculate the 2D permeability tensor for the reservoir for two scenarios: 1) a model in which all fractures are permeable, based on the whole DFN model and 2) those fractures determined to be in dilatational failure under the present day stress regime, a sub-set of the DFN. The resulting permeability anisotropy tensors show distinct anisotropies for the predicted CO2 movement within the reservoir. These

Reduction of emissions and geological storage of CO{sub 2}. Innovation an industrial stakes; Reduction des emissions et stockage geologique du CO{sub 2}. Innovation et enjeux industriels

Energy Technology Data Exchange (ETDEWEB)

Mandil, C.; Podkanski, J.; Socolow, R.; Dron, D.; Reiner, D.; Horrocks, P.; Fernandez Ruiz, P.; Dechamps, P.; Stromberg, L.; Wright, I.; Gazeau, J.C.; Wiederkehr, P.; Morcheoine, A.; Vesseron, P.; Feron, P.; Feraud, A.; Torp, N.T.; Christensen, N.P.; Le Thiez, P.; Czernichowski, I.; Hartman, J.; Roulet, C.; Roberts, J.; Zakkour, P.; Von Goerne, G.; Armand, R.; Allinson, G.; Segalen, L.; Gires, J.M.; Metz, B.; Brillet, B

2005-07-01

An international symposium on the reduction of emissions and geological storage of CO{sub 2} was held in Paris from 15 to 16 September 2005. The event, jointly organized by IFP, ADEME and BRGM, brought together over 400 people from more than 25 countries. It was an opportunity to review the international stakes related to global warming and also to debate ways of reducing CO{sub 2} emissions, taking examples from the energy and transport sectors. The last day was dedicated to technological advances in the capture and geological storage of CO{sub 2} and their regulatory and economic implications. This document gathers the available transparencies and talks presented during the colloquium: Opening address by F. Loos, French Minister-delegate for Industry; Session I - Greenhouse gas emissions: the international stakes. Outlook for global CO{sub 2} emissions. The global and regional scenarios: Alternative scenarios for energy use and CO{sub 2} emissions until 2050 by C. Mandil and J. Podkanski (IEA), The stabilization of CO{sub 2} emissions in the coming 50 years by R. Socolow (Princeton University). Evolution of the international context: the stakes and 'factor 4' issues: Costs of climate impacts and ways towards 'factor 4' by D. Dron (ENS Mines de Paris), CO{sub 2} emissions reduction policy: the situation in the United States by D. Reiner (MIT/Cambridge University), Post-Kyoto scenarios by P. Horrocks (European Commission), Possibilities for R and D in CO{sub 2} capture and storage in the future FP7 program by P. Fernandez Ruiz and P. Dechamps (European Commission). Session II - CO{sub 2} emission reductions in the energy and transport sectors. Reducing CO{sub 2} emissions during the production and conversion of fossil energies (fixed installations): Combined cycles using hydrogen by G. Haupt (Siemens), CO{sub 2} emission reductions in the oil and gas industry by I. Wright (BP). Reducing CO{sub 2} emissions in the transport sector: Sustainable

What does CO2 geological storage really mean?

International Nuclear Information System (INIS)

2008-01-01

It is now accepted that human activities are disturbing the carbon cycle of the planet. CO 2 , a greenhouse gas, has accumulated in the atmosphere where it contributes to climate change. Amongst the spectrum of short term measures that need to be urgently implemented to mitigate climate change, CO 2 capture and storage can play a decisive role as it could contribute 33% of the CO 2 reduction needed by 2050. This document aims to explain this solution by answering the following questions: where and how much CO 2 can we store underground, How can we transport and inject large quantities of CO 2 , What happens to the CO 2 once in the storage reservoir? Could CO 2 leak from the reservoir and if so, what might be the consequences? How can we monitor the storage site at depth and at the surface? What safety criteria need to be imposed and respected? (A.L.B.)

SIMULATION FRAMEWORK FOR REGIONAL GEOLOGIC CO{sub 2} STORAGE ALONG ARCHES PROVINCE OF MIDWESTERN UNITED STATES

Energy Technology Data Exchange (ETDEWEB)

Sminchak, Joel

2012-09-30

This report presents final technical results for the project Simulation Framework for Regional Geologic CO{sub 2} Storage Infrastructure along Arches Province of the Midwest United States. The Arches Simulation project was a three year effort designed to develop a simulation framework for regional geologic carbon dioxide (CO{sub 2}) storage infrastructure along the Arches Province through development of a geologic model and advanced reservoir simulations of large-scale CO{sub 2} storage. The project included five major technical tasks: (1) compilation of geologic, hydraulic and injection data on Mount Simon, (2) development of model framework and parameters, (3) preliminary variable density flow simulations, (4) multi-phase model runs of regional storage scenarios, and (5) implications for regional storage feasibility. The Arches Province is an informal region in northeastern Indiana, northern Kentucky, western Ohio, and southern Michigan where sedimentary rock formations form broad arch and platform structures. In the province, the Mount Simon sandstone is an appealing deep saline formation for CO{sub 2} storage because of the intersection of reservoir thickness and permeability. Many CO{sub 2} sources are located in proximity to the Arches Province, and the area is adjacent to coal fired power plants along the Ohio River Valley corridor. Geophysical well logs, rock samples, drilling logs, and geotechnical tests were evaluated for a 500,000 km{sup 2} study area centered on the Arches Province. Hydraulic parameters and historical operational information was also compiled from Mount Simon wastewater injection wells in the region. This information was integrated into a geocellular model that depicts the parameters and conditions in a numerical array. The geologic and hydraulic data were integrated into a three-dimensional grid of porosity and permeability, which are key parameters regarding fluid flow and pressure buildup due to CO{sub 2} injection. Permeability data

Leakage of CO2 from geologic storage: Role of secondaryaccumulation at shallow depth

Energy Technology Data Exchange (ETDEWEB)

Pruess, K.

2007-05-31

Geologic storage of CO2 can be a viable technology forreducing atmospheric emissions of greenhouse gases only if it can bedemonstrated that leakage from proposed storage reservoirs and associatedhazards are small or can be mitigated. Risk assessment must evaluatepotential leakage scenarios and develop a rational, mechanisticunderstanding of CO2 behavior during leakage. Flow of CO2 may be subjectto positive feedbacks that could amplify leakage risks and hazards,placing a premium on identifying and avoiding adverse conditions andmechanisms. A scenario that is unfavorable in terms of leakage behavioris formation of a secondary CO2 accumulation at shallow depth. This paperdevelops a detailed numerical simulation model to investigate CO2discharge from a secondary accumulation, and evaluates the role ofdifferent thermodynamic and hydrogeologic conditions. Our simulationsdemonstrate self-enhancing as well as self-limiting feedbacks.Condensation of gaseous CO2, 3-phase flow of aqueous phase -- liquid CO2-- gaseous CO2, and cooling from Joule-Thomson expansion and boiling ofliquid CO2 are found to play important roles in the behavior of a CO2leakage system. We find no evidence that a subsurface accumulation of CO2at ambient temperatures could give rise to a high-energy discharge, aso-called "pneumatic eruption."

Geological storage of CO2: What do we know, where are the gaps and what more needs to be done?

International Nuclear Information System (INIS)

Gale, John

2004-01-01

If deep reductions in anthropogenic greenhouse gas emissions are to be achieved, the introduction of CO 2 capture and storage in geological reservoirs is likely to be necessary. The technology would be deployed alongside other mitigation measures such as renewables, energy efficiency and fuel switching. Currently, research programmes on the geological storage of CO 2 are underway in the United States, the European Union, Australia and Japan. The aim of this paper is to present an overview of the research work that is currently underway and provide an analysis of the current state of knowledge on geological storage of CO 2. The analysis will be broken down to address the key geological storage options: deep coal seams, depleted hydrocarbon reservoirs and deep saline aquifers. In each case, areas of uncertainty will be highlighted as well as areas where it is considered that further work will be needed so that the technology can be accepted by Governments and the general public as a mitigation option suitable for wide-scale application throughout the world

Geological storage of CO2: what do we know, where are the gaps and what more needs to be done?

International Nuclear Information System (INIS)

Gale, J.

2004-01-01

If deep reductions in anthropogenic greenhouse gas emissions are to be achieved, the introduction of CO 2 capture and storage in geological reservoirs is likely to be necessary. The technology would be deployed alongside other mitigation measures such as renewables, energy efficiency and fuel switching. Currently, research programmes on the geological storage of CO 2 are underway in the United States, the European Union, Australia and Japan. The aim of this paper is to present an overview of the research work that is currently underway and provide an analysis of the current state of knowledge on geological storage of CO 2 . The analysis will be broken down to address the key geological storage options: deep coal seams, depleted hydrocarbon reservoirs and deep saline aquifers. In each case, areas of uncertainty will be highlighted as well as areas where it is considered that further work will be needed so that the technology can be accepted by Governments and the general public as a mitigation option suitable for wide-scale application throughout the world. (author)

Geological storage of CO2: risks analysis, monitoring and measures. Final report

International Nuclear Information System (INIS)

Abou Akar, A.; Audibert, N.; Audigane, P.; Baranger, P.; Bonijoly, D.; Carnec, C.; Czernichowski, I.; Debeglia, N.; Fabriol, H.; Foerster, E.; Gaus, I.; Le Nindre, Y.; Michel, K.; Morin, D.; Roy, S.; Sanjuan, B.; Sayedi, D.

2005-01-01

To use the CO 2 geological storage as a coherent solution in the greenhouse gases reduction it needs to answer to safety and monitoring conditions. In this framework the BRGM presents this study in six chapters: risks analysis, the monitoring methods (geochemistry, geophysics, aerial monitoring, biochemistry, hydrogeology), the metrology, the corrosion problems, the thermal, hydrodynamical, geochemical and mechanical simulation and the today and future regulations. (A.L.B.)

Site characterization of the highest-priority geologic formations for CO₂ storage in Wyoming

Energy Technology Data Exchange (ETDEWEB)

Surdam, Ronald C. [Univ. of Wyoming, Laramie, WY (United States); Bentley, Ramsey [Univ. of Wyoming, Laramie, WY (United States); Campbell-Stone, Erin [Univ. of Wyoming, Laramie, WY (United States); Dahl, Shanna [Univ. of Wyoming, Laramie, WY (United States); Deiss, Allory [Univ. of Wyoming, Laramie, WY (United States); Ganshin, Yuri [Univ. of Wyoming, Laramie, WY (United States); Jiao, Zunsheng [Univ. of Wyoming, Laramie, WY (United States); Kaszuba, John [Univ. of Wyoming, Laramie, WY (United States); Mallick, Subhashis [Univ. of Wyoming, Laramie, WY (United States); McLaughlin, Fred [Univ. of Wyoming, Laramie, WY (United States); Myers, James [Univ. of Wyoming, Laramie, WY (United States); Quillinan, Scott [Univ. of Wyoming, Laramie, WY (United States)

2013-12-07

This study, funded by U.S. Department of Energy National Energy Technology Laboratory award DE-FE0002142 along with the state of Wyoming, uses outcrop and core observations, a diverse electric log suite, a VSP survey, in-bore testing (DST, injection tests, and fluid sampling), a variety of rock/fluid analyses, and a wide range of seismic attributes derived from a 3-D seismic survey to thoroughly characterize the highest-potential storage reservoirs and confining layers at the premier CO₂ geological storage site in Wyoming. An accurate site characterization was essential to assessing the following critical aspects of the storage site: (1) more accurately estimate the CO₂ reservoir storage capacity (Madison Limestone and Weber Sandstone at the Rock Springs Uplift (RSU)), (2) evaluate the distribution, long-term integrity, and permanence of the confining layers, (3) manage CO₂ injection pressures by removing formation fluids (brine production/treatment), and (4) evaluate potential utilization of the stored CO₂

CO{sub 2}-GeoNet. A European network of excellence on geological storage of CO{sub 2}

Energy Technology Data Exchange (ETDEWEB)

Schulz, H.M. [GeoForschungsZentrum GFZ, Potzdam (Germany); May, F.; Gerling, P.; Kosinowski, M.; Krueger, M.; Faber, E.; Poggenburg, J.; Teschner, M. [Bundesanstalt fuer Geowissenschaften und Rohstoffe, Hannover (Germany)

2007-09-13

The Network of Excellence ''CO{sub 2}GeoNet'' contains a critical mass of European research institutions in the field of underground carbon dioxide (CO{sub 2}) storage. World projections of energy use show that fossil fuel dependency will continue to 2030 and beyond; but sustainability will need CO{sub 2} emissions to be reduced by 60% by 2050. This will be difficult and will require various strategies. The associated rise in global CO{sub 2} emissions, without abatement, will be at an average rate of 1.8% per annum (from the current value of 25 Gt p.a., to 38 Gt by 2030); a rise of over 50%. Urgent action is needed to cope with policy's objectives. Europe's CO{sub 2} emissions will rise by an average of 0.6% p.a. up to 2020, from a 2000 level of 3.1 Gt to 3.5 Gt by 2020. The rocks under the North Sea have a theoretical capacity for storing over 800 Gt of CO{sub 2}. Capturing CO{sub 2} from industrial point sources and storing it underground seems to be a very attractive route to making cuts in CO{sub 2} emissions. CO{sub 2} capture and storage allows diverse fuel inputs and outputs, enhances security of supply and is well aligned with hydrogen production from fossil fuels. Through a number of projects supported by the European Commission (e.g. Joule 2, Research Framework Programmes 4 and 5) Europe has led the World on R and D in this area, with rapid growth during the last decade. National programmes are also emerging. This success has a downside, by creating fragmentation through diversification. North America despite its rejection of the Kyoto protocol (except Canada), has recently embraced CO{sub 2} capture and geological storage and is allocating huge resources (over $4bn) over the next 10 years. Europe, as a result, risks losing its head start. We therefore must work more effectively and restructure our efforts. The main aim of CO{sub 2}GeoNet will be to integrate, strengthen, and build upon the momentum of previous and existing

Developments and innovation in carbon dioxide (CO{sub 2}) capture and storage technology. Volume 2: Carbon dioxide (CO{sub 2}) storage and utilisation

Energy Technology Data Exchange (ETDEWEB)

Mercedes Maroto-Valer, M. (ed.)

2010-07-01

This volume initially reviews geological sequestration of CO{sub 2}, from saline aquifer sequestration to oil and gas reservoir and coal bed storage, including coverage of reservoir sealing, and monitoring and modelling techniques used to verify geological sequestration of CO{sub 2}. Terrestrial and ocean sequestration are also reviewed, along with the environmental impact and performance assessments for these routes. The final section reviews advanced concepts for CO{sub 2} storage and utilization, such as industrial utilization, biofixation, mineral carbonation and photocatalytic reduction.

SIMULATION FRAMEWORK FOR REGIONAL GEOLOGIC CO{sub 2} STORAGE ALONG ARCHES PROVINCE OF MIDWESTERN UNITED STATES

Energy Technology Data Exchange (ETDEWEB)

Sminchak, Joel

2012-09-30

This report presents final technical results for the project Simulation Framework for Regional Geologic CO{sub 2} Storage Infrastructure along Arches Province of the Midwest United States. The Arches Simulation project was a three year effort designed to develop a simulation framework for regional geologic carbon dioxide (CO{sub 2}) storage infrastructure along the Arches Province through development of a geologic model and advanced reservoir simulations of large-scale CO{sub 2} storage. The project included five major technical tasks: (1) compilation of geologic, hydraulic and injection data on Mount Simon, (2) development of model framework and parameters, (3) preliminary variable density flow simulations, (4) multi-phase model runs of regional storage scenarios, and (5) implications for regional storage feasibility. The Arches Province is an informal region in northeastern Indiana, northern Kentucky, western Ohio, and southern Michigan where sedimentary rock formations form broad arch and platform structures. In the province, the Mount Simon sandstone is an appealing deep saline formation for CO{sub 2} storage because of the intersection of reservoir thickness and permeability. Many CO{sub 2} sources are located in proximity to the Arches Province, and the area is adjacent to coal fired power plants along the Ohio River Valley corridor. Geophysical well logs, rock samples, drilling logs, and geotechnical tests were evaluated for a 500,000 km{sup 2} study area centered on the Arches Province. Hydraulic parameters and historical operational information was also compiled from Mount Simon wastewater injection wells in the region. This information was integrated into a geocellular model that depicts the parameters and conditions in a numerical array. The geologic and hydraulic data were integrated into a three-dimensional grid of porosity and permeability, which are key parameters regarding fluid flow and pressure buildup due to CO{sub 2} injection. Permeability data

Experiment and simulation study on the effects of cement minerals on the water-rock-CO2 interaction during CO2 geological storage

Science.gov (United States)

Liu, N.; Cheng, J.

2016-12-01

The CO2 geological storage is one of the most promising technology to mitigate CO2 emission. The fate of CO2 underground is dramatically affected by the CO2-water-rock interaction, which are mainly dependent on the initial aquifer mineralogy and brine components. The cement minerals are common materials in sandstone reservoir but few attention has been paid for its effects on CO2-water-rock interaction. Five batch reactions, in which 5% cement minerals were assigned to be quartz, calcite, dolomite, chlorite and Ca-montmorillonite, respectively, were conducted to understanding the cement minerals behaviors and its corresponding effects on the matrix minerals alterations during CO2 geological storage. Pure mineral powders were selected to mix and assemble the 'sandstone rock' with different cement components meanwhile keeping the matrix minerals same for each group as 70% quartz, 20% K-feldspar and 5% albite. These `rock' reacted with 750ml deionized water and CO2 under 180° and 18MPa for 15 days, during which the water chemistry evolution and minerals surface micromorphology changes has been monitored. The minerals saturation indexes calculation and phase diagram as well as the kinetic models were made by PHREEQC to uncover the minerals reaction paths. The experiment results indicated that the quartz got less eroded, on the contrary, K-feldspar and albite continuously dissolved to favor the gibbsite and kaolinite precipitations. The carbonates cement minerals quickly dissolved to reach equilibrium with the pH buffered and in turn suppressed the alkali feldspar dissolutions. No carbonates minerals precipitations occurred until the end of reactions for all groups. The simulation results were basically consistent with the experiment record but failed to simulate the non-stoichiometric reactions and the minerals kinetic rates seemed underestimated at the early stage of reactions. The cement minerals significantly dominated the reaction paths during CO2 geological

What does CO{sub 2} geological storage really mean?

Energy Technology Data Exchange (ETDEWEB)

NONE

2008-07-01

It is now accepted that human activities are disturbing the carbon cycle of the planet. CO{sub 2}, a greenhouse gas, has accumulated in the atmosphere where it contributes to climate change. Amongst the spectrum of short term measures that need to be urgently implemented to mitigate climate change, CO{sub 2} capture and storage can play a decisive role as it could contribute 33% of the CO{sub 2} reduction needed by 2050. This document aims to explain this solution by answering the following questions: where and how much CO{sub 2} can we store underground, How can we transport and inject large quantities of CO{sub 2}, What happens to the CO{sub 2} once in the storage reservoir? Could CO{sub 2} leak from the reservoir and if so, what might be the consequences? How can we monitor the storage site at depth and at the surface? What safety criteria need to be imposed and respected? (A.L.B.)

Rapid solubility and mineral storage of CO₂ in basalt

DEFF Research Database (Denmark)

Gislason, Sigurdur R.; Broecker, W.S.; Gunnlaugsson, E.

2014-01-01

The long-term security of geologic carbon storage is critical to its success and public acceptance. Much of the security risk associated with geological carbon storage stems from its buoyancy. Gaseous and supercritical CO2 are less dense than formation waters, providing a driving force for it to ......The long-term security of geologic carbon storage is critical to its success and public acceptance. Much of the security risk associated with geological carbon storage stems from its buoyancy. Gaseous and supercritical CO2 are less dense than formation waters, providing a driving force...... for it to escape back to the surface. This buoyancy can be eliminated by the dissolution of CO2 into water prior to, or during its injection into the subsurface. The dissolution makes it possible to inject into fractured rocks and further enhance mineral storage of CO2 especially if injected into silicate rocks...... rich in divalent metal cations such as basalts and ultra-mafic rocks. We have demonstrated the dissolution of CO2 into water during its injection into basalt leading to its geologic solubility storage in less than five minutes and potential geologic mineral storage within few years after injection [1...

Modeling Diffusion and Buoyancy-Driven Convection with Application to Geological CO2 Storage

KAUST Repository

Allen, Rebecca

2015-04-01

ABSTRACT Modeling Diffusion and Buoyancy-Driven Convection with Application to Geological CO2 Storage Rebecca Allen Geological CO2 storage is an engineering feat that has been undertaken around the world for more than two decades, thus accurate modeling of flow and transport behavior is of practical importance. Diffusive and convective transport are relevant processes for buoyancy-driven convection of CO2 into underlying fluid, a scenario that has received the attention of numerous modeling studies. While most studies focus on Darcy-scale modeling of this scenario, relatively little work exists at the pore-scale. In this work, properties evaluated at the pore-scale are used to investigate the transport behavior modeled at the Darcy-scale. We compute permeability and two different forms of tortuosity, namely hydraulic and diffusive. By generating various pore ge- ometries, we find hydraulic and diffusive tortuosity can be quantitatively different in the same pore geometry by up to a factor of ten. As such, we emphasize that these tortuosities should not be used interchangeably. We find pore geometries that are characterized by anisotropic permeability can also exhibit anisotropic diffusive tortuosity. This finding has important implications for buoyancy-driven convection modeling; when representing the geological formation with an anisotropic permeabil- ity, it is more realistic to also account for an anisotropic diffusivity. By implementing a non-dimensional model that includes both a vertically and horizontally orientated 5 Rayleigh number, we interpret our findings according to the combined effect of the anisotropy from permeability and diffusive tortuosity. In particular, we observe the Rayleigh ratio may either dampen or enhance the diffusing front, and our simulation data is used to express the time of convective onset as a function of the Rayleigh ratio. Also, we implement a lattice Boltzmann model for thermal convective flows, which we treat as an analog for

Comparison of Dry Gas Seasonal Storage with CO2 Storage and Re-Use Potential

OpenAIRE

Killerud, Marie

2013-01-01

To make large-scale CO2 storage economic, many groups have proposed using CO2in EOR projects to create value for CO2 storage. However, CO2 EOR projectsgenerally require a large and variable supply of CO2 and consequently may requiretemporary storage of CO2 in geological formations. In order to store CO2 atoffshore sites as a source for CO2 EOR projects, the CO2 needs to be extractedfrom a storage site to a certain extent. Alternatively, CO2 EOR projects maybe developed alongside saline aquife...

Simulation of CO2–water–rock interactions on geologic CO2 sequestration under geological conditions of China

International Nuclear Information System (INIS)

Wang, Tianye; Wang, Huaiyuan; Zhang, Fengjun; Xu, Tianfu

2013-01-01

Highlights: • We determined the feasibilities of geologic CO 2 sequestration in China. • We determined the formation of gibbsite suggested CO 2 can be captured by rocks. • We suggested the mechanisms of CO 2 –water–rock interactions. • We found the corrosion and dissolution of the rock increased as temperature rose. -- Abstract: The main purpose of this study focused on the feasibility of geologic CO 2 sequestration within the actual geological conditions of the first Carbon Capture and Storage (CCS) project in China. This study investigated CO 2 –water–rock interactions under simulated hydrothermal conditions via physicochemical analyses and scanning electron microscopy (SEM). Mass loss measurement and SEM showed that corrosion of feldspars, silica, and clay minerals increased with increasing temperature. Corrosion of sandstone samples in the CO 2 -containing fluid showed a positive correlation with temperature. During reaction at 70 °C, 85 °C, and 100 °C, gibbsite (an intermediate mineral product) formed on the sample surface. This demonstrated mineral capture of CO 2 and supported the feasibility of geologic CO 2 sequestration. Chemical analyses suggested a dissolution–reprecipitation mechanism underlying the CO 2 –water–rock interactions. The results of this study suggested that mineral dissolution, new mineral precipitation, and carbonic acid formation-dissociation are closely interrelated in CO 2 –water–rock interactions

Mathematical programming (MP) model to determine optimal transportation infrastructure for geologic CO2 storage in the Illinois basin

Science.gov (United States)

Rehmer, Donald E.

Analysis of results from a mathematical programming model were examined to 1) determine the least cost options for infrastructure development of geologic storage of CO2 in the Illinois Basin, and 2) perform an analysis of a number of CO2 emission tax and oil price scenarios in order to implement development of the least-cost pipeline networks for distribution of CO2. The model, using mixed integer programming, tested the hypothesis of whether viable EOR sequestration sites can serve as nodal points or hubs to expand the CO2 delivery infrastructure to more distal locations from the emissions sources. This is in contrast to previous model results based on a point-to- point model having direct pipeline segments from each CO2 capture site to each storage sink. There is literature on the spoke and hub problem that relates to airline scheduling as well as maritime shipping. A large-scale ship assignment problem that utilized integer linear programming was run on Excel Solver and described by Mourao et al., (2001). Other literature indicates that aircraft assignment in spoke and hub routes can also be achieved using integer linear programming (Daskin and Panayotopoulos, 1989; Hane et al., 1995). The distribution concept is basically the reverse of the "tree and branch" type (Rothfarb et al., 1970) gathering systems for oil and natural gas that industry has been developing for decades. Model results indicate that the inclusion of hubs as variables in the model yields lower transportation costs for geologic carbon dioxide storage over previous models of point-to-point infrastructure geometries. Tabular results and GIS maps of the selected scenarios illustrate that EOR sites can serve as nodal points or hubs for distribution of CO2 to distal oil field locations as well as deeper saline reservoirs. Revenue amounts and capture percentages both show an improvement over solutions when the hubs are not allowed to come into the solution. Other results indicate that geologic

Could a geological storage of the CO2 emissions from Romanian power plants become a joint implementation project?

International Nuclear Information System (INIS)

Matei, Magdalena; Ene, Simona; Necula, Catalina; Matei, Lucian; Marinescu, Mihai

2006-01-01

Full text: Emissions trading is a solution that is most compatible with deregulated electricity markets. The Directive 2003/87/CE referring to CO 2 emission trading within Europe entered into force and till 31 March 2004 all the countries had to present to the Commission their national plan to comply with Directive's rules. Recent predictions of the Intergovernmental Panel on Climate Change indicate that global warming will accelerate within this century. CO 2 emitted by the burning of fossil fuels is thought to be a main driving factor of climate change. With the potential to produce power without releasing CO 2 into the atmosphere, CO 2 capturing may become an important part of the post- Kyoto strategies of many countries. Underground storage of CO 2 seems to be one of the most attractive alternative. Potential targets for CO 2 injection are: - depleted oil reservoirs, possibly in combination with enhanced oil recovery - former gas fields, possibly with additional gas production - deep aquifers containing saline, non-drinkable water - deep and unminable coal seams (exchange of absorbed methane by CO 2 with simultaneous gas production) - geothermal wells, after heat extraction from the aquifers - residual volumes of former deep coal and salt mines. An environmental political decision about the option of CO 2 underground storage has to consider forecasts about developments of global climate, societies, and economics. Due to the forthcoming emission trading there is a growing interest in underground storage options for CO 2 in Europe now. Flexible mechanisms agreed by Kyoto Protocol, namely the Project-based Joint Implementation (Art. 6) and the Emission Trading (Art. 17) could help Romania to attract investment with a long term impact on emissions reduction. The brief identification of major CO 2 emissions sources and of possible CO 2 geological storage capacities (coal mines, aquifers, geothermal wells, oil and gas fields) shows that it is very probable to

NOVEL CONCEPTS RESEARCH IN GEOLOGIC STORAGE OF CO2 PHASE III

Energy Technology Data Exchange (ETDEWEB)

Neeraj Gupta

2006-01-23

As part of the Department of Energy's (DOE) initiative on developing new technologies for storage of carbon dioxide in geologic reservoirs, Battelle has been investigating the feasibility of CO{sub 2} sequestration in the deep saline reservoirs in the Ohio River Valley region. In addition to the DOE, the project is being sponsored by American Electric Power (AEP), BP, The Ohio Coal Development Office (OCDO) of the Ohio Air Quality Development Authority, Schlumberger, and Battelle. The main objective of the project is to demonstrate that CO{sub 2} sequestration in deep formations is feasible from engineering and economic perspectives, as well as being an inherently safe practice and one that will be acceptable to the public. In addition, the project is designed to evaluate the geology of deep formations in the Ohio River Valley region in general and in the vicinity of AEP's Mountaineer Power Plant in particular, in order to determine their potential use for conducting a long-term test of CO{sub 2} disposal in deep saline formations. The current technical progress report summarizes activities completed for the October through December 2005 period of the project. As discussed in the following report, the main field activity was reservoir testing in the Copper Ridge ''B-zone'' in the AEP No.1 well. In addition reservoir simulations were completed to assess feasibility of CO{sub 2} injection for the Mountaineer site. These reservoir testing and computer simulation results suggest that injection potential may be substantially more than anticipated for the Mountaineer site. Work also continued on development of injection well design options, engineering assessment of CO{sub 2} capture systems, permitting, and assessment of monitoring technologies as they apply to the project site. Overall, the current design feasibility phase project is proceeding according to plans.

Effects of CO2 gas as leaks from geological storage sites on agro-ecosystems

International Nuclear Information System (INIS)

Patil, Ravi H.; Colls, Jeremy J.; Steven, Michael D.

2010-01-01

Carbon capture and storage in geological formations has potential risks in the long-term safety because of the possibility of CO 2 leakage. Effects of leaking gas, therefore, on vegetation, soil, and soil-inhabiting organisms are critical to understand. An artificial soil gassing and response detection field facility developed at the University of Nottingham was used to inject CO 2 gas at a controlled flow rate (1 l min -1 ) into soil to simulate build-up of soil CO 2 concentrations and surface fluxes from two land use types: pasture grassland, and fallow followed by winter bean. Mean soil CO 2 concentrations was significantly higher in gassed pasture plots than in gassed fallow plots. Germination of winter bean sown in gassed fallow plots was severely hindered and the final crop stand was reduced to half. Pasture grass showed stress symptoms and above-ground biomass was significantly reduced compared to control plot. A negative correlation (r = -0.95) between soil CO 2 and O 2 concentrations indicated that injected CO 2 displaced O 2 from soil. Gassing CO 2 reduced soil pH both in grass and fallow plots (p = 0.012). The number of earthworm castings was twice as much in gassed plots than in control plots. This study showed adverse effects of CO 2 gas on agro-ecosystem in case of leakage from storage sites to surface.

Petrophysical Characterization of Arroyal Antiform Geological Formations (Aguilar de Campoo, Palencia) as a Storage and Seal Rocks in the Technology Development Plant for Geological CO2 Storage (Hontomin, Burgos)

International Nuclear Information System (INIS)

Campos, R.; Barrios, I.; Gonzalez, A. M.; Pelayo, M.; Saldana, R.

2011-01-01

The geological storage program of Energy City Foundation is focusing its research effort in the Technological Development and Research Plant in Hontomin (Burgos) start off. The present report shows the petrophysical characterization of of the Arroyal antiform geological formations since they are representatives, surface like, of the storage and seal formations that will be found in the CO 2 injection plant in Hontomin. In this petrophysics characterization has taken place the study of matrix porosity, specific surface and density of the storage and seal formations. Mercury intrusion porosimetry, N 2 adsorption and He pycnometry techniques have been used for the characterization. Furthermore, it has carried out a mineralogical analysis of the seal materials by RX diffraction. (Author) 26 refs.

Preliminary Safety and Risk HSE Assessment. Application to the Potential Locations of a CO2 Geological Storage Pilot

International Nuclear Information System (INIS)

Recreo, F.; Eguilior, S.; Ruiz, C.; Lomba, L.; Hurtado, A.

2015-01-01

The location of a site safe and able to sequester CO2 for long periods of time is essential to gain public acceptance. This requires a long-term safety assessment developed in a robust and reliable framework. Site selection is the first step and requires specific research. This paper describes the application of the Selection and Classification Method of Geological Formations (SCF) developed to assess the potential of geological formations to CO2 storage. This assessment is based in the analysis of risks to Health, Safety and Environment (HSE) derived from potential CO2 leakage. Comparisons of the results obtained from a number of potential sites can help to select the best candidate for CO2 injection. The potential impact will be related to three key potential features of CO2 geological storage: the potential of the target geological formation for long term CO2 containment; the potential for secondary containment on containment failure of the target formation; and the site's potential to mitigate and/or disperse CO2 leakage if the primary and secondary containments fail. The methodology assesses each of these three characteristics through an analysis and assessment of properties of certain attributes of them. Uncertainty will remain as an input and output value of the methodology due to the usual lack of data in most site selection processes. The global uncertainty reports on the trust on the knowledge of the site characteristics. Therefore, the methodology enables comparing sites taking into account both the HSE risk expectation and the estimation of the quality of knowledge concerning such risk. The objective is to contribute to the selection of potential sites for a CO2 injection pilot plant in the Iberian Peninsula from the perspective of Safety and Risk Analysis.

The effect of CO2 on the mechanical properties of the Captain Sandstone: Geological storage of CO2 at the Goldeneye field (UK)

NARCIS (Netherlands)

Hangx, Suzanne|info:eu-repo/dai/nl/30483579X; van der Linden, A.; Marcelis, F.; Bauer, A.

2013-01-01

Geological storage of CO2 in clastic reservoirs is expected to have a variety of coupled chemical-mechanical effects, which may damage the overlying caprock and/or the near-wellbore area. We performed conventional triaxial creep experiments, combined with fluid flow-through experiments (brine and

Capture and geologic storage of carbon dioxide (CO2)

International Nuclear Information System (INIS)

2004-11-01

This dossier about carbon sequestration presents: 1 - the world fossil fuels demand and its environmental impact; 2 - the solutions to answer the climatic change threat: limitation of fossil fuels consumption, development of nuclear and renewable energies, capture and storage of CO 2 (environmental and industrial advantage, cost); 3 - the CO 2 capture: post-combustion smokes treatment, oxi-combustion techniques, pre-combustion techniques; 4 - CO 2 storage: in hydrocarbon deposits (Weyburn site in Canada), in deep saline aquifers (Sleipner and K12B (North Sea)), in non-exploitable coal seams (Recopol European project); 5 - international and national mobilization: IEA R and D program, USA (FutureGen zero-emission coal-fired power plant, Carbon Sequestration Leadership forum), European Union (AZEP, GRACE, GESTCO, CO2STORE, NASCENT, RECOPOL, Castor, ENCAP, CO2sink etc programs), French actions (CO 2 club, network of oil and gas technologies (RTPG)), environmental stake, competitiveness, research stake. (J.S.)

Uncertainty studies and risk assessment for CO2 storage in geological formations

International Nuclear Information System (INIS)

Walter, Lena Sophie

2013-01-01

Carbon capture and storage (CCS) in deep geological formations is one possible option to mitigate the greenhouse gas effect by reducing CO 2 emissions into the atmosphere. The assessment of the risks related to CO 2 storage is an important task. Events such as CO 2 leakage and brine displacement could result in hazards for human health and the environment. In this thesis, a systematic and comprehensive risk assessment concept is presented to investigate various levels of uncertainties and to assess risks using numerical simulations. Depending on the risk and the processes, which should be assessed, very complex models, large model domains, large time scales, and many simulations runs for estimating probabilities are required. To reduce the resulting high computational costs, a model reduction technique (the arbitrary polynomial chaos expansion) and a method for model coupling in space are applied. The different levels of uncertainties are: statistical uncertainty in parameter distributions, scenario uncertainty, e.g. different geological features, and recognized ignorance due to assumptions in the conceptual model set-up. Recognized ignorance and scenario uncertainty are investigated by simulating well defined model set-ups and scenarios. According to damage values, which are defined as a model output, the set-ups and scenarios can be compared and ranked. For statistical uncertainty probabilities can be determined by running Monte Carlo simulations with the reduced model. The results are presented in various ways: e.g., mean damage, probability density function, cumulative distribution function, or an overall risk value by multiplying the damage with the probability. If the model output (damage) cannot be compared to provided criteria (e.g. water quality criteria), analytical approximations are presented to translate the damage into comparable values. The overall concept is applied for the risks related to brine displacement and infiltration into drinking water

Subtask 2.17 - CO₂ Storage Efficiency in Deep Saline Formations

Energy Technology Data Exchange (ETDEWEB)

Gorecki, Charles D. [Univ. of North Dakota, Grand Forks, ND (United States); Liu, Guoxiang [Univ. of North Dakota, Grand Forks, ND (United States); Braunberger, Jason R. [Univ. of North Dakota, Grand Forks, ND (United States); Klenner, Robert C. L. [Univ. of North Dakota, Grand Forks, ND (United States); Ayash, Scott C. [Univ. of North Dakota, Grand Forks, ND (United States); Dotzenrod, Neil W. [Univ. of North Dakota, Grand Forks, ND (United States); Steadman, Edward N. [Univ. of North Dakota, Grand Forks, ND (United States); Harju, John A. [Univ. of North Dakota, Grand Forks, ND (United States)

2014-02-01

As the field of carbon capture and storage (CCS) continues to advance, and large-scale implementation of geologic carbon dioxide (CO₂) storage progresses, it will be important to understand the potential of geologic formations to store meaningful amounts of CO₂. Geologic CO₂ storage in deep saline formations (DSFs) has been suggested as one of the best potential methods for reducing anthropogenic CO₂ emission to the atmosphere, and as such, updated storage resource estimation methods will continue to be an important component for the widespread deployment of CCS around the world. While there have been several methodologies suggested in the literature, most of these methods are based on a volumetric calculation of the pore volume of the DSF multiplied by a storage efficiency term and do not consider the effect of site-specific dynamic factors such as injection rate, injection pattern, timing of injection, pressure interference between injection locations, and overall formation pressure buildup. These volumetric methods may be excellent for comparing the potential between particular formations or basins, but they have not been validated through real-world experience or full-formation injection simulations. Several studies have also suggested that the dynamic components of geologic storage may play the most important role in storing CO₂ in DSFs but until now have not directly compared CO₂ storage resource estimates made with volumetric methodologies to estimates made using dynamic CO₂ storage methodologies. In this study, two DSFs, in geographically separate areas with geologically diverse properties, were evaluated with both volumetric and dynamic CO₂ storage resource estimation methodologies to compare the results and determine the applicability of both approaches. In the end, it was determined that the dynamic CO₂ storage resource potential is timedependent and it

CO2 storage in Sweden

International Nuclear Information System (INIS)

Ekstroem, Clas; Andersson, Annika; Kling, Aasa; Bernstone, Christian; Carlsson, Anders; Liljemark, Stefan; Wall, Caroline; Erstedt, Thomas; Lindroth, Maria; Tengborg, Per; Edstroem, Mikael

2004-07-01

This study considers options, that could be feasible for Sweden, to transport and geologically store CO 2 , providing that technology for electricity production with CO 2 capture will be available in the future and also acceptable from cost- and reliability point of view. As a starting point, it is assumed that a new 600-1000 MW power plant, fired with coal or natural gas, will be constructed with CO 2 capture and localised to the Stockholm, Malmoe or Goeteborg areas. Of vital importance for storage of carbon dioxide in a reservoir is the possibility to monitor its distribution, i.e. its migration within the reservoir. It has been shown in the SACS-project that the distribution of carbon dioxide within the reservoir can be monitored successfully, mainly by seismic methods. Suitable geologic conditions and a large storage potential seems to exist mainly in South West Scania, where additional knowledge on geology/hydrogeology has been obtained since the year 2000 in connection to geothermal energy projects, and in the Eastern part of Denmark, bordering on South West Scania. Storage of carbon dioxide from the Stockholm area should not be excluded, but more studies are needed to clarify the storage options within this area. The possibilities to use CO 2 for enhanced oil recovery, EOR, in i.a. the North Sea should be investigated, in order to receive incomes from the CO 2 and shared costs for infrastructure, and by this also make the CO 2 regarded as a trading commodity, and thereby achieving a more favourable position concerning acceptance, legal issues and regulations. The dimensions of CO 2 -pipelines should be similar to those for natural natural gas, although regarding some aspects they have different design and construction prerequisites. To obtain cost efficiency, the transport distances should be kept short, and possibilities for co-ordinated networks with short distribution pipelines connected to common main pipelines, should be searched for. Also, synergies

Favourable Formations for CO{sub 2} Storage in the Almazan Basin; Formaciones Favorables para el Almacenamiento de CO{sub 2} en la Cuenca de Almazan

Energy Technology Data Exchange (ETDEWEB)

Ruiz Rivas, C.; Lomba Falcon, L.

2008-04-10

Geological storage of carbon dioxide is one of the technological options that have been considered nowadays for global climate change mitigation. Underground CO{sub 2} storage requires the selection and identification of deep geological formations which must meet criteria for health and environmental safety in the middle-term of one thousand years. Deep permeable formations, depleted oil and gas fields, unminable coal seams and saline rocks are possible geological formations for CO{sub 2} storage. Some areas in our country have been selected to search potential CO{sub 2} reservoirs. Among these areas, sedimentary basins are highlighted because of their thick stratigraphic sequences and the availability of extensive geological data which are coming from fossil fuel exploration. In this report, the identification and selection of favourable geological formations in the Almazan basin is presented. A 3D simplified subsurface basin geological model that was based on a Geographic Information System is included as well. The report also includes suitable CO{sub 2} injection areas in the surface for the selected geological formations. Finally, a preliminary CO{sub 2} storage capacity estimation of a potential structural trap has been calculated, considering only physical CO{sub 2} trapping. This work has been undertaken in the framework of the Geological CO{sub 2} Storage Project which is within the Singular Strategic Project of the Ministry of Education and Science Generation, Capture and Storage advanced technologies of CO{sub 2}. (Author) 84 refs.

Managing geological uncertainty in CO2-EOR reservoir assessments

Science.gov (United States)

Welkenhuysen, Kris; Piessens, Kris

2014-05-01

Recently the European Parliament has agreed that an atlas for the storage potential of CO2 is of high importance to have a successful commercial introduction of CCS (CO2 capture and geological storage) technology in Europe. CO2-enhanced oil recovery (CO2-EOR) is often proposed as a promising business case for CCS, and likely has a high potential in the North Sea region. Traditional economic assessments for CO2-EOR largely neglect the geological reality of reservoir uncertainties because these are difficult to introduce realistically in such calculations. There is indeed a gap between the outcome of a reservoir simulation and the input values for e.g. cost-benefit evaluations, especially where it concerns uncertainty. The approach outlined here is to turn the procedure around, and to start from which geological data is typically (or minimally) requested for an economic assessment. Thereafter it is evaluated how this data can realistically be provided by geologists and reservoir engineers. For the storage of CO2 these parameters are total and yearly CO2 injection capacity, and containment or potential on leakage. Specifically for the EOR operation, two additional parameters can be defined: the EOR ratio, or the ratio of recovered oil over injected CO2, and the CO2 recycling ratio of CO2 that is reproduced after breakthrough at the production well. A critical but typically estimated parameter for CO2-EOR projects is the EOR ratio, taken in this brief outline as an example. The EOR ratio depends mainly on local geology (e.g. injection per well), field design (e.g. number of wells), and time. Costs related to engineering can be estimated fairly good, given some uncertainty range. The problem is usually to reliably estimate the geological parameters that define the EOR ratio. Reliable data is only available from (onshore) CO2-EOR projects in the US. Published studies for the North Sea generally refer to these data in a simplified form, without uncertainty ranges, and are

A Framework to Estimate CO2 Leakage associated with Geological Storage in Mature Sedimentary Basins

Science.gov (United States)

Celia, M. A.; Bachu, S.; Gasda, S.

2002-12-01

Geological storage of carbon dioxide requires careful risk analysis to avoid unintended consequences associated with the subsurface injection. Most negative consequences of subsurface injection are associated with leakage of the injected CO2 out of the geological formation into which it is injected. Such leakage may occur through natural geological features, including fractures and faults, or it may occur through human-created pathways such as existing wells. Possible leakage of CO2 through existing wells appears to be especially important in mature sedimentary basins that have been explored intensively and exploited for hydrocarbon production. In the Alberta Basin of western Canada, more than 300,000 oil and gas wells have been drilled, while in the state of Texas in the United States, more than 1,500,000 wells have been drilled. Many of these wells have been abandoned, and the information available to describe their current state is highly variable and sometimes nonexistent. Because these wells represent possible direct conduits from the injection zone to the land surface, a comprehensive assessment of leakage potential associated with these wells needs to be pursued. Analysis of leakage potential associated with existing wells must combine a data mining component with a multi-level modeling effort to assess leakage potential in a probabilistic framework. Information available for existing wells must be categorized and analyzed, and general leakage characteristics associated with wells of varying properties must be quantified. One example of a realistic target formation is the Viking Formation in Alberta, which is overlain by a thick shale layer and contains hydrocarbon in some locations. The existence of hydrocarbon in the formation indicates that the overlying shale layer is an effective barrier to flow, and therefore this is a good candidate formation for CO2 storage. However, the formation and its cap rock are punctured by approximately 180,000 wells, with

The carbon dioxide capture and geological storage

International Nuclear Information System (INIS)

2006-06-01

This road-map proposes by the Group Total aims to inform the public on the carbon dioxide capture and geological storage. One possible means of climate change mitigation consists of storing the CO 2 generated by the greenhouse gases emission in order to stabilize atmospheric concentrations. This sheet presents the CO 2 capture from lage fossil-fueled combustion installations, the three capture techniques and the CO 2 transport options, the geological storage of the CO 2 and Total commitments in the domain. (A.L.B.)

Underground CO{sub 2} Storage: Approach for Favourable Formations in Ebro Basin; AGP de CO{sub 2}: Seleccion de Formaciones Favorables en la Cuenca del Ebro

Energy Technology Data Exchange (ETDEWEB)

Campos, R.; Perucha, A.; Recreo, F.

2008-04-10

The study of the possibilities of conducting Deep Geological CO{sub 2} Storage inside Spanish territory is being performed through the Strategic Singular Project PS-120000-2005-2 of the National Program of Energy from the Education and Science Ministry, and called CO{sub 2} generation, sequestration and storage advanced technologies, sub project N3 CO{sub 2} Geological Storage This report studies the possibilities the Ebro basin offers for definitive CO{sub 2} storage as one of the Spanish selected areas from previous studies. The study and reinterpretation of the information obtained from the hydrocarbon exploration accomplished in the area has lead to the selection of a series of geological formations. These formations have been chosen attending certain characteristics such as their disposition, extension, depth and porosity. The study has also been conducted considering the characteristics of the geological formations above the CO{sub 2} storage formations so as to guarantee the sealing of the storage. The study includes the approximate estimation of the storage capacity for each of the formations in Megatons of CO{sub 2}, which can be useful in future decision making. Deep geological storage is one of the more relevant international initiatives in order to eliminate or reduce the anthropogenic CO{sub 2} emissions to the atmosphere. (Author) 68 refs.

Measurement of residual CO2 saturation at a geological storage site using hydraulic tests

Science.gov (United States)

Rötting, T. S.; Martinez-Landa, L.; Carrera, J.; Russian, A.; Dentz, M.; Cubillo, B.

2012-12-01

Estimating long term capillary trapping of CO2 in aquifers remains a key challenge for CO2 storage. Zhang et al. (2011) proposed a combination of thermal, tracer, and hydraulic experiments to estimate the amount of CO2 trapped in the formation after a CO2 push and pull test. Of these three types of experiments, hydraulic tests are the simplest to perform and possibly the most informative. However, their potential has not yet been fully exploited. Here, a methodology is presented to interpret these tests and analyze which parameters can be estimated. Numerical and analytical solutions are used to simulate a continuous injection in a porous medium where residual CO2 has caused a reduction in hydraulic conductivity and an increase in storativity over a finite thickness (a few meters) skin around the injection well. The model results are interpreted using conventional pressure build-up and diagnostic plots (a plot of the drawdown s and the logarithmic derivative d s / d ln t of the drawdown as a function of time). The methodology is applied using the hydraulic parameters estimated for the Hontomin site (Northern Spain) where a Technology Demonstration Plant (TDP) for geological CO2 storage is planned to be set up. The reduction of hydraulic conductivity causes an increase in observed drawdowns, the increased storativity in the CO2 zone causes a delay in the drawdown curve with respect to the reference curve measured before CO2 injection. The duration (characteristic time) of these effects can be used to estimate the radius of the CO2 zone. The effects of reduced permeability and increased storativity are well separated from wellbore storage and natural formation responses, even if the CO2-brine interface is inclined (i.e. the CO2 forms a cone around the well). We find that both skin hydraulic conductivity and storativity (and thus residual CO2 saturation) can be obtained from the water injection test provided that water flow rate is carefully controlled and head build

Research Project on CO2 Geological Storage and Groundwater Resources: Water Quality Effects Caused by CO2 Intrusion into Shallow Groundwater

Energy Technology Data Exchange (ETDEWEB)

Birkholzer, Jens; Apps, John; Zheng, Liange; Zhang, Yingqi; Xu, Tianfu; Tsang, Chin-Fu

2008-10-01

One promising approach to reduce greenhouse gas emissions is injecting CO{sub 2} into suitable geologic formations, typically depleted oil/gas reservoirs or saline formations at depth larger than 800 m. Proper site selection and management of CO{sub 2} storage projects will ensure that the risks to human health and the environment are low. However, a risk remains that CO{sub 2} 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 CO{sub 2} 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 CO{sub 2}. This report describes a systematic evaluation of the possible water quality changes in response to CO{sub 2} 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 CO{sub 2} 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 CO{sub 2} intrusion into shallow aquifers (Section 4). Via reactive-transport modeling, the amount of hazardous constituents potentially mobilized by the ingress of CO{sub 2} was determined, the fate and migration of these constituents in the groundwater was predicted, and the likelihood that drinking water

Uncertainty studies and risk assessment for CO{sub 2} storage in geological formations

Energy Technology Data Exchange (ETDEWEB)

Walter, Lena Sophie

2013-07-01

Carbon capture and storage (CCS) in deep geological formations is one possible option to mitigate the greenhouse gas effect by reducing CO{sub 2} emissions into the atmosphere. The assessment of the risks related to CO{sub 2} storage is an important task. Events such as CO{sub 2} leakage and brine displacement could result in hazards for human health and the environment. In this thesis, a systematic and comprehensive risk assessment concept is presented to investigate various levels of uncertainties and to assess risks using numerical simulations. Depending on the risk and the processes, which should be assessed, very complex models, large model domains, large time scales, and many simulations runs for estimating probabilities are required. To reduce the resulting high computational costs, a model reduction technique (the arbitrary polynomial chaos expansion) and a method for model coupling in space are applied. The different levels of uncertainties are: statistical uncertainty in parameter distributions, scenario uncertainty, e.g. different geological features, and recognized ignorance due to assumptions in the conceptual model set-up. Recognized ignorance and scenario uncertainty are investigated by simulating well defined model set-ups and scenarios. According to damage values, which are defined as a model output, the set-ups and scenarios can be compared and ranked. For statistical uncertainty probabilities can be determined by running Monte Carlo simulations with the reduced model. The results are presented in various ways: e.g., mean damage, probability density function, cumulative distribution function, or an overall risk value by multiplying the damage with the probability. If the model output (damage) cannot be compared to provided criteria (e.g. water quality criteria), analytical approximations are presented to translate the damage into comparable values. The overall concept is applied for the risks related to brine displacement and infiltration into

Effects of CO{sub 2} gas as leaks from geological storage sites on agro-ecosystems

Energy Technology Data Exchange (ETDEWEB)

Patil, Ravi H.; Colls, Jeremy J. [Division of Agricultural and Environmental Sciences, School of Biosciences, University of Nottingham, NG7 2RD, Nottingham (United Kingdom); Steven, Michael D. [School of Geography, University of Nottingham, NG7 2RD, Nottingham (United Kingdom)

2010-12-15

Carbon capture and storage in geological formations has potential risks in the long-term safety because of the possibility of CO{sub 2} leakage. Effects of leaking gas, therefore, on vegetation, soil, and soil-inhabiting organisms are critical to understand. An artificial soil gassing and response detection field facility developed at the University of Nottingham was used to inject CO{sub 2} gas at a controlled flow rate (1 l min{sup -1}) into soil to simulate build-up of soil CO{sub 2} concentrations and surface fluxes from two land use types: pasture grassland, and fallow followed by winter bean. Mean soil CO{sub 2} concentrations was significantly higher in gassed pasture plots than in gassed fallow plots. Germination of winter bean sown in gassed fallow plots was severely hindered and the final crop stand was reduced to half. Pasture grass showed stress symptoms and above-ground biomass was significantly reduced compared to control plot. A negative correlation (r = -0.95) between soil CO{sub 2} and O{sub 2} concentrations indicated that injected CO{sub 2} displaced O{sub 2} from soil. Gassing CO{sub 2} reduced soil pH both in grass and fallow plots (p = 0.012). The number of earthworm castings was twice as much in gassed plots than in control plots. This study showed adverse effects of CO{sub 2} gas on agro-ecosystem in case of leakage from storage sites to surface. (author)

Integrated path towards geological storage

International Nuclear Information System (INIS)

Bouchard, R.; Delaytermoz, A.

2004-01-01

Among solutions to contribute to CO 2 emissions mitigation, sequestration is a promising path that presents the main advantage of being able to cope with the large volume at stake when considering the growing energy demand. Of particular importance, geological storage has widely been seen as an effective solution for large CO 2 sources like power plants or refineries. Many R and D projects have been initiated, whereby research institutes, government agencies and end-users achieve an effective collaboration. So far, progress has been made towards reinjection of CO 2 , in understanding and then predicting the phenomenon and fluid dynamics inside the geological target, while monitoring the expansion of the CO 2 bubble in the case of demonstration projects. A question arises however when talking about sequestration, namely the time scale to be taken into account. Time is indeed of the essence, and points out the need to understand leakage as well as trapping mechanisms. It is therefore of prime importance to be able to predict the fate of the injected fluids, in an accurate manner and over a relevant period of time. On the grounds of geology, four items are involved in geological storage reliability: the matrix itself, which is the recipient of the injected fluids; the seal, that is the mechanistic trap preventing the injected fluids to flow upward and escape; the lower part of the concerned structure, usually an aquifer, that can be a migration way for dissolved fluids; and the man- made injecting hole, the well, whose characteristics should be as good as the geological formation itself. These issues call for specific competencies such as reservoir engineering, geology and hydrodynamics, mineral chemistry, geomechanics, and well engineering. These competencies, even if put to use to a large extent in the oil industry, have never been connected with the reliability of geological storage as ultimate goal. This paper aims at providing an introduction to these

Preliminary Study of Favourable Formations for CO2 Subsurface Storage in Spain

International Nuclear Information System (INIS)

Zapatero, M. A.; Reyes, J. L.; Martinez, R.; Suarez, I.; Arenillas, A.; Perucha, M. A.

2009-01-01

This report is a synthesis of the possibilities of CO 2 storage in the Spanish subsurface. Compilation and analysis of geological information has been carried out, looking at surface and subsurface, in order to make a pre-selection of potential favourable units for CO 2 storage, taking in account that each of this storages needs a confining formation to seal the storage. Before the storage selection, a general description of the great geological units of the Iberian Peninsula is done. Afterwards, borehole logging from petroleum exploration is analysed in these units, formations and areas of interest. The aim is to finally obtain a description of selected units and their possibilities of CO 2 storage. (Author) 17 refs

Caprock and overburden processes in geological CO2 storage: An experimental study on sealing efficiency and mineral alterations

NARCIS (Netherlands)

Wollenweber, J.; Alles, S.a.; Kronimus, A.; Busch, A.; Stanjek, H.; Krooss, B.M.

2009-01-01

A comprehensive set of experimental and analytical methods has been used to characterise the sealing and fluid -transport properties of fine-grained (pelitic) sedimentary rocks under the pressure and temperature conditions of geological CO2 storage. The flow experiments were carried out on

Atmospheric and geological CO2 damage costs in energy scenarios

International Nuclear Information System (INIS)

Smekens, K.E.L.; Van der Zwaan, B.C.C.

2006-05-01

Geological carbon dioxide capture and storage (CCS) is currently seriously considered for addressing, in the near term, the problem of climate change. CCS technology is available today and is expected to become an increasingly affordable CO2 abatement alternative. Whereas the rapidly growing scientific literature on CCS as well as experimental and commercial practice demonstrate the technological and economic feasibility of implementing this clean fossil fuel option on a large scale, relatively little attention has been paid so far to the risks and environmental externalities of geological storage of CO2. This paper assesses the effects of including CCS damage costs in a long-term energy scenario analysis for Europe. An external cost sensitivity analysis is performed with a bottom-up energy technology model that accounts not only for CCS technologies but also for their external costs. Our main conclusion is that in a business-as-usual scenario (i.e. without climate change intervention or externality internalisation), CCS technologies are likely to be deployed at least to some extent, mainly in the power generation sector, given the economic benefits of opportunities such as enhanced coal bed methane, oil and gas recovery. Under a strict climate (CO2 emissions) constraint, CCS technologies are deployed massively. With the simultaneous introduction of both CO2 and CCS taxation in the power sector, designed to internalise the external atmospheric and geological effects of CO2 emissions and storage, respectively, we find that CCS will only be developed if the climate change damage costs are at least of the order of 100 euro/t CO2 or the CO2 storage damage costs not more than a few euro/t CO2. When the internalised climate change damage costs are as high as 67 euro/t CO2, the expensive application of CCS to biomass-fuelled power plants (with negative net CO2 emissions) proves the most effective CCS alternative to reduce CO2 emissions, rather than CCS applied to fossil

Industrial Analogues on CO{sub 2} Storage; Analogos Industriales del Almacenamiento de CO{sub 2}

Energy Technology Data Exchange (ETDEWEB)

Martinez, R; Campos, R; Perez del Villar, L; Suarez, I; Zapatero, M A

2008-08-06

This volume tries to introduce the study of industrial analogues of CO{sub 2} storage, those industrial activities that, because of some specific conditions, are considered similar to CO{sub 2} geological storage activities. The goal is to obtain useful conclusions for application in the incipient exploration of this type of storages. Therefore, strategic storages of natural gas have been studied, with a special emphasis in the project developed in the surroundings of Yela (Guadalajara). Other activities are also described, as some projects that include CO{sub 2} injection to increase the recovery of oil and/or gas in nearly depleted reservoirs, and also a case of CO{sub 2} storage in a saline aquifer (Salipriina). Finally, Rewopol Project methodology is summarized, as an experimental case of CO{sub 2} storage on coal, coupled with coal bed methane production. Summing up, the main goal of this work is to determine the most adequate technologies that have to be developed in a successful CO{sub 2} storage, exploration and exploitation project. (Author) 28 refs.

Methods to Assess Geological CO2 Storage Capacity: Status and Best Practice

Energy Technology Data Exchange (ETDEWEB)

NONE

2013-08-01

To understand the emission reduction potential of carbon capture and storage (CCS), decision makers need to understand the amount of CO2 that can be safely stored in the subsurface and the geographical distribution of storage resources. Estimates of storage resources need to be made using reliable and consistent methods. Previous estimates of CO2 storage potential for a range of countries and regions have been based on a variety of methodologies resulting in a correspondingly wide range of estimates. Consequently, there has been uncertainty about which of the methodologies were most appropriate in given settings, and whether the estimates produced by these methods were useful to policy makers trying to determine the appropriate role of CCS. In 2011, the IEA convened two workshops which brought together experts for six national surveys organisations to review CO2 storage assessment methodologies and make recommendations on how to harmonise CO2 storage estimates worldwide. This report presents the findings of these workshops and an internationally shared guideline for quantifying CO2 storage resources.

Clayey cap-rocks reactivity in presence of CO2 in deep geological storage conditions: experimentation/modeling integrated approach

International Nuclear Information System (INIS)

Credoz, A.

2009-10-01

CO 2 capture, transport and geological storage is one of the main solutions considered in the short and medium term to reduce CO 2 and others greenhouse gases emissions towards the atmosphere, by storing CO 2 in deeper geological reservoirs during 100 to 10 000 years. This Ph-D study offers a multi-scale vision of complex clayey cap-rocks reactivity and evolution. These formations are identified for the CO 2 containment and sealing into the reservoir. From the experimental scale on purified clay minerals to integrative modeling at high space and time scales, the strategy developed allowed identifying the main geochemical processes, to check the good agreement between experiment and modeling, and to lay emphasis the operational impacts on long-term cap-rocks integrity. Carbonated cements alteration is likely to open cap-rock porosity and to create preferential reactive pathway for reactive fluid flow. Besides, this could alter the cap-rock structure and the global geo-mechanic properties. Clay minerals alteration, including the illitization process, reduces the clay fraction volume but considerably limits the porosity increase. The illitization process in acidic conditions determined experimentally and by modeling at low and high scale, is coupled with silica precipitation. The final porosity increase control results of these two reactive processes balance. By a fundamental side, this study reveals new kinetic parameters of clay minerals and highlights new structural transformations. By an operational side, this study contributes to the acquisition of qualitative data (long-term reactive pathways of clayey cap-rocks, coupled reactivity carbonates/clays) and quantitative data (CO 2 penetration distance into the cap-rock) to partly answer to the performance and safety assessment CO 2 capture and geological storage. (author)

Influence of Chemical, Mechanical, and Transport Processes on Wellbore Leakage from Geologic CO2 Storage Reservoirs.

Science.gov (United States)

Carroll, Susan A; Iyer, Jaisree; Walsh, Stuart D C

2017-08-15

Wells are considered to be high-risk pathways for fluid leakage from geologic CO 2 storage reservoirs, because breaches in this engineered system have the potential to connect the reservoir to groundwater resources and the atmosphere. Given these concerns, a few studies have assessed leakage risk by evaluating regulatory records, often self-reported, documenting leakage in gas fields. Leakage is thought to be governed largely by initial well-construction quality and the method of well abandonment. The geologic carbon storage community has raised further concerns because acidic fluids in the CO 2 storage reservoir, alkaline cement meant to isolate the reservoir fluids from the overlying strata, and steel casings in wells are inherently reactive systems. This is of particular concern for storage of CO 2 in depleted oil and gas reservoirs with numerous legacy wells engineered to variable standards. Research suggests that leakage risks are not as great as initially perceived because chemical and mechanical alteration of cement has the capacity to seal damaged zones. Our work centers on defining the coupled chemical and mechanical processes governing flow in damaged zones in wells. We have developed process-based models, constrained by experiments, to better understand and forecast leakage risk. Leakage pathways can be sealed by precipitation of carbonate minerals in the fractures and deformation of the reacted cement. High reactivity of cement hydroxides releases excess calcium that can precipitate as carbonate solids in the fracture network under low brine flow rates. If the flow is fast, then the brine remains undersaturated with respect to the solubility of calcium carbonate minerals, and zones depleted in calcium hydroxides, enriched in calcium carbonate precipitates, and made of amorphous silicates leached of original cement minerals are formed. Under confining pressure, the reacted cement is compressed, which reduces permeability and lowers leakage risks. The

The integrated CO{sub 2} pilot in the SW of France (oxycombustion and geological storage) : a potential answer to CO{sub 2} mitigation in bitumen production

Energy Technology Data Exchange (ETDEWEB)

Aimard, N.; Prebende, C. [Total, Pau (France); Cieutat, D.; Sanchez-Molinero, I.; Tsiava, R. [Air Liquide, Jouy-en-Josas (France)

2008-10-15

Carbon capture and storage technologies are promising options in the reduction of greenhouse gas emissions in extra heavy oil production fields. The research centre at Total launched an integrated carbon capture and storage project at Lacq in the southwest of France. It involves the conversion of a steam boiler into an oxy-fuel combustion unit. The pilot plant is expected to emit up to 120,000 tons of carbon dioxide (CO{sub 2}) over a 2-year period. The CO{sub 2} rich flue gas will be cleaned up and compressed and the resulting CO{sub 2} will be conveyed via pipeline to a depleted gas field, where it will be injected into a deep carbonate reservoir. This paper demonstrated that oxycombustion could have some advantages compared to post-combustion for CO{sub 2} capture in terms of energy efficiency for steam generation. It discussed a pilot plant whose objectives were to demonstrate the technical feasibility and reliability of an integrated scheme for steam production including CO{sub 2} capture, transportation, injection and storage, at a reduced scale, typically one tenth of future larger scale facilities. This paper also described how to develop and apply geological storage qualification methodologies, monitoring and verification techniques in a real operational situation to prepare future larger scale long term storage projects. It also presented the characteristics of one of the world's first industrial oxy-combustion units, the 30MWth oxy-gas boiler. It was concluded that the Lacq CO{sub 2} pilot project is a unique challenging project as it integrates both industrial CO{sub 2} capture facilities within an existing gas treatment complex with CO{sub 2} compression, transportation, injection and storage into an onshore gas depleted reservoir. 5 refs., 3 tabs., 9 figs.

CO2 point sources and subsurface storage capacities for CO2 in aquifers in Norway

International Nuclear Information System (INIS)

Boee, Reidulv; Magnus, Christian; Osmundsen, Per Terje; Rindstad, Bjoern Ivar

2002-01-01

The GESTCO project comprises a study of the distribution and coincidence of thermal CO 2 emission sources and location/quality of geological storage capacity in Europe. Four of the most promising types of geological storage are being studied. 1. Onshore/offshore saline aquifers with or without lateral seal. 2. Low entalpy geothermal reservoirs. 3. Deep methane-bearing coal beds and abandoned coal and salt mines. 4. Exhausted or near exhausted hydrocarbon structures. In this report we present an inventory of CO 2 point sources in Norway (1999) and the results of the work within Study Area C: Deep saline aquifers offshore/near shore Northern and Central Norway. Also offshore/near shore Southern Norway has been included while the Barents Sea is not described in any detail. The most detailed studies are on the Tilje and Aare Formations on the Troendelag Platform off Mid-Norway and on the Sognefjord, Fensfjord and Krossfjord Formations, southeast of the Troll Field off Western Norway. The Tilje Formation has been chosen as one of the cases to be studied in greater detail (numerical modelling) in the project. This report shows that offshore Norway, there are concentrations of large CO 2 point sources in the Haltenbanken, the Viking Graben/Tampen Spur area, the Southern Viking Graben and the central Trough, while onshore Norway there are concentrations of point sources in the Oslofjord/Porsgrund area, along the coast of western Norway and in the Troendelag. A number of aquifers with large theoretical CO 2 storage potential are pointed out in the North Sea, the Norwegian Sea and in the Southern Barents Sea. The storage capacity in the depth interval 0.8 - 4 km below sea level is estimated to be ca. 13 Gt (13000000000 tonnes) CO 2 in geological traps (outside hydrocarbon fields), while the storage capacity in aquifers not confined to traps is estimated to be at least 280 Gt CO 2 . (Author)

Noble gas geochemistry to monitor CO{sub 2} geological storages; Apports de la geochimie des gaz rares a la surveillance des sites de sequestration geologique de CO{sub 2}

Energy Technology Data Exchange (ETDEWEB)

Lafortune, St

2007-11-15

According to the last IPCC (Intergovernmental Panel on Climate Change) report, a probability of 90 % can be now established for the responsibility of the anthropogenic CO{sub 2} emissions for the global climate change observed since the beginning of the 20. century. To reduce these emissions and keep producing energy from coal, oil or gas combustions, CO{sub 2} could be stored in geological reservoirs like aquifers, coal beds, and depleted oil or gas fields. Storing CO{sub 2} in geological formations implies to control the efficiency and to survey the integrity of the storages, in order to be able to detect the possible leaks as fast as possible. Here, we study the feasibility of a geochemical monitoring through noble gas geochemistry. We present (1) the development of a new analytical line, Garodiox, developed to extract quantitatively noble gas from water samples, (2) the testing of Garodiox on samples from a natural CO{sub 2} storage analogue (Pavin lake, France) and (3) the results of a first field work on a natural CO{sub 2} accumulation (Montmiral, France). The results we obtain and the conclusions we draw, highlight the interest of the geochemical monitoring we suggest. (author)

Cost Implications of Uncertainty in CO{sub 2} Storage Resource Estimates: A Review

Energy Technology Data Exchange (ETDEWEB)

Anderson, Steven T., E-mail: sanderson@usgs.gov [National Center, U.S. Geological Survey (United States)

2017-04-15

Carbon capture from stationary sources and geologic storage of carbon dioxide (CO{sub 2}) is an important option to include in strategies to mitigate greenhouse gas emissions. However, the potential costs of commercial-scale CO{sub 2} storage are not well constrained, stemming from the inherent uncertainty in storage resource estimates coupled with a lack of detailed estimates of the infrastructure needed to access those resources. Storage resource estimates are highly dependent on storage efficiency values or storage coefficients, which are calculated based on ranges of uncertain geological and physical reservoir parameters. If dynamic factors (such as variability in storage efficiencies, pressure interference, and acceptable injection rates over time), reservoir pressure limitations, boundaries on migration of CO{sub 2}, consideration of closed or semi-closed saline reservoir systems, and other possible constraints on the technically accessible CO{sub 2} storage resource (TASR) are accounted for, it is likely that only a fraction of the TASR could be available without incurring significant additional costs. Although storage resource estimates typically assume that any issues with pressure buildup due to CO{sub 2} injection will be mitigated by reservoir pressure management, estimates of the costs of CO{sub 2} storage generally do not include the costs of active pressure management. Production of saline waters (brines) could be essential to increasing the dynamic storage capacity of most reservoirs, but including the costs of this critical method of reservoir pressure management could increase current estimates of the costs of CO{sub 2} storage by two times, or more. Even without considering the implications for reservoir pressure management, geologic uncertainty can significantly impact CO{sub 2} storage capacities and costs, and contribute to uncertainty in carbon capture and storage (CCS) systems. Given the current state of available information and the

Influence of methane in CO2 transport and storage for CCS technology.

Science.gov (United States)

Blanco, Sofía T; Rivas, Clara; Fernández, Javier; Artal, Manuela; Velasco, Inmaculada

2012-12-04

CO(2) Capture and Storage (CCS) is a good strategy to mitigate levels of atmospheric greenhouse gases. The type and quantity of impurities influence the properties and behavior of the anthropogenic CO(2), and so must be considered in the design and operation of CCS technology facilities. Their study is necessary for CO(2) transport and storage, and to develop theoretical models for specific engineering applications to CCS technology. In this work we determined the influence of CH(4), an important impurity of anthropogenic CO(2), within different steps of CCS technology: transport, injection, and geological storage. For this, we obtained new pressure-density-temperature (PρT) and vapor-liquid equilibrium (VLE) experimental data for six CO(2) + CH(4) mixtures at compositions which represent emissions from the main sources in the European Union and United States. The P and T ranges studied are within those estimated for CO(2) pipelines and geological storage sites. From these data we evaluated the minimal pressures for transport, regarding the density and pipeline's capacity requirements, and values for the solubility parameter of the mixtures, a factor which governs the solubility of substances present in the reservoir before injection. We concluded that the presence of CH(4) reduces the storage capacity and increases the buoyancy of the CO(2) plume, which diminishes the efficiency of solubility and residual trapping of CO(2), and reduces the injectivity into geological formations.

A workflow for handling heterogeneous 3D models with the TOUGH2 family of codes: Applications to numerical modeling of CO 2 geological storage

Science.gov (United States)

Audigane, Pascal; Chiaberge, Christophe; Mathurin, Frédéric; Lions, Julie; Picot-Colbeaux, Géraldine

2011-04-01

This paper is addressed to the TOUGH2 user community. It presents a new tool for handling simulations run with the TOUGH2 code with specific application to CO 2 geological storage. This tool is composed of separate FORTRAN subroutines (or modules) that can be run independently, using input and output files in ASCII format for TOUGH2. These modules have been developed specifically for modeling of carbon dioxide geological storage and their use with TOUGH2 and the Equation of State module ECO2N, dedicated to CO 2-water-salt mixture systems, with TOUGHREACT, which is an adaptation of TOUGH2 with ECO2N and geochemical fluid-rock interactions, and with TOUGH2 and the EOS7C module dedicated to CO 2-CH 4 gas mixture is described. The objective is to save time for the pre-processing, execution and visualization of complex geometry for geological system representation. The workflow is rapid and user-friendly and future implementation to other TOUGH2 EOS modules for other contexts (e.g. nuclear waste disposal, geothermal production) is straightforward. Three examples are shown for validation: (i) leakage of CO 2 up through an abandoned well; (ii) 3D reactive transport modeling of CO 2 in a sandy aquifer formation in the Sleipner gas Field, (North Sea, Norway); and (iii) an estimation of enhanced gas recovery technology using CO 2 as the injected and stored gas to produce methane in the K12B Gas Field (North Sea, Denmark).

Modeling of CO2 storage in aquifers

International Nuclear Information System (INIS)

Savioli, Gabriela B; Santos, Juan E

2011-01-01

Storage of CO 2 in geological formations is a means of mitigating the greenhouse effect. Saline aquifers are a good alternative as storage sites due to their large volume and their common occurrence in nature. The first commercial CO 2 injection project is that of the Sleipner field in the Utsira Sand aquifer (North Sea). Nevertheless, very little was known about the effectiveness of CO 2 sequestration over very long periods of time. In this way, numerical modeling of CO 2 injection and seismic monitoring is an important tool to understand the behavior of CO 2 after injection and to make long term predictions in order to prevent CO 2 leaks from the storage into the atmosphere. The description of CO 2 injection into subsurface formations requires an accurate fluid-flow model. To simulate the simultaneous flow of brine and CO 2 we apply the Black-Oil formulation for two phase flow in porous media, which uses the PVT data as a simplified thermodynamic model. Seismic monitoring is modeled using Biot's equations of motion describing wave propagation in fluid-saturated poroviscoelastic solids. Numerical examples of CO 2 injection and time-lapse seismics using data of the Utsira formation show the capability of this methodology to monitor the migration and dispersal of CO 2 after injection.

Crucial thermophysical mechanisms for the safety of CO{sub 2} geological storage; Mecanismes thermophysiques determinant la securite du stockage geologique du CO{sub 2}

Energy Technology Data Exchange (ETDEWEB)

Chiquet, P

2006-09-15

CO{sub 2} underground storage as an option for reducing greenhouse gases emissions consists of trapping industrial CO{sub 2} and injecting it into deep geological formations such as saline aquifers and hydrocarbons reservoirs. This study aims at assessing leakage processes and evaluating storage capacities. To this end, two leakage phenomena were considered, cap-rock capillary breakthrough and diffusional transport. The former involves interfacial properties of the brine/CO{sub 2}/mineral system: brine/CO{sub 2} interfacial tension and rock wettability under dense CO{sub 2}. Chapter one presents a series of IFT measurements performed at temperatures and pressures up to 4 5 MPa-110 C. Results show a great decrease of IFT with pressure in the 0-to-20 MPa range beyond what it tends to stabilize at values in the order of 25-30 mN.m{sup -1}. Chapter two deals with rock wettability. Dynamic contact angles were measured on muscovite mica and quartz up to 10 MPa. Results highlight an alteration of wettability with pressure that was accounted for by means of a DLVO based model. Direct capillary entry pressures on a clay stone sample are proposed in chapter three. Diffusion, is treated in chapter four. We used the Taylor dispersion method to measure D up to 40 MPa. Results indicate low values in the order of 2.10{sup -9} m{sup 2}.s{sup -1}. Chapter five discusses the consequences of the previous parameters in terms of storage capacity. (author)

Effect of Mineral Dissolution/Precipitation and CO2 Exsolution on CO2 transport in Geological Carbon Storage.

Science.gov (United States)

Xu, Ruina; Li, Rong; Ma, Jin; He, Di; Jiang, Peixue

2017-09-19

Geological carbon sequestration (GCS) in deep saline aquifers is an effective means for storing carbon dioxide to address global climate change. As the time after injection increases, the safety of storage increases as the CO 2 transforms from a separate phase to CO 2 (aq) and HCO 3 - by dissolution and then to carbonates by mineral dissolution. However, subsequent depressurization could lead to dissolved CO 2 (aq) escaping from the formation water and creating a new separate phase which may reduce the GCS system safety. The mineral dissolution and the CO 2 exsolution and mineral precipitation during depressurization change the morphology, porosity, and permeability of the porous rock medium, which then affects the two-phase flow of the CO 2 and formation water. A better understanding of these effects on the CO 2 -water two-phase flow will improve predictions of the long-term CO 2 storage reliability, especially the impact of depressurization on the long-term stability. In this Account, we summarize our recent work on the effect of CO 2 exsolution and mineral dissolution/precipitation on CO 2 transport in GCS reservoirs. We place emphasis on understanding the behavior and transformation of the carbon components in the reservoir, including CO 2 (sc/g), CO 2 (aq), HCO 3 - , and carbonate minerals (calcite and dolomite), highlight their transport and mobility by coupled geochemical and two-phase flow processes, and consider the implications of these transport mechanisms on estimates of the long-term safety of GCS. We describe experimental and numerical pore- and core-scale methods used in our lab in conjunction with industrial and international partners to investigate these effects. Experimental results show how mineral dissolution affects permeability, capillary pressure, and relative permeability, which are important phenomena affecting the input parameters for reservoir flow modeling. The porosity and the absolute permeability increase when CO 2 dissolved water is

Screening of prospective sites for geological storage of CO{sub 2} in the Southern Baltic Sea

Energy Technology Data Exchange (ETDEWEB)

Vernon, R.; O' Neil, N.; Pasquali, R. [SLR Consulting, Dublin (Ireland); Nieminen, M.

2013-05-15

The BASTOR project focuses on identifying and characterising potential sites for CO{sub 2} storage in the southern Baltic Sea region. A compilation of available digital data from well logs, seismic line data interpretations, mapped structure outlines and published material from existing hydrocarbon fields and identified and mapped structures from Sweden, Poland, Latvia, Lithuania and Kaliningrad have been incorporated into a regional GIS for the Baltic Sea region. A detailed screening of regional sedimentary basins identified the Slupsk Border Zone as having suitable structures for storage of CO{sub 2} in depleted oil and gas fields or saline aquifers. Cambrian sandstone saline aquifers below 900 m have been identified as the principal regional potential storage target with the Dalders Monocline as the most promising area. Eight individual structures were identified as having greatest potential. Detailed 3D geological static models were developed for three of these structures located in offshore Latvia (E6 and E7) and one cross-border structure (Dalders Structure). A theoretical regional CO{sub 2} storage capacity calculation based on the GeoCapacity methodology was undertaken. A regional storage capacity for Cambrian sandstones below 900 m was estimated at a total of 16 Gt, with 2 Gt for the Dalders Monocline. Theoretical storage estimates for individual structures for the Baltic Sea regions includes 760 Mt for the Latvian structures and the Dalders Structure, 9.1 Mt for the structures located in Poland, 31 Mt in Lithuania and 170 Mt in Kaliningrad. These estimates are based on the best available data at the time of writing. However these estimates will be improved upon as new data becomes available from other sources. (orig.)

Assessing reservoir performance risk in CO2 storage projects

International Nuclear Information System (INIS)

Bowden, A.R.; Rigg, A.

2005-01-01

One of the main issues for researchers involved with geological storage of carbon dioxide (CO 2 ) has been the development of a proper methodology to assess and compare alternative CO 2 injection projects on the basis of risk. Consideration needs to be given to technical aspects, such as the risk of leakage and the effectiveness of the intended reservoir, as well as less tangible aspects such as the value and safety of geological storage of CO 2 , and potential impacts on the community and environment. The Geological Disposal of Carbon Dioxide (GEODISC), was a research program of the Australian Petroleum Cooperative Research Centre which identified 56 potential environmentally sustainable sites for CO 2 injection (ESSCIs) within Australia. Several studies were carried out, involving detailed evaluation of the suitability of 4 selected sites, including Dongara, Petrel, Gippsland and Carnarvon. The GEODISC program included a risk assessment research module which required a complete and quantified risk assessment of CO 2 injection as a storage option. Primary goals were to assess the risk of leakage, to assess the effectiveness of the intended reservoir, and to assess negative consequences to facilitate comparison of alternative sites. This paper discussed the background and risk assessment model. Key performance indicators (KPIs) were also developed to address the purpose of risk assessment. It was concluded that the RISQUE method is an appropriate approach and that potential injection projects can be measured against six KPIs including containment; effectiveness; self-funding potential; wider community benefits; community safety and community amenity. 6 refs., 3 tabs., 3 figs

Monitoring of injected CO2 at two commercial geologic storage sites with significant pressure depletion and/or re-pressurization histories: A case study

Directory of Open Access Journals (Sweden)

Dayanand Saini

2017-03-01

The monitoring technologies that have been used/deployed/tested at both the normally pressured West Hastings and the subnormally pressured Bell Creek storage sites appear to adequately address any of the potential “out of zone migration” of injected CO2 at these sites. It would be interesting to see if any of the collected monitoring data at the West Hastings and the Bell Creek storage sites could also be used in future to better understand the viability of initially subnormally pressured and subsequently depleted and re-pressurized oil fields as secure geologic CO2 storage sites with relatively large storage CO2 capacities compared to the depleted and re-pressurized oil fields that were initially discovered as normally pressured.

Increasing CO2 storage in oil recovery

International Nuclear Information System (INIS)

Jessen, K.; Kovscek, A.R.; Orr, F.M. Jr.

2005-01-01

Oil fields offer a significant potential for storing CO 2 and will most likely be the first large scale geological targets for sequestration as the infrastructure, experience and permitting procedures already exist. The problem of co-optimizing oil production and CO 2 storage differs significantly from current gas injection practice due to the cost-benefit imbalance resulting from buying CO 2 for enhanced oil recovery projects. Consequently, operators aim to minimize the amount of CO 2 required to sweep an oil reservoir. For sequestration purposes, where high availability of low cost CO 2 is assumed, the design parameters of enhanced oil recovery processes must be re-defined to optimize the amount of CO 2 left in the reservoir at the time of abandonment. To redefine properly the design parameters, thorough insight into the mechanisms controlling the pore scale displacement efficiency and the overall sweep efficiency is essential. We demonstrate by calculation examples the different mechanisms controlling the displacement behavior of CO 2 sequestration schemes, the interaction between flow and phase equilibrium and how proper design of the injection gas composition and well completion are required to co-optimize oil production and CO 2 storage. [Author

Increasing CO2 storage in oil recovery

International Nuclear Information System (INIS)

Jessen, Kristian; Kovscek, Anthony R.; Orr, Franklin M.

2005-01-01

Oil fields offer a significant potential for storing CO 2 and will most likely be the first large scale geological targets for sequestration as the infrastructure, experience and permitting procedures already exist. The problem of co-optimizing oil production and CO 2 storage differs significantly from current gas injection practice due to the cost-benefit imbalance resulting from buying CO 2 for enhanced oil recovery projects. Consequently, operators aim to minimize the amount of CO 2 required to sweep an oil reservoir. For sequestration purposes, where high availability of low cost CO 2 is assumed, the design parameters of enhanced oil recovery processes must be re-defined to optimize the amount of CO 2 left in the reservoir at the time of abandonment. To redefine properly the design parameters, thorough insight into the mechanisms controlling the pore scale displacement efficiency and the overall sweep efficiency is essential. We demonstrate by calculation examples the different mechanisms controlling the displacement behavior of CO 2 sequestration schemes, the interaction between flow and phase equilibrium and how proper design of the injection gas composition and well completion are required to co-optimize oil production and CO 2 storage

Comparison of monitoring technologies for CO2 storage and radioactive waste disposal

International Nuclear Information System (INIS)

Ryu, Jihun; Koh, Yongkwon; Choi, Jongwon; Lee, Jongyoul

2013-01-01

The monitoring techniques used in radioactive waste disposal have fundamentals of geology, hydrogeology, geochemistry etc, which could be applied to CO 2 sequestration. Large and diverse tools are available to monitoring methods for radioactive waste and CO 2 storage. They have fundamentals on geophysical and geochemical principles. Many techniques are well established while others are both novel and at an early stage of development. Reliable and cost-effective monitoring will be an important part of making geologic sequestration a safe, effective and acceptable method for radioactive waste disposal and CO 2 storage. In study, we discuss the monitoring techniques and the role of these techniques in providing insight in the risks of radioactive waste disposal and CO 2 sequestration

Geologic Carbon Sequestration: Mitigating Climate Change by Injecting CO2 Underground (LBNL Summer Lecture Series)

Energy Technology Data Exchange (ETDEWEB)

Oldenburg, Curtis M. [Lawrence Berkeley National Lab. (LBNL), Berkeley, CA (United States). Earth Sciences Division

2009-07-21

Summer Lecture Series 2009: Climate change provides strong motivation to reduce CO2 emissions from the burning of fossil fuels. Carbon dioxide capture and storage involves the capture, compression, and transport of CO2 to geologically favorable areas, where its injected into porous rock more than one kilometer underground for permanent storage. Oldenburg, who heads Berkeley Labs Geologic Carbon Sequestration Program, will focus on the challenges, opportunities, and research needs of this innovative technology.

Optimizing and Quantifying CO₂ Storage Resource in Saline Formations and Hydrocarbon Reservoirs

Energy Technology Data Exchange (ETDEWEB)

Bosshart, Nicholas W. [Univ. of North Dakota, Grand Folks, ND (United States). Energy & Environmental Research Center; Ayash, Scott C. [Univ. of North Dakota, Grand Folks, ND (United States). Energy & Environmental Research Center; Azzolina, Nicholas A. [Univ. of North Dakota, Grand Folks, ND (United States). Energy & Environmental Research Center; Peck, Wesley D. [Univ. of North Dakota, Grand Folks, ND (United States). Energy & Environmental Research Center; Gorecki, Charles D. [Univ. of North Dakota, Grand Folks, ND (United States). Energy & Environmental Research Center; Ge, Jun [Univ. of North Dakota, Grand Folks, ND (United States). Energy & Environmental Research Center; Jiang, Tao [Univ. of North Dakota, Grand Folks, ND (United States). Energy & Environmental Research Center; Burton-Kelly, Matthew E. [Univ. of North Dakota, Grand Folks, ND (United States). Energy & Environmental Research Center; Anderson, Parker W. [Univ. of North Dakota, Grand Folks, ND (United States). Energy & Environmental Research Center; Dotzenrod, Neil W. [Univ. of North Dakota, Grand Folks, ND (United States). Energy & Environmental Research Center; Gorz, Andrew J. [Univ. of North Dakota, Grand Folks, ND (United States). Energy & Environmental Research Center

2017-06-30

In an effort to reduce carbon dioxide (CO₂) emissions from large stationary sources, carbon capture and storage (CCS) is being investigated as one approach. This work assesses CO₂ storage resource estimation methods for deep saline formations (DSFs) and hydrocarbon reservoirs undergoing CO₂ enhanced oil recovery (EOR). Project activities were conducted using geologic modeling and simulation to investigate CO₂ storage efficiency. CO₂ storage rates and efficiencies in DSFs classified by interpreted depositional environment were evaluated at the regional scale over a 100-year time frame. A focus was placed on developing results applicable to future widespread commercial-scale CO₂ storage operations in which an array of injection wells may be used to optimize storage in saline formations. The results of this work suggest future investigations of prospective storage resource in closed or semiclosed formations need not have a detailed understanding of the depositional environment of the reservoir to generate meaningful estimates. However, the results of this work also illustrate the relative importance of depositional environment, formation depth, structural geometry, and boundary conditions on the rate of CO₂ storage in these types of systems. CO₂ EOR occupies an important place in the realm of geologic storage of CO₂, as it is likely to be the primary means of geologic CO₂ storage during the early stages of commercial implementation, given the lack of a national policy and the viability of the current business case. This work estimates CO₂ storage efficiency factors using a unique industry database of CO₂ EOR sites and 18 different reservoir simulation models capturing fluvial clastic and shallow shelf carbonate depositional environments for reservoir depths of 1219 and 2438 meters (4000 and 8000 feet) and 7.6-, 20-, and 64-meter (25-, 66

A laboratory study of supercritical CO2 adsorption on cap rocks in the geological storage conditions

Science.gov (United States)

Jedli, Hedi; Jbara, Abdessalem; Hedfi, Hachem; Bouzgarrou, Souhail; Slimi, Khalifa

2017-04-01

In the present study, various cap rocks have been experimentally reacted in water with supercritical CO2 in geological storage conditions ( P = 8 × 106 Pa and T = 80 °C) for 25 days. To characterize the potential CO2-water-rock interactions, an experimental setup has been built to provide additional information concerning the effects of structure, thermal and surface characteristics changes due to CO2 injection with cap rocks. In addition, CO2 adsorption capacities of different materials (i.e., clay evaporate and sandstone) are measured. These samples were characterized by XRD technique. The BET specific surface area was determined by nitrogen isotherms. In addition, thermal characteristics of untreated adsorbents were analyzed via TGA method and topography surfaces are identified by Scanning Electron Microscope (SEM). Taking into account pressure and temperature, the physical as well as chemical mechanisms of CO2 retention were determined. Isotherm change profiles of samples for relative pressure range indicate clearly that CO2 was adsorbed in different quantities. In accordance with the X-ray diffraction, a crystalline phase was formed due to the carbonic acid attack and precipitation of some carbonate.

Assessing reservoir performance risk in CO{sub 2} storage projects

Energy Technology Data Exchange (ETDEWEB)

Bowden, A.R. [URS Corp., San Francisco, CA (United States); Rigg, A. [CRC for Greenhouse Gas Technologies, Canberra (Australia)

2005-07-01

One of the main issues for researchers involved with geological storage of carbon dioxide (CO{sub 2}) has been the development of a proper methodology to assess and compare alternative CO{sub 2} injection projects on the basis of risk. Consideration needs to be given to technical aspects, such as the risk of leakage and the effectiveness of the intended reservoir, as well as less tangible aspects such as the value and safety of geological storage of CO{sub 2}, and potential impacts on the community and environment. The Geological Disposal of Carbon Dioxide (GEODISC), was a research program of the Australian Petroleum Cooperative Research Centre which identified 56 potential environmentally sustainable sites for CO{sub 2} injection (ESSCIs) within Australia. Several studies were carried out, involving detailed evaluation of the suitability of 4 selected sites, including Dongara, Petrel, Gippsland and Carnarvon. The GEODISC program included a risk assessment research module which required a complete and quantified risk assessment of CO{sub 2} injection as a storage option. Primary goals were to assess the risk of leakage, to assess the effectiveness of the intended reservoir, and to assess negative consequences to facilitate comparison of alternative sites. This paper discussed the background and risk assessment model. Key performance indicators (KPIs) were also developed to address the purpose of risk assessment. It was concluded that the RISQUE method is an appropriate approach and that potential injection projects can be measured against six KPIs including containment; effectiveness; self-funding potential; wider community benefits; community safety and community amenity. 6 refs., 3 tabs., 3 figs.

Risk assessment-led characterisation of the SiteChar UK north sea site for the geological storage of CO2

International Nuclear Information System (INIS)

Akhurst, Maxine; Hannis, Sarah D.; Quinn, Martyn F.; Long, David; Shi, Ji-Quan; Koenen, Marielle; Pluymaekers, Maarten; Delprat-Jannaud, Florence; Lecomte, Jean-Claude; Bossie-Codreanu, Daniel; Nagy, Stanislaw; Klimkowski, Lukas; Gei, Davide

2015-01-01

Risk assessment-led characterisation of a site for the geological storage of CO 2 in the UK northern North Sea was performed for the EU SiteChar research project as one of a portfolio of sites. Implementation and testing of the SiteChar project site characterisation work-flow has produced a 'dry-run' storage permit application that is compliant with regulatory requirements. A site suitable for commercial-scale storage was characterised, compatible with current and future industrial carbon dioxide (CO 2 ) sources in the northern UK. Pre-characterisation of the site, based on existing information acquired during hydrocarbon exploration and production, has been achieved from publicly available data. The project concept is to store captured CO 2 at a rate of 5 Mt per year for 20 years in the Blake Oil Field and surrounding Captain Sandstone saline aquifer. This commercial-scale storage of 100 Mt CO 2 can be achieved through a storage scenario combining injection of CO 2 into the oil field and concurrent water production down-dip of the field. There would be no encroachment of supercritical phase CO 2 for more than two kilometres beyond the field boundary and no adverse influence on operating hydrocarbon fields provided there is pressure management. Components of a storage permit application for the site are presented, developed as far as possible within a research project. Characterisation and technical investigations were guided by an initial assessment of perceived risks to the prospective site and a need to provide the information required for the storage permit application. The emphasis throughout was to reduce risks and uncertainty on the subsurface containment of stored CO 2 , particularly with respect to site technical performance, monitoring and regulatory issues, and effects on other resources. The results of selected risk assessment-led site characterisation investigations and the subsequent risk reassessments are described together with their

Opportunities for low-cost CO2 storage demonstration projects in China

International Nuclear Information System (INIS)

Meng, Kyle C.; Williams, Robert H.; Celia, Michael A.

2007-01-01

Several CO 2 storage demonstration projects are needed in a variety of geological formations worldwide to prove the viability of CO 2 capture and storage as a major option for climate change mitigation. China has several low-cost CO 2 sources at sites that produce NH 3 from coal via gasification. At these plants, CO 2 generated in excess of the amount needed for other purposes (e.g., urea synthesis) is vented as a relatively pure stream. These CO 2 sources would potentially be economically interesting candidates for storage demonstration projects if there are suitable storage sites nearby. In this study a survey was conducted to estimate CO 2 availability at modern Chinese coal-fed ammonia plants. Results indicate that annual quantities of available, relatively pure CO 2 per site range from 0.6 to 1.1 million tonnes. The CO 2 source assessment was complemented by analysis of possible nearby opportunities for CO 2 storage. CO 2 sources were mapped in relation to China's petroliferous sedimentary basins where prospective CO 2 storage reservoirs possibly exist. Four promising pairs of sources and sinks were identified. Project costs for storage in deep saline aquifers were estimated for each pairing ranging from $15-21/t of CO 2 . Potential enhanced oil recovery and enhanced coal bed methane recovery opportunities near each prospective source were also considered

Estimation of geological storage capacity of CO{sub 2}: Methodology and implementation to the Duero basin (Central East Area); Estimacion de la Capacidad de Almacenamiento Geologico de CO{sub 2}: Metodologia y Aplicacion a la Cuenca del Duero (Zona Centro-Oriental)

Energy Technology Data Exchange (ETDEWEB)

Hurtado, A.; Eguilior, S.

2008-08-06

This paper presents the methodology for assessment of the storage capacity into a saline aquifer depth and the results of the studies carried out in the central east area of the Duero Basin. The extension of the study area represents about 40% of the basin. This methodology has been conducted under the need of estimate of uncertainty in everything related to behavior of long-term stored CO{sub 2} in geological formations because one of the major challenges associated with this activity is ensuring the retention of stored CO{sub 2} along the period of the required time. The method is based on the implementation of a Geographic Information System as a tool for capture, storage, management and presentation of data in maps, as well as a tool for analysis and modelling through its link to both geostatistical methods and description of CO{sub 2} thermodynamic behaviour in deep geological storage conditions, by using real gases Equations of States, specially the Sterner-Pitzer Cubic Equation of State. All these analyses are accompanied by the error propagation due to the calculations required for the determination of the volume of rock, the vertical accuracy of the topographic layers, as well as other uncertainties associated with the variables required for the characterization of the CO{sub 2} in the storage conditions. The conclusion is that the deep geologic CO{sub 2} storage capacity in the study area is between 1,667 and 11,976 Mt, i.e. between 11 and 81 years of storage capacity with a current spanish CO{sub 2} production of 148 Mt/year. (Author) 40 refs.

Potential hazards of CO2 leakage in storage systems : learning from natural systems

International Nuclear Information System (INIS)

Beaubien, S.E.; Lombardi, S.; Ciotoli, G.; Annunziatellis, A.; Hatziyannis, G.; Metaxas, A.; Pearce, J.M.

2005-01-01

The Natural Analogues for the Storage of CO2 in the Geological Environment (NASCENT) Project has examined several naturally occurring carbon dioxide (CO 2 ) deposits throughout Europe to better understand the possible long term geological effects of a man-made CO 2 storage reservoir. Natural geological accumulations of CO 2 also occur widely throughout the world, some of which leak CO 2 to the surface, while others are effectively sealed. It is important to understanding the characteristics of both types of deposits in order to select and design underground storage sites for CO 2 storage. Four naturally occurring CO 2 sites were reviewed in this paper with reference to issues related to risk assessment, such as migration pathways; the speed of migration and mass flux rates; changes in groundwater chemistry; and, the effects these emissions may have on local populations and ecosystems. One site was located in northern Greece, near the Florina CO 2 gas field. The other three sites were in central Italy, including a selected area of the Latera geothermal complex, where natural deep CO 2 migrates upwards along faults and is emitted to the atmosphere; the San Vittorino intermontane basin where CO 2 -charged groundwaters cause the dissolution of limestone to form large sinkholes; and, the Ciampino area southeast of Rome, where CO 2 from deep-seated volcanism migrates along faults in a residential area. Work performed on these sites included soil gas, CO 2 flux and aqueous geochemical surveys. A GIS based model was also developed for the Latera site to assesses the risk of deep gas migration to surface. It was emphasized that these 4 sites are extreme cases compared to a man-made CO 2 geological storage site. For example all sites have an essentially infinite supply of deep CO 2 as the result of the thermo-metamorphic reactions forming this gas, whereas a man-made storage site would have a finite volume of gas which would be limited in its mass transfer out of the

Interfacial Interactions and Wettability Evaluation of Rock Surfaces for CO2 Storage

NARCIS (Netherlands)

Shojai Kaveh, N.

2014-01-01

To reduce CO2 emissions into the atmosphere, different scenarios are proposed to capture and store carbon dioxide (CO2) in geological formations (CCS). Storage strategies include CO2 injection into deep saline aquifers, depleted gas and oil reservoirs, and unmineable coal seams. To identify a secure

Rocky Mountain Regional CO{sub 2} Storage Capacity and Significance

Energy Technology Data Exchange (ETDEWEB)

Laes, Denise; Eisinger, Chris; Esser, Richard; Morgan, Craig; Rauzi, Steve; Scholle, Dana; Matthews, Vince; McPherson, Brian

2013-08-30

The purpose of this study includes extensive characterization of the most promising geologic CO{sub 2} storage formations on the Colorado Plateau, including estimates of maximum possible storage capacity. The primary targets of characterization and capacity analysis include the Cretaceous Dakota Formation, the Jurassic Entrada Formation and the Permian Weber Formation and their equivalents in the Colorado Plateau region. The total CO{sub 2} capacity estimates for the deep saline formations of the Colorado Plateau region range between 9.8 metric GT and 143 metric GT, depending on assumed storage efficiency, formations included, and other factors.

Reactive transport at the pore-scale: Geological Labs on Chip studies (GLoCs) for CO2 storage in saline aquifers

Science.gov (United States)

Azaroual, M. M.; Lassin, A., Sr.; André, L., Sr.; Devau, N., Sr.; Leroy, P., Sr.

2017-12-01

The near well bore of CO2 injection in saline aquifer is the main sensitive part of the targeted carbone storage reservoirs. The recent development of microfluidics tools mimicking porous media of geological reservoirs allowed studying physical, physico-chemical and thermodynamic mechanisms. We used the GLoCs "Geological Labs on Chip" to study dynamic and reactive transport processes at the pore scale induced by the CO2 geological storage. The present work is a first attempt to reproduce, by reactive transport modeling, an experiment of calcium carbonate precipitation during the co-injection of two aqueous solutions in a GLoC device. For that purpose, a new kinetics model, based on the transition-state-theory and on surface complexation modeling, was developed to describe the co-precipitation of amorphous calcium carbonate (ACC) and calcite. ACC precipitates and creates surface complexation sites from which calcite can nucleate and create new surface complexation sites. When the kinetics of calcite precipitation are fast enough, the consumption of matter leads to the dissolution of ACC. The modeling results were first compared to batch experiments (from the literature) and then applied with success to dynamic experiment observations carried out on a GLoC device (from the literature). On the other hand, we evaluated the solubility of CO2 in capillary waters that increases between 5 to 10 folds for reservoir conditions (200 bar and 100°C) compared to the bulk water. The GLoCs tools started to address an excellent and much finer degree of processes control (reactive transport processes, mixing effects, minerals precipitation and dissolution kinetics, etc.) thanks to in situ analysis and characterization techniques, allowing access in real time to relevant properties. Current investigations focus on key parameters influencing the flowing dynamics and trapping mechanisms (relative permeability, capillary conditions, kinetics of dissolution and precipitation of minerals).

Numerical investigation of CO2 storage in hydrocarbon field using a geomechanical-fluid coupling model

Directory of Open Access Journals (Sweden)

Guang Li

2016-09-01

Full Text Available Increasing pore pressure due to CO2 injection can lead to stress and strain changes of the reservoir. One of the safely standards for long term CO2 storage is whether stress and strain changes caused by CO2 injection will lead to irreversible mechanical damages of the reservoir and impact the integrity of caprock which could lead to CO2 leakage through previously sealing structures. Leakage from storage will compromise both the storage capacity and the perceived security of the project, therefore, a successful CO2 storage project requires large volumes of CO2 to be injected into storage site in a reliable and secure manner. Yougou hydrocarbon field located in Orods basin was chosen as storage site based on it's stable geological structure and low leakage risks. In this paper, we present a fluid pressure and stress-strain variations analysis for CO2 geological storage based on a geomechanical-fluid coupling model. Using nonlinear elasticity theory to describe the geomechanical part of the model, while using the Darcy's law to describe the fluid flow. Two parts are coupled together using the poroelasticity theory. The objectives of our work were: 1 evaluation of the geomechanical response of the reservoir to different CO2 injection scenarios. 2 assessment of the potential leakage risk of the reservoir caused by CO2 injection.

Discussion of the influence of CO and CH4 in CO2 transport, injection, and storage for CCS technology.

Science.gov (United States)

Blanco, Sofía T; Rivas, Clara; Bravo, Ramón; Fernández, Javier; Artal, Manuela; Velasco, Inmaculada

2014-09-16

This paper discusses the influence of the noncondensable impurities CO and CH4 on Carbon Capture and Storage (CCS) technology. We calculated and drew conclusions about the impact of both impurities in the CO2 on selected transport, injection, and storage parameters (pipeline pressure drop, storage capacity, etc.), whose analysis is necessary for the safe construction and operation of CO2 pipelines and for the secure long-term geological storage of anthropogenic CO2. To calculate these parameters, it is necessary to acquire data on the volumetric properties and the vapor-liquid equilibrium of the fluid being subjected to CCS. In addition to literature data, we used new experimental data, which are presented here and were obtained for five mixtures of CO2+CO with compositions characteristic of the typical emissions of the E.U. and the U.S.A. Temperatures and pressures are based on relevant CO2 pipeline and geological storage site values. From our experimental results, Peng-Robinson, PC-SAFT, and GERG Equations of State for were validated CO2+CO under the conditions of CCS. We conclude that the concentration of both impurities strongly affects the studied parameters, with CO being the most influential and problematic. The overall result of these negative effects is an increase in the difficulties, risks, and overall costs of CCS.

NETL CO₂ Storage prospeCtive Resource Estimation Excel aNalysis (CO₂-SCREEN) User's Manual

Energy Technology Data Exchange (ETDEWEB)

Sanguinito, Sean M. [National Energy Technology Lab. (NETL), Pittsburgh, PA, (United States); Goodman, Angela [National Energy Technology Lab. (NETL), Pittsburgh, PA, (United States); Levine, Jonathan [National Energy Technology Lab. (NETL), Pittsburgh, PA, (United States)

2017-04-03

This user’s manual guides the use of the National Energy Technology Laboratory’s (NETL) CO₂ Storage prospeCtive Resource Estimation Excel aNalysis (CO₂-SCREEN) tool, which was developed to aid users screening saline formations for prospective CO₂ storage resources. CO₂- SCREEN applies U.S. Department of Energy (DOE) methods and equations for estimating prospective CO₂ storage resources for saline formations. CO2-SCREEN was developed to be substantive and user-friendly. It also provides a consistent method for calculating prospective CO₂ storage resources that allows for consistent comparison of results between different research efforts, such as the Regional Carbon Sequestration Partnerships (RCSP). CO₂-SCREEN consists of an Excel spreadsheet containing geologic inputs and outputs, linked to a GoldSim Player model that calculates prospective CO₂ storage resources via Monte Carlo simulation.

Large temporal scale and capacity subsurface bulk energy storage with CO2

Science.gov (United States)

Saar, M. O.; Fleming, M. R.; Adams, B. M.; Ogland-Hand, J.; Nelson, E. S.; Randolph, J.; Sioshansi, R.; Kuehn, T. H.; Buscheck, T. A.; Bielicki, J. M.

2017-12-01

Decarbonizing energy systems by increasing the penetration of variable renewable energy (VRE) technologies requires efficient and short- to long-term energy storage. Very large amounts of energy can be stored in the subsurface as heat and/or pressure energy in order to provide both short- and long-term (seasonal) storage, depending on the implementation. This energy storage approach can be quite efficient, especially where geothermal energy is naturally added to the system. Here, we present subsurface heat and/or pressure energy storage with supercritical carbon dioxide (CO2) and discuss the system's efficiency, deployment options, as well as its advantages and disadvantages, compared to several other energy storage options. CO2-based subsurface bulk energy storage has the potential to be particularly efficient and large-scale, both temporally (i.e., seasonal) and spatially. The latter refers to the amount of energy that can be stored underground, using CO2, at a geologically conducive location, potentially enabling storing excess power from a substantial portion of the power grid. The implication is that it would be possible to employ centralized energy storage for (a substantial part of) the power grid, where the geology enables CO2-based bulk subsurface energy storage, whereas the VRE technologies (solar, wind) are located on that same power grid, where (solar, wind) conditions are ideal. However, this may require reinforcing the power grid's transmission lines in certain parts of the grid to enable high-load power transmission from/to a few locations.

CO2 Capture Project-An Integrated, Collaborative Technology Development Project for Next Generation CO2 Separation, Capture and Geologic Sequestration

Energy Technology Data Exchange (ETDEWEB)

Helen Kerr; Linda M. Curran

2005-04-15

The CO{sub 2} Capture Project (CCP) was a joint industry project, funded by eight energy companies (BP, ChevronTexaco, EnCana, ENI, Norsk Hydro, Shell, Statoil, and Suncor) and three government agencies (European Union [DG RES & DG TREN], the Norwegian Research Council [Klimatek Program] and the U.S. Department of Energy [NETL]). The project objective was to develop new technologies that could reduce the cost of CO{sub 2} capture and geologic storage by 50% for retrofit to existing plants and 75% for new-build plants. Technologies were to be developed to ''proof of concept'' stage by the end of 2003. Certain promising technology areas were increased in scope and the studies extended through 2004. The project budget was approximately $26.4 million over 4 years and the work program is divided into eight major activity areas: Baseline Design and Cost Estimation--defined the uncontrolled emissions from each facility and estimate the cost of abatement in $/tonne CO{sub 2}. Capture Technology, Post Combustion: technologies, which can remove CO{sub 2} from exhaust gases after combustion. Capture Technology, Oxyfuel: where oxygen is separated from the air and then burned with hydrocarbons to produce an exhaust with high CO{sub 2} for storage. Capture Technology, Pre-Combustion: in which, natural gas and petroleum cokes are converted to hydrogen and CO{sub 2} in a reformer/gasifier. Common Economic Model/Technology Screening: analysis and evaluation of each technology applied to the scenarios to provide meaningful and consistent comparison. New Technology Cost Estimation: on a consistent basis with the baseline above, to demonstrate cost reductions. Geologic Storage, Monitoring and Verification (SMV): providing assurance that CO{sub 2} can be safely stored in geologic formations over the long term. Non-Technical: project management, communication of results and a review of current policies and incentives governing CO{sub 2} capture and storage. Pre

Toward physical aspects affecting a possible leakage of geologically stored CO₂ into the shallow subsurface

DEFF Research Database (Denmark)

Singh, Ashok; Delfs, Jens Olaf; Görke, Uwe Jens

2014-01-01

In geological formations, migration of CO2 plume is very complex and irregular. To make CO2 capture and storage technology feasible, it is important to quantify CO2 amount associated with possible leakage through natural occurring faults and fractures in geologic medium. Present work examines the...

Evolution of the Petrophysical and Mineralogical Properties of Two Reservoir Rocks Under Thermodynamic Conditions Relevant for CO2 Geological Storage at 3 km Depth

International Nuclear Information System (INIS)

Rimmel, G.; Barlet-Gouedard, V.; Renard, F.

2010-01-01

Injection of carbon dioxide (CO 2 ) underground, for long-term geological storage purposes, is considered as an economically viable option to reduce greenhouse gas emissions in the atmosphere. The chemical interactions between supercritical CO 2 and the potential reservoir rock need to be thoroughly investigated under thermodynamic conditions relevant for geological storage. In the present study, 40 samples of Lavoux limestone and Adamswiller sandstone, both collected from reservoir rocks in the Paris basin, were experimentally exposed to CO 2 in laboratory autoclaves specially built to simulate CO 2 -storage-reservoir conditions. The two types of rock were exposed to wet supercritical CO 2 and CO 2 -saturated water for one month, at 28 MPa and 90 C, corresponding to conditions for a burial depth approximating 3 km. The changes in mineralogy and micro-texture of the samples were measured using X-ray diffraction analyses, Raman spectroscopy, scanning-electron microscopy, and energy-dispersion spectroscopy microanalysis. The petrophysical properties were monitored by measuring the weight, density, mechanical properties, permeability, global porosity, and local porosity gradients through the samples. Both rocks maintained their mechanical and mineralogical properties after CO 2 exposure despite an increase of porosity and permeability. Microscopic zones of calcite dissolution observed in the limestone are more likely to be responsible for such increase. In the sandstone, an alteration of the petro-fabric is assumed to have occurred due to clay minerals reacting with CO 2 . All samples of Lavoux limestone and Adamswiller sandstone showed a measurable alteration when immersed either in wet supercritical CO 2 or in CO 2 -saturated water. These batch experiments were performed using distilled water and thus simulate more severe conditions than using formation water (brine). (authors)

CO2 sequestration

International Nuclear Information System (INIS)

Favre, E.; Jammes, L.; Guyot, F.; Prinzhofer, A.; Le Thiez, P.

2009-01-01

This document presents the summary of a conference-debate held at the Academie des Sciences (Paris, France) on the topic of CO 2 sequestration. Five papers are reviewed: problems and solutions for the CO 2 sequestration; observation and surveillance of reservoirs; genesis of carbonates and geological storage of CO 2 ; CO 2 sequestration in volcanic and ultra-basic rocks; CO 2 sequestration, transport and geological storage: scientific and economical perspectives

Have We Overestimated Saline Aquifer CO2 Storage Capacities?

International Nuclear Information System (INIS)

Thibeau, S.; Mucha, V.

2011-01-01

During future, large scale CO 2 geological storage in saline aquifers, fluid pressure is expected to rise as a consequence of CO 2 injection, but the pressure build up will have to stay below specified values to ensure a safe and long term containment of the CO 2 in the storage site. The pressure build up is the result of two different effects. The first effect is a local overpressure around the injectors, which is due to the high CO 2 velocities around the injectors, and which can be mitigated by adding CO 2 injectors. The second effect is a regional scale pressure build up that will take place if the storage aquifer is closed or if the formation water that flows away from the pressurised area is not large enough to compensate volumetrically the CO 2 injection. This second effect cannot be mitigated by adding additional injectors. In the first section of this paper, we review some major global and regional assessments of CO 2 storage capacities in deep saline aquifers, in term of mass and storage efficiency. These storage capacities are primarily based on a volumetric approach: storage capacity is the volumetric sum of the CO 2 that can be stored through various trapping mechanisms. We then discuss in Section 2 storage efficiencies derived from a pressure build up approach, as stated in the CO2STORE final report (Chadwick A. et al. (eds) (2008) Best Practice for the Storage of CO 2 in Saline Aquifers, Observations and Guidelines from the SACS and CO2STORE Projects, Keyworth, Nottingham, BGS Occasional Publication No. 14) and detailed by Van der Meer and Egberts (van der Meer L.G.H., Egberts P.J.P. (2008) A General Method for Calculating Subsurface CO 2 Storage Capacity, OTC Paper 19309, presented at the OTC Conference held in Houston, Texas, USA, 5-8 May). A quantitative range of such storage efficiency is presented, based on a review of orders of magnitudes of pore and water compressibilities and allowable pressure increase. To illustrate the relevance of this

Shaft sealing issue in CO2 storage sites

Science.gov (United States)

Dieudonné, A.-C.; Charlier, R.; Collin, F.

2012-04-01

Carbon capture and storage is an innovating approach to tackle climate changes through the reduction of greenhouse gas emissions. Deep saline aquifers, depleted oil and gas reservoirs and unmineable coal seams are among the most studied reservoirs. However other types of reservoir, such as abandonned coal mines, could also be used for the storage of carbon dioxide. In this case, the problem of shaft sealing appears to be particularly critical regarding to the economic, ecologic and health aspects of geological storage. The purpose of the work is to study shaft sealing in the framework of CO2 storage projects in abandoned coal mines. The problem of gas transfers around a sealing system is studied numerically using the finite elements code LAGAMINE, which has been developped for 30 years at the University of Liege. A coupled hydro-mechanical model of unsaturated geomaterials is used for the analyses. The response of the two-phase flow model is first studied through a simple synthetic problem consisting in the injection of gas in a concrete-made column. It stands out of this first modeling that the advection of the gas phase represents the main transfer mechanism of CO2 in highly unsaturated materials. Furthermore the setting of a bentonite barrier seal limits considerably the gas influx into the biosphere. A 2D axisymetric hydromechanical modeling of the Anderlues natural gas storage site is then performed. The geological and hydrogeological contexts of the site are used to define the problem, for the initial and boundary conditions, as well as the material properties. In order to reproduce stress and water saturation states in the shale before CO2 injection in the mine, different phases corresponding to the shaft sinking, the mining and the set up of the sealing system are simulated. The system efficiency is then evaluated by simulating the CO2 injection with the imposed pressure at the shaft wall. According to the modeling, the low water saturation of concrete and

Summary Report on CO{sub 2} Geologic Sequestration & Water Resources Workshop

Energy Technology Data Exchange (ETDEWEB)

Varadharajan, C.; Birkholzer, J.; Kraemer, S.; Porse, S.; Carroll, S.; Wilkin, R.; Maxwell, R.; Bachu, S.; Havorka, S.; Daley, T.; Digiulio, D.; Carey, W.; Strasizar, B.; Huerta, N.; Gasda, S.; Crow, W.

2012-02-15

The United States Environmental Protection Agency (EPA) and Lawrence Berkeley National Laboratory (LBNL) jointly hosted a workshop on “CO{sub 2} Geologic Sequestration and Water Resources” in Berkeley, June 1–2, 2011. The focus of the workshop was to evaluate R&D needs related to geological storage of CO{sub 2} and potential impacts on water resources. The objectives were to assess the current status of R&D, to identify key knowledge gaps, and to define specific research areas with relevance to EPA’s mission. About 70 experts from EPA, the DOE National Laboratories, industry, and academia came to Berkeley for two days of intensive discussions. Participants were split into four breakout session groups organized around the following themes: Water Quality and Impact Assessment/Risk Prediction; Modeling and Mapping of Area of Potential Impact; Monitoring and Mitigation; Wells as Leakage Pathways. In each breakout group, participants identified and addressed several key science issues. All groups developed lists of specific research needs; some groups prioritized them, others developed short-term vs. long-term recommendations for research directions. Several crosscutting issues came up. Most participants agreed that the risk of CO{sub 2} leakage from sequestration sites that are properly selected and monitored is expected to be low. However, it also became clear that more work needs to be done to be able to predict and detect potential environmental impacts of CO{sub 2} storage in cases where the storage formation may not provide for perfect containment and leakage of CO{sub 2}–brine might occur.

Kalundborg case study, a feasibility study of CO{sub 2} storage in onshore saline aquifers. CO2STORE[Denmark

Energy Technology Data Exchange (ETDEWEB)

Larsen, Michael; Bech, N.; Bidstrup, T.; Christensen, Niels Peter; Vangkilde-Pedersen, T. [GEUS (Denmark); Biede, O. [ENERGI E2 (Denmark)

2007-06-15

The Danish case-study of the CO2STORE project comprises the potential future capture and underground storage of CO{sub 2} from two point sources. These are the coal fired power plant Asnaesvaerket and the Statoil refinery both located in the city of Kalundborg, Denmark. Initial mapping of the storage structure was conducted as part of the EU funded research project GESTCO that was concluded in 2003. The study identified a large underground structure forming a potential, future storage site 15 km to the northeast of the city. Porous sandstones filled with saline water at a depth of approximately 1.500 m form the reservoir. The structure covers approximately 160 km{sup 2} and a preliminary calculation suggests a storage capacity of nearly 900 million tonnes of CO2 equal to more than 150 years of CO{sub 2} emissions from the two point sources. In the Kalundborg case-study, a fictive capture and storage scenario will be formulated and modelled. The scenario is based on experiences learned through the SACS and GESTCO projects. Detailed geological modelling, reservoir simulation, reservoir and cap rock characterisation and risk assessment will be important issues for the case-study. The Geological Survey of Denmark and Greenland (GEUS) is project leader for the Kalundborg case-study. Information on CO{sub 2} emissions from the point sources and technical and economical input for the three scenarios is provided by the industrial partners; ENERGI E2 and Statoil ASA. The scenario is designed only for this case study and does not reflect the strategic plans of ENERGI E2 nor Statoil ASA. Geochemical simulation and modelling studies on reservoir and cap rock were performed at Bureau de Recherches Geologiques et Minieres (BRGM) in France. The CO2STORE project is performed within the European Community supported 5th Framework Programme. (au)

Modelling of the Duero Sedimentary Basin and Selection of Deep Favourable Geological Formations for Supercritical CO{sub 2} Storage; Modelizacion del Subsuelo de la Cuenca del Duero y Seleccion de Formaciones Favorables para el Almacenamiento de CO{sub 2} en Estado Supercritico

Energy Technology Data Exchange (ETDEWEB)

Prado, A. J.; Perez del Villar, L.; Pelayo, M.; Recreo, F.

2008-04-10

Currently, the Deep Geological Storage is the internationally most accepted option to store CO{sub 2}, whose main goal is to reduce the CO{sub 2} emissions to the atmosphere. This work, which has been carried out in the frame of The Strategic Singular Project entitled: CO{sub 2} generation, capture and storage advanced technologies summarizes a general methodology focused on the selection and modelling of favourable formations to store CO{sub 2} and to estimate their storage capacity. To conclude, the Duero basin suitability to allocate a CO{sub 2} storage plant has been quantified by integrating the Multi-criteria Evaluation Methods with the corresponding developed Geographical Information Systems. (Author) 45 refs.

Environmental Responses to Carbon Mitigation through Geological Storage

Energy Technology Data Exchange (ETDEWEB)

Cunningham, Alfred [Montana State Univ., Bozeman, MT (United States); Bromenshenk, Jerry [Montana State Univ., Bozeman, MT (United States)

2013-08-30

In summary, this DOE EPSCoR project is contributing to the study of carbon mitigation through geological storage. Both deep and shallow subsurface research needs are being addressed through research directed at improved understanding of environmental responses associated with large scale injection of CO₂ into geologic formations. The research plan has two interrelated research objectives. Objective 1: Determine the influence of CO₂-related injection of fluids on pore structure, material properties, and microbial activity in rock cores from potential geological carbon sequestration sites. Objective 2: Determine the Effects of CO₂ leakage on shallow subsurface ecosystems (microbial and plant) using field experiments from an outdoor field testing facility.

Preliminary Study of Favourable Formations for CO{sub 2} Subsurface Storage in Spain; Estudio Preliminar de las Formaciones Favorables para el Almacenamiento Subterraneo de CO{sub 2} en Espana

Energy Technology Data Exchange (ETDEWEB)

Zapatero, M. A.; Reyes, J. L.; Martinez, R.; Suarez, I.; Arenillas, A.; Perucha, M. A.

2009-10-12

This report is a synthesis of the possibilities of CO{sub 2} storage in the Spanish subsurface. Compilation and analysis of geological information has been carried out, looking at surface and subsurface, in order to make a pre-selection of potential favourable units for CO{sub 2} storage, taking in account that each of this storages needs a confining formation to seal the storage. Before the storage selection, a general description of the great geological units of the Iberian Peninsula is done. Afterwards, borehole logging from petroleum exploration is analysed in these units, formations and areas of interest. The aim is to finally obtain a description of selected units and their possibilities of CO{sub 2} storage. (Author) 17 refs.

Canadian CO2 Capture and Storage Technology Network : promoting zero emissions technologies

International Nuclear Information System (INIS)

2004-11-01

This brochure provided information on some Canadian initiatives in carbon dioxide (CO 2 ) capture and storage. There has been growing interest in the implementation of components of CO 2 capture, storage and utilization technologies in Canada. Technology developments by the CANMET Energy Technology Centre concerning CO 2 capture using oxy-fuel combustion and amine separation were examined. Techniques concerning gasification of coal for electricity production and CO 2 capture were reviewed. Details of a study of acid gas underground injection were presented. A review of monitoring technologies in CO 2 storage in enhanced oil recovery was provided. Issues concerning the enhancement of methane recovery through the monitoring of CO 2 injected into deep coal beds were discussed. Storage capacity assessment of Canadian sedimentary basins, coal seams and oil and gas reservoirs were reviewed, in relation to their suitability for CO 2 sequestration. Details of the International Test Centre for Carbon Dioxide Capture in Regina, Saskatchewan were presented, as well as issues concerning the sequestration of CO 2 in oil sands tailings streams. A research project concerning the geologic sequestration of CO 2 and simultaneous CO 2 and methane production from natural gs hydrate reservoirs was also discussed. 12 figs.

Simple dielectric mixing model in the monitoring of CO2 leakage from geological storage aquifer

Science.gov (United States)

Abidoye, L. K.; Bello, A. A.

2017-03-01

The principle of the dielectric mixing for multiphase systems in porous media has been employed to investigate CO2-water-porous media system and monitor the leakage of CO2, in analogy to scenarios that can be encountered in geological carbon sequestration. A dielectric mixing model was used to relate the relative permittivity for different subsurface materials connected with the geological carbon sequestration. The model was used to assess CO2 leakage and its upward migration, under the influences of the depth-dependent characteristics of the subsurface media as well as the fault-connected aquifers. The results showed that for the upward migration of CO2 in the subsurface, the change in the bulk relative permittivity (εb) of the CO2-water-porous media system clearly depicts the leakage and movement of CO2, especially at depth shallower than 800 m. At higher depth, with higher pressure and temperature, the relative permittivity of CO2 increases with pressure, while that of water decreases with temperature. These characteristics of water and supercritical CO2, combine to limit the change in the εb, at higher depth. Furthermore, it was noted that if the pore water was not displaced by the migrating CO2, the presence of CO2 in the system increases the εb. But, with the displacement of pore water by the migrating CO2, it was shown how the εb profile decreases with time. Owing to its relative simplicity, composite dielectric behaviour of multiphase materials can be effectively deployed for monitoring and enhancement of control of CO2 movement in the geological carbon sequestration.

Risk Assessment and Management for Long-Term Storage of CO2 in Geologic Formations — United States Department of Energy R&D

Directory of Open Access Journals (Sweden)

Dawn Deel

2007-02-01

Full Text Available Concern about increasing atmospheric concentrations of carbon dioxide (CO2 and other greenhouse gases (GHG and their impact on the earth's climate has grown significantly over the last decade. Many countries, including the United States, wrestle with balancing economic development and meeting critical near-term environmental goals while minimizing long-term environmental risks. One promising solution to the buildup of GHGs in the atmosphere, being pursued by the U.S. Department of Energy's (DOE National Energy Technology Laboratory (NETL and its industrial and academic partners, is carbon sequestration—a process of permanent storage of CO2 emissions in underground geologic formations, thus avoiding CO2 release to the atmosphere. This option looks particularly attractive for point source emissions of GHGs, such as fossil fuel fired power plants. CO2 would be captured, transported to a sequestration site, and injected into an appropriate geologic formation. However, sequestration in geologic formations cannot achieve a significant role in reducing GHG emissions unless it is acceptable to stakeholders, regulators, and the general public, i.e., unless the risks involved are judged to be acceptable. One tool that can be used to achieve acceptance of geologic sequestration of CO2 is risk assessment, which is a proven method to objectively manage hazards in facilities such as oil and natural gas fields, pipelines, refineries, and chemical plants. Although probabilistic risk assessment (PRA has been applied in many areas, its application to geologic CO2 sequestration is still in its infancy. The most significant risk from geologic carbon sequestration is leakage of CO2. Two types of CO2 releases are possible—atmospheric and subsurface. High concentrations of CO2 caused by a release to the atmosphere would pose health risks to humans and animals, and any leakage of CO2 back into the atmosphere negates the effort expended to sequester the CO2

Near-surface monitoring strategies for geologic carbon dioxide storage verification

Energy Technology Data Exchange (ETDEWEB)

Oldenburg, Curtis M.; Lewicki, Jennifer L.; Hepple, Robert P.

2003-10-31

Geologic carbon sequestration is the capture of anthropogenic carbon dioxide (CO{sub 2}) and its storage in deep geologic formations. Geologic CO{sub 2} storage verification will be needed to ensure that CO{sub 2} is not leaking from the intended storage formation and seeping out of the ground. Because the ultimate failure of geologic CO{sub 2} storage occurs when CO{sub 2} seeps out of the ground into the atmospheric surface layer, and because elevated concentrations of CO{sub 2} near the ground surface can cause health, safety, and environmental risks, monitoring will need to be carried out in the near-surface environment. The detection of a CO{sub 2} leakage or seepage signal (LOSS) in the near-surface environment is challenging because there are large natural variations in CO{sub 2} concentrations and fluxes arising from soil, plant, and subsurface processes. The term leakage refers to CO{sub 2} migration away from the intended storage site, while seepage is defined as CO{sub 2} passing from one medium to another, for example across the ground surface. The flow and transport of CO{sub 2} at high concentrations in the near-surface environment will be controlled by its high density, low viscosity, and high solubility in water relative to air. Numerical simulations of leakage and seepage show that CO{sub 2} concentrations can reach very high levels in the shallow subsurface even for relatively modest CO{sub 2} leakage fluxes. However, once CO{sub 2} seeps out of the ground into the atmospheric surface layer, surface winds are effective at dispersing CO{sub 2} seepage. In natural ecological systems with no CO{sub 2} LOSS, near-surface CO{sub 2} fluxes and concentrations are controlled by CO{sub 2} uptake by photosynthesis, and production by root respiration, organic carbon biodegradation in soil, deep outgassing of CO{sub 2}, and by exchange of CO{sub 2} with the atmosphere. Existing technologies available for monitoring CO{sub 2} in the near-surface environment

Assessing European capacity for geological storage of carbon dioxide-the EU GeoCapacity project

NARCIS (Netherlands)

Vangkilde-Pedersen, T.; Anthonsen, K.L.; Smith, N.; Kirk, K.; Neele, F.; Meer, B. van der; Le Gallo, Y. le; Bossie-Codreanu, D.; Wojcicki, A.; Nindre, Y.-M. le; Hendriks, C.; Dalhoff, F.; Peter Christensen, N.

2009-01-01

The focus of the GeoCapacity project is GIS mapping of CO2 point sources, infrastructure and geological storage in Europe. The main objective is to assess the European capacity for geological storage of CO2 in deep saline aquifers, oil and gas structures and coal beds. Other priorities are further

CO2 CAPTURE PROJECT - AN INTEGRATED, COLLABORATIVE TECHNOLOGY DEVELOPMENT PROJECT FOR NEXT GENERATION CO2 SEPARATION, CAPTURE AND GEOLOGIC SEQUESTRATION

Energy Technology Data Exchange (ETDEWEB)

Dr. Helen Kerr

2003-08-01

The CO{sub 2} Capture Project (CCP) is a joint industry project, funded by eight energy companies (BP, ChevronTexaco, EnCana, Eni, Norsk Hydro, Shell, Statoil, and Suncor) and three government agencies (1) European Union (DG Res & DG Tren), (2) Norway (Klimatek) and (3) the U.S.A. (Department of Energy). The project objective is to develop new technologies, which could reduce the cost of CO{sub 2} capture and geologic storage by 50% for retrofit to existing plants and 75% for new-build plants. Technologies are to be developed to ''proof of concept'' stage by the end of 2003. The project budget is approximately $24 million over 3 years and the work program is divided into eight major activity areas: (1) Baseline Design and Cost Estimation--defined the uncontrolled emissions from each facility and estimate the cost of abatement in $/tonne CO{sub 2}. (2) Capture Technology, Post Combustion: technologies, which can remove CO{sub 2} from exhaust gases after combustion. (3) Capture Technology, Oxyfuel: where oxygen is separated from the air and then burned with hydrocarbons to produce an exhaust with high CO{sub 2} for storage. (4) Capture Technology, Pre -Combustion: in which, natural gas and petroleum coke are converted to hydrogen and CO{sub 2} in a reformer/gasifier. (5) Common Economic Model/Technology Screening: analysis and evaluation of each technology applied to the scenarios to provide meaningful and consistent comparison. (6) New Technology Cost Estimation: on a consistent basis with the baseline above, to demonstrate cost reductions. (7) Geologic Storage, Monitoring and Verification (SMV): providing assurance that CO{sub 2} can be safely stored in geologic formations over the long term. (8) Non-Technical: project management, communication of results and a review of current policies and incentives governing CO{sub 2} capture and storage. Technology development work dominated the past six months of the project. Numerous studies are making

Experimental Studies on the Interaction of scCO2 and scCO2-SO2 With Rock Forming Minerals at Conditions of Geologic Carbon Storages - First Results

Science.gov (United States)

Erzinger, J.; Wilke, F.; Wiersberg, T.; Vasquez Parra, M.

2010-12-01

Co-injection of SO2 (plus possibly NOx and O2) during CO2 storage in deep saline aquifers may cause stronger brine acidification than CO2 alone. Because of that, we investigate chemical corrosion of rocks and rock-forming minerals with impure supercritical CO2 (scCO2) at possible storage conditions of >73.7 bar and >31°C. Contaminates were chosen with respect to the composition of CO2 captured industrially from coal-fired power plants using the oxyfuel technology. The resulting data should build a base for the long-term prediction of the behavior of CO2 in geologic storage reservoirs. Experiments of up to 1000 hrs duration have been performed with 10 natural mineral concentrates (calcite, dolomite, siderite, anhydrite, hematite, albite, microcline, kaolinite, muscovite, biotite) in 3n NaCl solution and pure scCO2 or scCO2+SO2 (99.5+0.5 vol%). The NaCl reaction fluid resembles the average salinity of deep formation waters of the North German Basin and is not free of oxygen. To increase reaction rates all minerals were ground and the reagents agitated either by stirring or shaking in autoclaves of about one liter in volume. The autoclaves consist of Hastelloy™ or ferromagnetic stainless steel fully coated with PTFE. We used in average 15 g of solids, 700 ml liquid, and the vessels were pressurized up to 100 bars with CO2 or CO2-SO2 mixture. Experiments were run at temperatures up to 90°C. Before, during and after the experiments small amounts fluids were sampled and analyzed for dissolved constituents and pH. Solid phases were characterized by XRF, XRD, and EMPA before and after the experiments. Pure scCO2 corrodes all carbonates, reacts only slightly with anhydrite, albite, and microcline at a minimum pH of 4, and does not recognizably interact with the others. After the experiment, albite has gained in a, not yet fully identified, carbonate phase which might be dawsonite. Reaction fluids of the experiments with scCO2+SO2 have mostly lower pH than using scCO2

A sensitivity analysis on seismic tomography data with respect to CO2 saturation of a CO2 geological sequestration field

Science.gov (United States)

Park, Chanho; Nguyen, Phung K. T.; Nam, Myung Jin; Kim, Jongwook

2013-04-01

Monitoring CO2 migration and storage in geological formations is important not only for the stability of geological sequestration of CO2 but also for efficient management of CO2 injection. Especially, geophysical methods can make in situ observation of CO2 to assess the potential leakage of CO2 and to improve reservoir description as well to monitor development of geologic discontinuity (i.e., fault, crack, joint, etc.). Geophysical monitoring can be based on wireline logging or surface surveys for well-scale monitoring (high resolution and nallow area of investigation) or basin-scale monitoring (low resolution and wide area of investigation). In the meantime, crosswell tomography can make reservoir-scale monitoring to bridge the resolution gap between well logs and surface measurements. This study focuses on reservoir-scale monitoring based on crosswell seismic tomography aiming describe details of reservoir structure and monitoring migration of reservoir fluid (water and CO2). For the monitoring, we first make a sensitivity analysis on crosswell seismic tomography data with respect to CO2 saturation. For the sensitivity analysis, Rock Physics Models (RPMs) are constructed by calculating the values of density and P and S-wave velocities of a virtual CO2 injection reservoir. Since the seismic velocity of the reservoir accordingly changes as CO2 saturation changes when the CO2 saturation is less than about 20%, while when the CO2 saturation is larger than 20%, the seismic velocity is insensitive to the change, sensitivity analysis is mainly made when CO2 saturation is less than 20%. For precise simulation of seismic tomography responses for constructed RPMs, we developed a time-domain 2D elastic modeling based on finite difference method with a staggered grid employing a boundary condition of a convolutional perfectly matched layer. We further make comparison between sensitivities of seismic tomography and surface measurements for RPMs to analysis resolution

Use of comparative assessment framework for comparison of geological nuclear waste and CO2 disposal technologies

Energy Technology Data Exchange (ETDEWEB)

Streimikiene, Dalia

2010-09-15

Comparative assessment of few future energy and climate change mitigation options for Lithuania in 2020 performed indicated that nuclear and combined cycle gas turbine technologies are very similar energy options in terms of costs taking into account GHG emission reduction costs. Comparative assessment of these energy options requires evaluation of the potentials and costs for geological CO2 and nuclear waste storage as the main uncertainties in comparative assessment of electricity generation technologies are related with these back-end technologies. The paper analyses the main characteristics of possible geological storage of CO2 and NW options in Lithuania.

Microorganisms implication in the CO2 geologic storage processes

International Nuclear Information System (INIS)

Dupraz, S.

2008-01-01

A first result of this thesis is the building and validation of a circulation reactor named BCC (Bio-mineralization Control Cell). The reactor has the functionality of a biological reactor and allows a monitoring of physico-chemical characteristics such as Eh, pH, electrical conductivity, spectro-photochemical parameters. It also has a capability of percolation through rock cores. It is a first step toward an analogical modeling of interactions between injected CO 2 and deep bio-spheric components. Moreover, a new spectro-photochemical method for monitoring reduced sulfur species has been developed which allows efficient monitoring of sulfate-reducing metabolisms. In the thesis, we have tested four metabolisms relevant to bio-mineralisation or biological assimilation of CO 2 : a reference ureolytic aerobic strain, Bacillus pasteurii, a sulfate-reducing bacterium, Desulfovibrio longus, a sulfate-reducing consortium (DVcons) and an homoacetogenic bacterium, Acetobacterium carbinolicum. In the case of Bacillus pasteurii, which is considered as a model for non photosynthetic prokaryotic carbonate bio-mineralization, we have demonstrated that the biological basification and carbonate bio-mineralization processes can be modelled accurately both analogically and numerically under conditions relevant to deep CO 2 storage, using a synthetic saline groundwater. We have shown that salinity has a positive effect on CO 2 mineral trapping by this bacterium; we have measured the limits of the system in terms of CO 2 pressure and we have shown that the carbonates that nucleate on intracellular calcium phosphates have specific carbon isotope signatures. The studied deep-subsurface strains (Desulfovibrio longus and Acetobacterium carbinolicum) as well as the sulfate-reducing consortium also have capabilities of converting CO 2 into solid carbonates, much less efficient though than in the case of Bacillus pasteurii. However, once inoculated in synthetic saline groundwater and

Demonstrating storage of CO2 in geological reservoirs: the Sleipner and SACS projects

International Nuclear Information System (INIS)

Torp, T.A.; Gale, J.

2004-01-01

At the Sleipner gas field in the North Sea, CO 2 has been stripped from the produced natural gas and injected into a sand layer called the Utsira formation. Injection started in October 1996, to date nearly 8 million tonnes of CO 2 have been injected without any significant operational problems observed in the capture plant or in the injection well. The Sleipner project is the first commercial application of CO 2 storage in deep saline aquifers in the world. To monitor the injected CO 2 , a separate project called the saline aquifer CO 0 2 storage (SACS) project was established in 1998. As part of the SACS project, 3D seismic surveying has been used to successfully monitor the CO 2 in the Utsira formation, an industry first. Repeat seismic surveys have successfully imaged movement of the injected CO 2 within the reservoir. Reservoir simulation tools have been successfully adapted to describe the migration of the CO 2 in the reservoir. The simulation packages have been calibrated against the repeat seismic surveys and shown themselves to be capable of replicating the position of the CO 2 in the reservoir. The possible reactions between minerals within the reservoir sand and the injected CO 2 have been studied by laboratory experiments and simulations. The cumulative experiences of the Sleipner and SACS projects will be embodied in a Best Practice Manual to assist other organisations planning CO 2 injection projects to take advantage of the learning processes undertaken and to assist in facilitating new projects of this type. (author)

Geological storage of CO2 : Mechanical and chemical effects on host and seal formations

NARCIS (Netherlands)

Hangx, Suzanne

2009-01-01

The socio-economic impact of global warming resulting from anthropogenic CO2 emissions has lead to much attention for carbon mitigation strategies in recent years. One of the most promising ways of disposing of CO2 is through Carbon Capture and Storage (CCS), entailing CO2 capture at source,

Penn West Energy Trust CO{sub 2} EOR storage monitoring project

Energy Technology Data Exchange (ETDEWEB)

Chalaturnyk, R. [Alberta Univ., Edmonton, AB (Canada)

2007-07-01

This presentation described Penn West Energy Trust's carbon dioxide (CO{sub 2}) enhanced oil recovery (EOR) storage monitoring project. The project formed part of a royalty credit program that offered a royalty reduction to energy companies as part of a plan to encourage the development of a CO{sub 2} storage industry in Alberta. The multi-agency project is expected to provide a better understanding of the fate of CO{sub 2} injected into petroleum reservoirs and the role that CO{sub 2} storage will play in reducing greenhouse gas (GHG) emissions. The project is located in a reservoir that had previously been waterflooded. High purity CO{sub 2} is injected through 2 directional wells. Data acquired from the field is used to provide information on baseline geology and hydrogeology, as well as to provide details of baseline leakages. Rock properties are investigated in order identify issues affecting rock strength. Geophysical monitoring is conducted to interpret baseline seismic profile datasets as well as to integrate active and passive survey analyses with geochemical characterization studies and reservoir models. The project is currently in the stage of developing a simulation model based on a comprehensive understanding of CO{sub 2} injection mechanisms. The model will be used to predict CO{sub 2} storage capacity and movement. refs., tabs., figs.

Subsurface impact of CO2: Response of carbonate rocks and wellbore cement to supercritical CO2 injection and long-term storage. Geologica Ultraiectina (310)

NARCIS (Netherlands)

Liteanu, E.

2009-01-01

Capture of CO2 at fossil fuel power station coupled with geological storage in empty oil and gas reservoirs is widely viewed as the most promising option for reducing CO2 emissions to the atmosphere, i.e. for climate change mitigation. Injection of CO2 into such reservoirs will change their chemical

A Dynamic Programming Model for Optimizing Frequency of Time-Lapse Seismic Monitoring in Geological CO2 Storage

Science.gov (United States)

Bhattacharjya, D.; Mukerji, T.; Mascarenhas, O.; Weyant, J.

2005-12-01

Designing a cost-effective and reliable monitoring program is crucial to the success of any geological CO2 storage project. Effective design entails determining both, the optimal measurement modality, as well as the frequency of monitoring the site. Time-lapse seismic provides the best spatial coverage and resolution for reservoir monitoring. Initial results from Sleipner (Norway) have demonstrated effective monitoring of CO2 plume movement. However, time-lapse seismic is an expensive monitoring technique especially over the long term life of a storage project and should be used judiciously. We present a mathematical model based on dynamic programming that can be used to estimate site-specific optimal frequency of time-lapse surveys. The dynamics of the CO2 sequestration process are simplified and modeled as a four state Markov process with transition probabilities. The states are M: injected CO2 safely migrating within the target zone; L: leakage from the target zone to the adjacent geosphere; R: safe migration after recovery from leakage state; and S: seepage from geosphere to the biosphere. The states are observed only when a monitoring survey is performed. We assume that the system may go to state S only from state L. We also assume that once observed to be in state L, remedial measures are always taken to bring it back to state R. Remediation benefits are captured by calculating the expected penalty if CO2 seeped into the biosphere. There is a trade-off between the conflicting objectives of minimum discounted costs of performing the next time-lapse survey and minimum risk of seepage and its associated costly consequences. A survey performed earlier would spot the leakage earlier. Remediation methods would have been utilized earlier, resulting in savings in costs attributed to excessive seepage. On the other hand, there are also costs for the survey and remedial measures. The problem is solved numerically using Bellman's optimality principal of dynamic

Screening and ranking framework (SRF) for geologic CO2 storagesite selection on the basis of HSE risk

Energy Technology Data Exchange (ETDEWEB)

Oldenburg, Curtis M.

2006-11-27

A screening and ranking framework (SRF) has been developedto evaluate potential geologic carbon dioxide (CO2) storage sites on thebasis of health, safety, and environmental (HSE) risk arising from CO2leakage. The approach is based on the assumption that CO2 leakage risk isdependent on three basic characteristics of a geologic CO2 storage site:(1) the potential for primary containment by the target formation; (2)the potential for secondary containment if the primary formation leaks;and (3) the potential for attenuation and dispersion of leaking CO2 ifthe primary formation leaks and secondary containment fails. Theframework is implemented in a spreadsheet in which users enter numericalscores representing expert opinions or published information along withestimates of uncertainty. Applications to three sites in Californiademonstrate the approach. Refinements and extensions are possible throughthe use of more detailed data or model results in place of propertyproxies.

Continuous atmospheric monitoring of the injected CO2 behavior over geological storage sites using flux stations: latest technologies and resources

Science.gov (United States)

Burba, George; Madsen, Rodney; Feese, Kristin

2014-05-01

quantify leakages from the subsurface, to improve storage efficiency, and for other storage characterizations [5-8]. In this presentation, the latest regulatory and methodological updates are provided regarding atmospheric monitoring of the injected CO2 behavior using flux stations. These include 2013 improvements in methodology, as well as the latest literature, including regulatory documents for using the method and step-by-step instructions on implementing it in the field. Updates also include 2013 development of a fully automated remote unattended flux station capable of processing data on-the-go to continuously output final CO2 emission rates in a similar manner as a standard weather station outputs weather parameters. References: [1] Burba G. Eddy Covariance Method for Scientific, Industrial, Agricultural and Regulatory Applications. LI-COR Biosciences; 2013. [2] International Energy Agency. Quantification techniques for CO2 leakage. IEA-GHG; 2012. [3] US Department of Energy. Best Practices for Monitoring, Verification, and Accounting of CO2 Stored in Deep Geologic Formations. US DOE; 2012. [4] Liu G. (Ed.). Greenhouse Gases: Capturing, Utilization and Reduction. Intech; 2012. [5] Finley R. et al. An Assessment of Geological Carbon Sequestration Options in the Illinois Basin - Phase III. DOE-MGSC; DE-FC26-05NT42588; 2012. [6] LI-COR Biosciences. Surface Monitoring for Geologic Carbon Sequestration. LI-COR, 980-11916, 2011. [7] Eggleston H., et al. (Eds). IPCC Guidelines for National Greenhouse Gas Inventories, IPCC NGGI P, WMO/UNEP; 2006-2011. [8] Burba G., Madsen R., Feese K. Eddy Covariance Method for CO2 Emission Measurements in CCUS Applications: Principles, Instrumentation and Software. Energy Procedia, 40C: 329-336; 2013.

Assessment of Ademe's R and D actions for the CO2 capture and storage sector

International Nuclear Information System (INIS)

2015-05-01

This publication presents research actions and projects supported by the ADEME in the field of CO 2 capture and storage. This programme aims at promoting the emergence of significant innovations, at developing the national technology portfolio, at identifying and reducing uncertainties related to exploitation, and at developing and strengthening its technological integration in manufacturing industry and energy sectors. While indicating the invested amount, research demonstrator projects are mentioned. Results obtained between 2007 and 2013 in different fields are briefly described: technical-economic studies or pre-feasibility studies, CO 2 capture (capture in post-combustion or in oxy-combustion), CO 2 geological storage (site selection, knowledge development on storage site sustainability, safety of CO 2 storage sites, monitoring of CO 2 storage sites, environmental impacts of storage sites), and issue of social feasibility of CO 2 capture and storage

Physicochemical effects of discrete CO2-SO2 mixtures on injection and storage in a sandstone aquifer

NARCIS (Netherlands)

Waldmann, S.; Hofstee, C.; Koenen, M.; Loeve, D.

2016-01-01

Geological storage of captured CO2, which typically will contain certain amounts of impurities, in salineaquifers is of potential to reduce greenhouse gas emissions into the atmosphere. The co-injection of theimpurity SO2has an effect on the chemical reactivity of the fluid and solid phases as well

Radiocarbon as a Reactive Tracer for Tracking Permanent CO₂ Storage in Basaltic Rocks

Energy Technology Data Exchange (ETDEWEB)

Matter, Juerg [Columbia Univ., New York, NY (United States); Stute, Martin [Columbia Univ., New York, NY (United States); Schlosser, Peter [Columbia Univ., New York, NY (United States); Broecker, Wallace [Columbia Univ., New York, NY (United States)

2015-09-30

In view of concerns about the long-term integrity and containment of CO₂ storage in geologic reservoirs, many efforts have been made to improve the monitoring, verification and accounting methods for geologically stored CO₂. Our project aimed to demonstrate that carbon-14 (¹⁴C) could be used as a reactive tracer to monitor geochemical reactions and evaluate the extent of mineral trapping of CO₂ in basaltic rocks. The capacity of a storage reservoir for mineral trapping of CO₂ is largely a function of host rock composition. Mineral carbonation involves combining CO₂ with divalent cations including Ca²⁺, Mg²⁺ and Fe²⁺. The most abundant geological sources for these cations are basaltic rocks. Based on initial storage capacity estimates, we know that basalts have the necessary capacity to store million to billion tons of CO₂ via in situ mineral carbonation. However, little is known about CO2-fluid-rock reactions occurring in a basaltic storage reservoir during and post-CO₂ injection. None of the common monitoring and verification techniques have been able to provide a surveying tool for mineral trapping. The most direct method for quantitative monitoring and accounting involves the tagging of the injected CO₂ with 14C because 14C is not present in deep geologic reservoirs prior to injection. Accordingly, we conducted two CO₂ injection tests at the CarbFix pilot injection site in Iceland to study the feasibility of 14C as a reactive tracer for monitoring CO₂-fluid-rock reactions and CO₂ mineralization. Our newly developed monitoring techniques, using 14C as a reactive tracer, have been successfully demonstrated. For the first time, permanent and safe disposal of CO₂ as environmentally benign carbonate minerals in basaltic rocks could be shown. Over 95% of the injected CO₂ at the Carb

Onshore/ Offshore Geologic Assessment for Carbon Storage in the Southeastern United States

Science.gov (United States)

Knapp, C. C.; Knapp, J. H.; Brantley, D.; Lakshmi, V.; Almutairi, K.; Almayahi, D.; Akintunde, O. M.; Ollmann, J.

2017-12-01

Eighty percent of the world's energy relies on fossil fuels and under increasingly stricter national and international regulations on greenhouse gas emissions storage of CO2 in geologic repositories seems to be not only a feasible, but also and vital solution for near/ mid-term reduction of carbon emissions. We have evaluated the feasibility of CO2 storage in saline formations of the Eastern North American Margin (ENAM) including (1) the Jurassic/Triassic (J/TR) sandstones of the buried South Georgia Rift (SGR) basin, and (2) the Mesozoic and Cenozoic geologic formations along the Mid- and South Atlantic seaboard. These analyses have included integration of subsurface geophysical data (2- and 3-D seismic surveys) with core samples, well logs as well as uses of geological databases and geospatial analysis leading to CO2 injection simulation models. ENAM is a complex and regionally extensive mature Mesozoic passive margin rift system encompassing: (1) a large volume and regional extent of related magmatism known as the Central Atlantic Magmatic Province (CAMP), (2) a complete stratigraphic column that records the post-rift evolution in several basins, (3) preserved lithospheric-scale pre-rift structures including Paleozoic sutures, and (4) a wide range of geological, geochemical, and geophysical studies both onshore and offshore. While the target reservoirs onshore show heterogeneity and a highly complex geologic evolution they also show promising conditions for significant safe CO2 storage away from the underground acquifers. Our offshore study (the Southeast Offshore Storage Resource Assessment - SOSRA) is focused on the outer continental shelf from North Carolina to the southern tip of Florida. Three old exploration wells are available to provide additional constraints on the seismic reflection profiles. Two of these wells (TRANSCO 1005-1 and COST GE-1) penetrate the pre-rift Paleozoic sedimentary formations while the EXXON 564-1 well penetrates the post

Status of knowledge on risks related to CO2 geological storage. Report nr 1: risks during the injection phase. Investigation report

International Nuclear Information System (INIS)

Gombert, Philippe; Thoraval, Alain

2010-01-01

Carbon capture and storage (CCS) is considered as a possibility to struggle against greenhouse effect and therefore against climate change. This process is here presented as comprising three main periods: exploitation during 40 to 50 years which itself comprises three phases (design, injection and closure), memory during about 300 years, and a long term period (700 to 800 years during which the existence of the storage and its associated risks will be forgotten). This study concerns the injection phase of the first period and some of its associated risks: leakages, thermal-hydro-mechanical-chemical disturbances at the vicinity of the storage. The report gives an overview of CO 2 geological capture and storage (capture, transport, injection, storage, foreseen storage media, nature of the injected fluid, regulations, returns on experience), identifies the associated risks, discusses issues of assessment of risks related to well leakages and to disturbances at the vicinity of the well (mechanical, physical and chemical, bacteriological risks)

Leveraging Regional Exploration to Develop Geologic Framework for CO2 Storage in Deep Formations in Midwestern United States

Energy Technology Data Exchange (ETDEWEB)

Neeraj Gupta

2009-09-30

Obtaining subsurface data for developing a regional framework for geologic storage of CO{sub 2} can require drilling and characterization in a large number of deep wells, especially in areas with limited pre-existing data. One approach for achieving this objective, without the prohibitive costs of drilling costly standalone test wells, is to collaborate with the oil and gas drilling efforts in a piggyback approach that can provide substantial cost savings and help fill data gaps in areas that may not otherwise get characterized. This leveraging with oil/gas drilling also mitigates some of the risk involved in standalone wells. This collaborative approach has been used for characterizing in a number of locations in the midwestern USA between 2005 and 2009 with funding from U.S. Department of Energy's National Energy Technology Laboratory (DOE award: DE-FC26-05NT42434) and in-kind contributions from a number of oil and gas operators. The results are presented in this final technical report. In addition to data collected under current award, selected data from related projects such as the Midwestern Regional Carbon Sequestration Partnership (MRCSP), the Ohio River Valley CO{sub 2} storage project at and near the Mountaineer Plant, and the drilling of the Ohio Stratigraphic well in Eastern Ohio are discussed and used in the report. Data from this effort are also being incorporated into the MRCSP geologic mapping. The project activities were organized into tracking and evaluation of characterization opportunities; participation in the incremental drilling, basic and advanced logging in selected wells; and data analysis and reporting. Although a large number of opportunities were identified and evaluated, only a small subset was carried into the field stage. Typical selection factors included reaching an acceptable agreement with the operator, drilling and logging risks, and extent of pre-existing data near the candidate wells. The region of study is primarily along

Potential for geological sequestration of CO{sub 2} in Switzerland - Final report; Studie zur Abschaetzung des Potenzials fuer CO{sub 2}-Sequestrierung in der Schweiz - Schlussbericht

Energy Technology Data Exchange (ETDEWEB)

Diamond, L. W.; Chevalier, G. [Institut fuer Geologie, Universitaet Bern, Bern (Switzerland); Leu, W. [Geoform AG, Geologische Beratungen und Studien, Villeneuve (former Minusio) (Switzerland)

2010-08-15

One approach to dispose of the greenhouse gas CO{sub 2} is to inject it into deep, porous geological formations, where is remains safely trapped over periods of many millennia. This report evaluates the potential for this option within Switzerland, based on a literature review. Only geological criteria for CO{sub 2} sequestration are taken into account, following international best-practice principles for reservoir safety. Simultaneous consideration of nine geological attributes (including faulting and natural seismicity) allows the sequestration potential to be mapped at a resolution of a few km{sup 2}, using a scale between 0 (negligible potential) and 1 (high potential). It is concluded that the crystalline rocks of the Alps and the sediments underlying the valleys of Valais, Ticino and Grisons are unsuitable for CO{sub 2} sequestration. However, the sedimentary rocks below the Central Plateau (and to lesser extent below the Jura Chain), locally show moderate to very good potential. At least four formations of porous sandstones and limestones (saline aquifers) underlie large areas of the Plateau within the technically favoured depth interval of 800-2500 m. Approximately 5000 km{sup 2} of the Plateau (mostly in the sector Fribourg-Olten-Lucerne) exhibits sequestration potentials above 0.6, offering a theoretical (unproven) storage capacity for approximately 2680 million tonnes of CO{sub 2}. From a purely geological point of view these results are promising. Although the high potentials do not guarantee the feasibility of CO{sub 2} sequestration, they serve as guides to areas that warrant detailed investigation. If this CO{sub 2} storage option is pursued in Switzerland, then more detailed geological investigations and a pilot study would be necessary to prove its feasibility. The assessed risks, leakage-monitoring procedures and non-geological criteria (proximity to CO{sub 2} point-sources, economics, conflicts of use of the subsurface, etc.) would have to be

The potential of near-surface geophysical methods in a hierarchical monitoring approach for the detection of shallow CO2 seeps at geological storage sites

Science.gov (United States)

Sauer, U.; Schuetze, C.; Dietrich, P.

2013-12-01

The MONACO project (Monitoring approach for geological CO2 storage sites using a hierarchic observation concept) aims to find reliable monitoring tools that work on different spatial and temporal scales at geological CO2 storage sites. This integrative hierarchical monitoring approach based on different levels of coverage and resolutions is proposed as a means of reliably detecting CO2 degassing areas at ground surface level and for identifying CO2 leakages from storage formations into the shallow subsurface, as well as CO2 releases into the atmosphere. As part of this integrative hierarchical monitoring concept, several methods and technologies from ground-based remote sensing (Open-path Fourier-transform infrared (OP-FTIR) spectroscopy), regional measurements (near-surface geophysics, chamber-based soil CO2 flux measurement) and local in-situ measurements (using shallow boreholes) will either be combined or used complementary to one another. The proposed combination is a suitable concept for investigating CO2 release sites. This also presents the possibility of adopting a modular monitoring concept whereby our monitoring approach can be expanded to incorporate other methods in various coverage scales at any temporal resolution. The link between information obtained from large-scale surveys and local in-situ monitoring can be realized by sufficient geophysical techniques for meso-scale monitoring, such as geoelectrical and self-potential (SP) surveys. These methods are useful for characterizing fluid flow and transport processes in permeable near-surface sedimentary layers and can yield important information concerning CO2-affected subsurface structures. Results of measurements carried out a natural analogue site in the Czech Republic indicate that the hierarchical monitoring approach represents a successful multidisciplinary modular concept that can be used to monitor both physical and chemical processes taking place during CO2 migration and seepage. The

Predicting long-term performance of engineered geologic carbon dioxide storage systems to inform decisions amidst uncertainty

Science.gov (United States)

Pawar, R.

2016-12-01

Risk assessment and risk management of engineered geologic CO2 storage systems is an area of active investigation. The potential geologic CO2 storage systems currently under consideration are inherently heterogeneous and have limited to no characterization data. Effective risk management decisions to ensure safe, long-term CO2 storage requires assessing and quantifying risks while taking into account the uncertainties in a storage site's characteristics. The key decisions are typically related to definition of area of review, effective monitoring strategy and monitoring duration, potential of leakage and associated impacts, etc. A quantitative methodology for predicting a sequestration site's long-term performance is critical for making key decisions necessary for successful deployment of commercial scale geologic storage projects where projects will require quantitative assessments of potential long-term liabilities. An integrated assessment modeling (IAM) paradigm which treats a geologic CO2 storage site as a system made up of various linked subsystems can be used to predict long-term performance. The subsystems include storage reservoir, seals, potential leakage pathways (such as wellbores, natural fractures/faults) and receptors (such as shallow groundwater aquifers). CO2 movement within each of the subsystems and resulting interactions are captured through reduced order models (ROMs). The ROMs capture the complex physical/chemical interactions resulting due to CO2 movement and interactions but are computationally extremely efficient. The computational efficiency allows for performing Monte Carlo simulations necessary for quantitative probabilistic risk assessment. We have used the IAM to predict long-term performance of geologic CO2 sequestration systems and to answer questions related to probability of leakage of CO2 through wellbores, impact of CO2/brine leakage into shallow aquifer, etc. Answers to such questions are critical in making key risk management

Geological storage of carbon dioxide: the role of sedimentary basins

International Nuclear Information System (INIS)

Gunter, W.D.; Bachu, S.

2001-01-01

Sedimentary basins, occuring throughout the world, are thick piles of geologically deposited sediments that are the hosts for fossil fuel deposits. They may become even more important in the future if their large storage capacity is utilized for disposing of carbon dioxide. Sedimentary basins are dynamic, in the sense that they have an intricate plumbing system defined by the location of high and low permeability strata that control the flow of fluids throughout the basins and define 'hydrogeological' traps. The most secure type of hydrogeological trapping is found in oil and gas reservoirs in the form of 'structural' or 'stratigraphic' traps, termed 'closed' hydrogeological traps which have held oil and gas for millions of years. Obviously, these would be very attractive for CO 2 storage due to their long history of containment. A second type of hydrogeological trapping has been recognized in aquifers of sedimentary basins that have slow flow rates. The pore space in such 'open' hydrogeological traps is usually filled with saline ground or formation water. A volume of CO 2 injected into a deep open hydrogeological trap can take over a million years to travel updip to reach the surface and be released to the atmosphere. Although the capacity of structural/stratigraphic traps for CO 2 storage is small relative to open hydrogeological traps in deep sedimentary basins, they are likely to be used first as they are known to be secure, having held oil and gas for geological time. As the capacity of closed traps is exhausted and more is learned about geochemical trapping, the large storage capacity available in open hydrogeological traps will be utilized where security of the geological storage of CO 2 can be enhanced by geochemical reactions of the CO 2 with basic silicate minerals to form carbonates. Potential short circuits to the surface through faults or abandoned wells must be located and their stability evaluated before injection of CO 2 . In any event, a

Stored CO2 and Methane Leakage Risk Assessment and Monitoring Tool Development: CO2 Capture Project Phase 2 (CCP2)

Energy Technology Data Exchange (ETDEWEB)

Dan Kieki

2008-09-30

The primary project goal is to develop and test tools for optimization of ECBM recovery and geologic storage of CO{sub 2} in coalbeds, in addition to tools for monitoring CO{sub 2} sequestration in coalbeds to support risk assessment. Three critical topics identified are (1) the integrity of coal bed methane geologic and engineered systems, (2) the optimization of the coal bed storage process, and (3) reliable monitoring and verification systems appropriate to the special conditions of CO{sub 2} storage and flow in coals.

Feasibility of CO2 storage in geothermal reservoirs example of the Paris Basin - France. Final report

International Nuclear Information System (INIS)

Barbier, J.; Robelin, C.; Kervevan, C.; Thiery, D.; Menjoz, A.; Matray, J.M.; Cotiche, C.; Herbrich, B.

2003-01-01

This study is realized in the framework of GESCO project, which aims to provide the first documentation that, for emission sources within selected key areas, sufficient geological storage capacity is available. Then the BRGM/ANTEA/CFG took care to provide: an inventory of the CO 2 emitters in France, an inventory of the main deep aquifers present in the Paris basin, an evaluation of the storage capacities of CO 2 in one of the four principal case-study, technical solutions for CO 2 injection in geothermal aquifers and an evaluation of the cost of CO 2 storage in such an aquifer. (A.L.B.)

GHGT-10 : Assessing the integrity of fault- and top seals at CO2 storage sites

NARCIS (Netherlands)

Orlic, B.; Heege J.H. ter; Wassing, B.

2011-01-01

Induced stress changes due to CO2 injection into geological reservoirs can mechanically damage bounding fault- and top seals creating preferential pathways for CO2 migration from the containment or trigger existing faults causing seismic activity at storage sites. In this paper we present

Geoelectric Monitoring of geological CO2 storage at Ketzin, Germany (CO2SINK project): Downhole and Surface-Downhole measurements

Science.gov (United States)

Kiessling, D.; Schuett, H.; Schoebel, B.; Krueger, K.; Schmidt-Hattenberger, C.; Schilling, F.

2009-04-01

Numerical models of the CO2 storage experiment CO2SINK (CO2 Storage by Injection into a Natural Saline Aquifer at Ketzin), where CO2 is injected into a deep saline aquifer at roughly 650 m depth, yield a CO2 saturation of approximately 50% for large parts of the plume. Archie's equation predicts an increase of the resistivity by a factor of approximately 3 to 4 for the reservoir sandstone, and laboratory tests on Ketzin reservoir samples support this prediction. Modeling results show that tracking the CO2 plume may be doable with crosshole resistivity surveys under these conditions. One injection well and two observation wells were drilled in 2007 to a depth of about 800 m and were completed with "smart" casings, arranged L-shaped with distances of 50 m and 100 m. 45 permanent ring-shaped steel electrodes were attached to the electrically insulated casings of the three Ketzin wells at 590 m to 735 m depth with a spacing of about 10 m. It is to our knowledge the deepest permanent vertical electrical resistivity array (VERA) worldwide. The electrodes are connected to the current power supply and data registration units at the surface through custom-made cables. This deep electrode array allows for the registration of electrical resistivity tomography (ERT) data sets at basically any desired repetition rate and at very low cost, without interrupting the injection operations. The installation of all 45 electrodes succeeded. The electrodes are connected to the electrical cable, and the insulated casing stood undamaged. Even after 2-odd years under underground conditions only 6 electrodes are in a critical state now, caused by corrosion effects. In the framework of the COSMOS project (CO2-Storage, Monitoring and Safety Technology), supported by the German "Geotechnologien" program, the geoelectric monitoring has been performed. The 3D crosshole time-laps measurements are taken using dipole-dipole configurations. The data was inverted using AGI EarthImager 3D to obtain 3D

Inverse Problem for 3D coupled Flow-Geomechanics Models and Induced Seismicity: Application to Subsurface Characterization and Seismicity Forecasting in Geologic CO2 Storage

Science.gov (United States)

Castineira, D.; Jha, B.; Juanes, R.

2016-12-01

Carbon Capture and Sequestration (CCS) is regarded as a promising technology to mitigate rising CO2 concentrations in the atmosphere from industrial emissions. However, as a result of the inherent uncertainty that is present in geological structures, assessing the stability of geological faults and quantifying the potential for induced seismicity is a fundamental challenge for practical implementation of CCS. Here we present a formal framework for the solution of the inverse problem associated with coupled flow and geomechanics models of CO2 injection and subsurface storage. Our approach builds from the application of Gaussian Processes, MCMC and posterior predictive analysis to evaluate relevant earthquake attributes (earthquake time, location and magnitude) in 3D synthetic models of CO2 storage under geologic, observational and operational uncertainty. In our approach, we first conduct hundreds of simulations of a high-fidelity 3D computational model for CO2 injection into a deep saline aquifer, dominated by an anticline structure and a fault. This ensemble of realizations accounts for uncertainty in the model parameters (including fault geomechanical and rock properties) and observations (earthquake time, location and magnitude). We apply Gaussian processes (GP) to generate a valid surrogate that closely approximates the behavior of the high fidelity (and computationally intensive) model, and apply hyperparameter optimization and cross-validation techniques in the solution of this multidimensional data-fit problem. The net result of this process is the generation of a fast model that can be effectively used for Bayesian analysis. We then implement Markov chain Monte Carlo (MCMC) to determine the posterior distribution of the model uncertain parameters (given some prior distributions for those parameters and given the likelihood defined in this case by the GP model). Our results show that the resulting posterior distributions correctly converge towards the "true

Geologic CO2 Sequestration: Predicting and Confirming Performance in Oil Reservoirs and Saline Aquifers

Science.gov (United States)

Johnson, J. W.; Nitao, J. J.; Newmark, R. L.; Kirkendall, B. A.; Nimz, G. J.; Knauss, K. G.; Ziagos, J. P.

2002-05-01

Reducing anthropogenic CO2 emissions ranks high among the grand scientific challenges of this century. In the near-term, significant reductions can only be achieved through innovative sequestration strategies that prevent atmospheric release of large-scale CO2 waste streams. Among such strategies, injection into confined geologic formations represents arguably the most promising alternative; and among potential geologic storage sites, oil reservoirs and saline aquifers represent the most attractive targets. Oil reservoirs offer a unique "win-win" approach because CO2 flooding is an effective technique of enhanced oil recovery (EOR), while saline aquifers offer immense storage capacity and widespread distribution. Although CO2-flood EOR has been widely used in the Permian Basin and elsewhere since the 1980s, the oil industry has just recently become concerned with the significant fraction of injected CO2 that eludes recycling and is therefore sequestered. This "lost" CO2 now has potential economic value in the growing emissions credit market; hence, the industry's emerging interest in recasting CO2 floods as co-optimized EOR/sequestration projects. The world's first saline aquifer storage project was also catalyzed in part by economics: Norway's newly imposed atmospheric emissions tax, which spurred development of Statoil's unique North Sea Sleipner facility in 1996. Successful implementation of geologic sequestration projects hinges on development of advanced predictive models and a diverse set of remote sensing, in situ sampling, and experimental techniques. The models are needed to design and forecast long-term sequestration performance; the monitoring techniques are required to confirm and refine model predictions and to ensure compliance with environmental regulations. We have developed a unique reactive transport modeling capability for predicting sequestration performance in saline aquifers, and used it to simulate CO2 injection at Sleipner; we are now

Leakage Risk Assessment for a Potential CO2 Storage Project in Saskatchewan, Canada

Energy Technology Data Exchange (ETDEWEB)

Houseworth, J.E.; Oldenburg, C.M.; Mazzoldi, A.; Gupta, A.K.; Nicot, J.-P.; Bryant, S.L.

2011-05-01

A CO{sub 2} sequestration project is being considered to (1) capture CO{sub 2} emissions from the Consumers Cooperative Refineries Limited at Regina, Saskatchewan and (2) geologically sequester the captured CO{sub 2} locally in a deep saline aquifer. This project is a collaboration of several industrial and governmental organizations, including the Petroleum Technology Research Centre (PTRC), Sustainable Development Technology Canada (SDTC), SaskEnvironment Go Green Fund, SaskPower, CCRL, Schlumberger Carbon Services, and Enbridge. The project objective is to sequester 600 tonnes CO{sub 2}/day. Injection is planned to start in 2012 or 2013 for a period of 25 years for a total storage of approximately 5.5 million tonnes CO{sub 2}. This report presents an assessment of the leakage risk of the proposed project using a methodology known as the Certification Framework (CF). The CF is used for evaluating CO{sub 2} leakage risk associated with geologic carbon sequestration (GCS), as well as brine leakage risk owing to displacement and pressurization of brine by the injected CO{sub 2}. We follow the CF methodology by defining the entities (so-called Compartments) that could be impacted by CO{sub 2} leakage, the CO{sub 2} storage region, the potential for leakage along well and fault pathways, and the consequences of such leakage. An understanding of the likelihood and consequences of leakage forms the basis for understanding CO{sub 2} leakage risk, and forms the basis for recommendations of additional data collection and analysis to increase confidence in the risk assessment.

South Louisiana Enhanced Oil Recovery/Sequestration R&D Project Small Scale Field Tests of Geologic Reservoir Classes for Geologic Storage

Energy Technology Data Exchange (ETDEWEB)

Hite, Roger [Blackhorse Energy LLC, Houston, TX (United States)

2016-10-01

The project site is located in Livingston Parish, Louisiana, approximately 26 miles due east of Baton Rouge. This project proposed to evaluate an early Eocene-aged Wilcox oil reservoir for permanent storage of CO₂. Blackhorse Energy, LLC planned to conduct a parallel CO₂ oil recovery project in the First Wilcox Sand. The primary focus of this project was to examine and prove the suitability of South Louisiana geologic formations for large-scale geologic sequestration of CO₂ in association with enhanced oil recovery applications. This was to be accomplished through the focused demonstration of small-scale, permanent storage of CO₂ in the First Wilcox Sand. The project was terminated at the request of Blackhorse Energy LLC on October 22, 2014.

Quantification of oil recovery efficiency, CO 2 storage potential, and fluid-rock interactions by CWI in heterogeneous sandstone oil reservoirs

DEFF Research Database (Denmark)

Seyyedi, Mojtaba; Sohrabi, Mehran; Sisson, Adam

2017-01-01

Significant interest exists in improving recovery from oil reservoirs while addressing concerns about increasing CO2 concentrations in the atmosphere. The combination of Enhanced Oil Recovery (EOR) and safe geologic storage of CO2 in oil reservoirs is appealing and can be achieved by carbonated (CO...... for oil recovery and CO2 storage potential on heterogeneous cores. Since not all the oil reservoirs are homogenous, understanding the potential of CWI as an integrated EOR and CO2 storage scenario in heterogeneous oil reservoirs is essential....

Chemistry of fluids from a natural analogue for a geological CO{sub 2} storage site (Montmiral, France): Lessons for CO{sub 2}-water-rock interaction assessment and monitoring

Energy Technology Data Exchange (ETDEWEB)

Pauwels, Helene [BRGM - Water Division, 3, av Claude Guillemin, 45060 Orleans Cedex (France)], E-mail: h.pauwels@brgm.fr; Gaus, Irina; Le Nindre, Yves Michel [BRGM - Water Division, 3, av Claude Guillemin, 45060 Orleans Cedex (France); Pearce, Jonathan [British Geological Survey, Kingsley Dunham Centre, Keyworth, Nottingham NG125GG (United Kingdom); Czernichowski-Lauriol, Isabelle [BRGM - Water Division, 3, av Claude Guillemin, 45060 Orleans Cedex (France)

2007-12-15

Chemical and isotope studies of natural CO{sub 2} accumulations aid in assessing the chemical effects of CO{sub 2} on rock and thus provide a potential for understanding the long-term geochemical processes involved in CO{sub 2} geological storage. Several natural CO{sub 2} accumulations were discovered during gas and oil exploration in France's carbogaseous peri-Alpine province (south-eastern France) in the 1960s. One of these, the Montmiral accumulation at a depth of more than 2400 m, is currently being exploited. The chemical composition of the water collected at the wellhead has changed in time and the final salinity exceeds 75 g/L. These changes in time can be explained by assuming that the fraction of the reservoir brine in the recovered brine-CO{sub 2}-H{sub 2}O mixture varies, resulting in variable proportions of H{sub 2}O and brine in the sampled water. The proportions can be estimated in selected samples due to the availability of gas and water flowrate data. These data enabled the reconstruction of the chemical and isotope composition of the brine. The proportions of H{sub 2}O and brine can also be estimated from isotope ({delta}{sup 2}H, {delta}{sup 18}O) composition of collected water and {delta}{sup 18}O of the sulfates or CO{sub 2}. The reconstituted brine has a salinity of more than 85 g/L and, according to its Br{sup -} content and isotope ({delta}{sup 2}H, {delta}{sup 18}O, {delta}{sup 34}S) composition, originates from an evaporated Triassic seawater that underwent dilution by meteoric water. The reconstitution of the brine's chemical composition enabled an evaluation of the CO{sub 2}-water-rock interactions based on: (1) mineral saturation indices; and (2) comparison with initial evaporated Triassic seawater. Dissolution of K- and SO{sub 4}-containing minerals such as K-feldspar and anhydrite, and precipitation of Ca and Mg containing minerals that are able to trap CO{sub 2} (carbonates) are highlighted. The changes in concentration of

Petrophysical Characterization of Arroyal Antiform Geological Formations (Aguilar de Campoo, Palencia) as a Storage and Seal Rocks in the Technology Development Plant for Geological CO{sub 2} Storage (Hontomin, Burgos); Caracterizacin Petrofisica de las Formaciones Geologicas de la Antiforma de Arroyal (Aguilar de Campoo, Palencia) como Posibles Rocas Almacen y Sello en la Planta de Desarrollo Tecnologico de Almacenamiento Geologico de CO{sub 2} (Hontomin, Burgos)

Energy Technology Data Exchange (ETDEWEB)

Campos, R.; Barrios, I.; Gonzalez, A. M.; Pelayo, M.; Saldana, R.

2011-05-13

The geological storage program of Energy City Foundation is focusing its research effort in the Technological Development and Research Plant in Hontomin (Burgos) start off. The present report shows the petrophysical characterization of of the Arroyal antiform geological formations since they are representatives, surface like, of the storage and seal formations that will be found in the CO{sub 2} injection plant in Hontomin. In this petrophysics characterization has taken place the study of matrix porosity, specific surface and density of the storage and seal formations. Mercury intrusion porosimetry, N{sub 2} adsorption and He pycnometry techniques have been used for the characterization. Furthermore, it has carried out a mineralogical analysis of the seal materials by RX diffraction. (Author) 26 refs.

Potential evaluation of CO2 storage and enhanced oil recovery of tight oil reservoir in the Ordos Basin, China.

Science.gov (United States)

Tian, Xiaofeng; Cheng, Linsong; Cao, Renyi; Zhang, Miaoyi; Guo, Qiang; Wang, Yimin; Zhang, Jian; Cui, Yu

2015-07-01

Carbon -di-oxide (CO2) is regarded as the most important greenhouse gas to accelerate climate change and ocean acidification. The Chinese government is seeking methods to reduce anthropogenic CO2 gas emission. CO2 capture and geological storage is one of the main methods. In addition, injecting CO2 is also an effective method to replenish formation energy in developing tight oil reservoirs. However, exiting methods to estimate CO2 storage capacity are all based on the material balance theory. This was absolutely correct for normal reservoirs. However, as natural fractures widely exist in tight oil reservoirs and majority of them are vertical ones, tight oil reservoirs are not close. Therefore, material balance theory is not adaptive. In the present study, a new method to calculate CO2 storage capacity is presented. The CO2 effective storage capacity, in this new method, consisted of free CO2, CO2 dissolved in oil and CO2 dissolved in water. Case studies of tight oil reservoir from Ordos Basin was conducted and it was found that due to far lower viscosity of CO2 and larger solubility in oil, CO2 could flow in tight oil reservoirs more easily. As a result, injecting CO2 in tight oil reservoirs could obviously enhance sweep efficiency by 24.5% and oil recovery efficiency by 7.5%. CO2 effective storage capacity of Chang 7 tight oil reservoir in Longdong area was 1.88 x 10(7) t. The Chang 7 tight oil reservoir in Ordos Basin was estimated to be 6.38 x 10(11) t. As tight oil reservoirs were widely distributed in Songliao Basin, Sichuan Basin and so on, geological storage capacity of CO2 in China is potential.

The Ohio River Valley CO2 Storage Project AEP Mountaineer Plant, West Virginia Numerical Simulation and Risk Assessment Report

Energy Technology Data Exchange (ETDEWEB)

Neeraj Gupta

2008-03-31

A series of numerical simulations of carbon dioxide (CO{sub 2}) injection were conducted as part of a program to assess the potential for geologic sequestration in deep geologic reservoirs (the Rose Run and Copper Ridge formations), at the American Electric Power (AEP) Mountaineer Power Plant outside of New Haven, West Virginia. The simulations were executed using the H{sub 2}O-CO{sub 2}-NaCl operational mode of the Subsurface Transport Over Multiple Phases (STOMP) simulator (White and Oostrom, 2006). The objective of the Rose Run formation modeling was to predict CO{sub 2} injection rates using data from the core analysis conducted on the samples. A systematic screening procedure was applied to the Ohio River Valley CO{sub 2} storage site utilizing the Features, Elements, and Processes (FEP) database for geological storage of CO{sub 2} (Savage et al., 2004). The objective of the screening was to identify potential risk categories for the long-term geological storage of CO{sub 2} at the Mountaineer Power Plant in New Haven, West Virginia. Over 130 FEPs in seven main classes were assessed for the project based on site characterization information gathered in a geological background study, testing in a deep well drilled on the site, and general site conditions. In evaluating the database, it was apparent that many of the items were not applicable to the Mountaineer site based its geologic framework and environmental setting. Nine FEPs were identified for further consideration for the site. These FEPs generally fell into categories related to variations in subsurface geology, well completion materials, and the behavior of CO{sub 2} in the subsurface. Results from the screening were used to provide guidance on injection system design, developing a monitoring program, performing reservoir simulations, and other risk assessment efforts. Initial work indicates that the significant FEPs may be accounted for by focusing the storage program on these potential issues. The

Modeling geologic storage of carbon dioxide: Comparison of non-hysteretic and hysteretic characteristic curves

International Nuclear Information System (INIS)

Doughty, Christine

2007-01-01

Numerical models of geologic storage of carbon dioxide (CO 2 ) in brine-bearing formations use characteristic curves to represent the interactions of non-wetting-phase CO 2 and wetting-phase brine. When a problem includes both injection of CO 2 (a drainage process) and its subsequent post-injection evolution (a combination of drainage and wetting), hysteretic characteristic curves are required to correctly capture the behavior of the CO 2 plume. In the hysteretic formulation, capillary pressure and relative permeability depend not only on the current grid-block saturation, but also on the history of the saturation in the grid block. For a problem that involves only drainage or only wetting, a non-hysteretic formulation, in which capillary pressure and relative permeability depend only on the current value of the grid-block saturation, is adequate. For the hysteretic formulation to be robust computationally, care must be taken to ensure the differentiability of the characteristic curves both within and beyond the turning-point saturations where transitions between branches of the curves occur. Two example problems involving geologic CO 2 storage are simulated with TOUGH2, a multiphase, multicomponent code for flow and transport through geological media. Both non-hysteretic and hysteretic formulations are used, to illustrate the applicability and limitations of non-hysteretic methods. The first application considers leakage of CO 2 from the storage formation to the ground surface, while the second examines the role of heterogeneity within the storage formation

Ganglion dynamics and its implications to geologic carbon dioxide storage.

Science.gov (United States)

Wang, Yifeng; Bryan, Charles; Dewers, Thomas; Heath, Jason E; Jove-Colon, Carlos

2013-01-02

Capillary trapping of a nonwetting fluid phase in the subsurface has been considered as an important mechanism for geologic storage of carbon dioxide (CO(2)). This mechanism can potentially relax stringent requirements for the integrity of cap rocks for CO(2) storage and therefore can significantly enhance storage capacity and security. We here apply ganglion dynamics to understand the capillary trapping of supercritical CO(2) (scCO(2)) under relevant reservoir conditions. We show that, by breaking the injected scCO(2) into small disconnected ganglia, the efficiency of capillary trapping can be greatly enhanced, because the mobility of a ganglion is inversely dependent on its size. Supercritical CO(2) ganglia can be engineered by promoting CO(2)-water interface instability during immiscible displacement, and their size distribution can be controlled by injection mode (e.g., water-alternating-gas) and rate. We also show that a large mobile ganglion can potentially break into smaller ganglia due to CO(2)-brine interface instability during buoyant rise, thus becoming less mobile. The mobility of scCO(2) in the subsurface is therefore self-limited. Vertical structural heterogeneity within a reservoir can inhibit the buoyant rise of scCO(2) ganglia. The dynamics of scCO(2) ganglia described here provides a new perspective for the security and monitoring of subsurface CO(2) storage.

SUBTASK 2.19 – OPERATIONAL FLEXIBILITY OF CO2 TRANSPORT AND STORAGE

Energy Technology Data Exchange (ETDEWEB)

Jensen, Melanie; Schlasner, Steven; Sorensen, James; Hamling, John

2014-12-31

experts represented a range of disciplines and hailed from North America and Europe. Major findings of the study are that compression and transport of CO2 for enhanced oil recovery (EOR) purposes in the United States has shown that impurities are not likely to cause transport problems if CO2 stream composition standards are maintained and pressures are kept at 10.3 MPa or higher. Cyclic, or otherwise intermittent, CO2 supplies historically have not impacted in-field distribution pipeline networks, wellbore integrity, or reservoir conditions. The U.S. EOR industry has demonstrated that it is possible to adapt to variability and intermittency in CO2 supply through flexible operation of the pipeline and geologic storage facility. This CO2 transport and injection experience represents knowledge that can be applied in future CCS projects. A number of gaps in knowledge were identified that may benefit from future research and development, further enhancing the possibility for widespread application of CCS. This project was funded through the Energy & Environmental Research Center–U.S. Department of Energy Joint Program on Research and Development for Fossil Energy-Related Resources Cooperative Agreement No. DE-FC26-08NT43291. Nonfederal funding was provided by the IEA Greenhouse Gas R&D Programme.

Leakage and Seepage of CO2 from Geologic Carbon Sequestration Sites: CO2 Migration into Surface Water

International Nuclear Information System (INIS)

Oldenburg, Curt M.; Lewicki, Jennifer L.

2005-01-01

Geologic carbon sequestration is the capture of anthropogenic carbon dioxide (CO 2 ) and its storage in deep geologic formations. One of the concerns of geologic carbon sequestration is that injected CO 2 may leak out of the intended storage formation, migrate to the near-surface environment, and seep out of the ground or into surface water. In this research, we investigate the process of CO 2 leakage and seepage into saturated sediments and overlying surface water bodies such as rivers, lakes, wetlands, and continental shelf marine environments. Natural CO 2 and CH 4 fluxes are well studied and provide insight into the expected transport mechanisms and fate of seepage fluxes of similar magnitude. Also, natural CO 2 and CH 4 fluxes are pervasive in surface water environments at levels that may mask low-level carbon sequestration leakage and seepage. Extreme examples are the well known volcanic lakes in Cameroon where lake water supersaturated with respect to CO 2 overturned and degassed with lethal effects. Standard bubble formation and hydrostatics are applicable to CO 2 bubbles in surface water. Bubble-rise velocity in surface water is a function of bubble size and reaches a maximum of approximately 30 cm s -1 at a bubble radius of 0.7 mm. Bubble rise in saturated porous media below surface water is affected by surface tension and buoyancy forces, along with the solid matrix pore structure. For medium and fine grain sizes, surface tension forces dominate and gas transport tends to occur as channel flow rather than bubble flow. For coarse porous media such as gravels and coarse sand, buoyancy dominates and the maximum bubble rise velocity is predicted to be approximately 18 cm s -1 . Liquid CO 2 bubbles rise slower in water than gaseous CO 2 bubbles due to the smaller density contrast. A comparison of ebullition (i.e., bubble formation) and resulting bubble flow versus dispersive gas transport for CO 2 and CH 4 at three different seepage rates reveals that

Thermo-hydro-chemical performance assessment of CO2 storage in saline aquifer

International Nuclear Information System (INIS)

Le Gallo, Y.; Trenty, L.; Michel, A.

2007-01-01

Research and development methodologies for the storage of CO 2 in geological formation are in developing over the last 10 years. In this context, numerical simulators are the practical tools to understand the physical processes involved by acid gas injection and evaluate the long term stability of the storage. CO 2 storage models can be seen as a mix between two types of models: a reservoir model coupling multiphase flow in porous media with local phase equilibrium and a hydrogeochemical model coupling transport in aqueous phase with local chemical equilibrium and kinetic reaction laws. A 3D-multiphase model, COORES, was built to assess the influence of different driving forces both hydrodynamic and geomechanics as well as geochemical on the CO 2 plume behavior during injection and storage (1000 years). Different coupling strategies were used to model these phenomena: - pressure, temperature and diffusion are solved implicitly for better numerical stability; - geochemical reactions involve heterogeneous kinetically-controlled reactions between the host rock and the CO 2 -rich aqueous phase which imply an implicit coupling with fluid flow; From the assumed initial mineral composition (6 minerals), aqueous species (10 chemical elements and 37 aqueous species), the geochemical alteration of the host rocks (sand and shale) is directly linked with the CO 2 plume evolution. A performance assessment using an experimental design approach is used to quantify the different driving forces and parameter influences. In the case of CO 2 injection in a saline quartz rich aquifer used to illustrate the model capabilities, the geochemical changes of the host rock have a small influence on the CO 2 distribution at the end of storage life (here 1000 years) compared to the other hydrodynamic mechanisms: free CO 2 (gas or supercritical), or trapped (capillary and in-solution). (authors)

Strategic use of the underground for an energy mix plan, synergies among CO2 and CH4 Geological Storage and Geothermal Energy: Italian Energy review and Latium case study

Science.gov (United States)

Procesi, M.; Cantucci, B.; Buttinelli, M.; Armezzani, G.; Quattrocchi, F.

2012-04-01

Since the world-wide energy demand has been growing so much in the last years, it is necessary to develop a strategic mix-energy plan to supply low GHG (GreenHouseGas) emissions energy and solve the problem of CO2 emission increasing. A recent study published by European Commission shows that, if existing trends continue, by 2050 CO2 emissions will be unsustainably high: 900-1000 parts per million by volume. The European Commission in 2007 underline the necessity to elaborate, at European level, a Strategic Energy Technology Plan focused on non-carbon or reduced-carbon sources of energy, as renewable energies, CO2 capture and storage technologies, smart energy networks and energy efficiency and savings. Future scenarios for 2030 elaborated by the International Energy Agency (IEA) shows as a mix energy plan could reduce the global CO2 emissions from 27Gt to 23 Gt (about 15%). A strategic use of the underground in terms of: - development of CCS (Carbon dioxide Capture and Storage) associated to fossil fuel combustion; - increase of CH4 geological storage sites; - use of renewable energies as geothermic for power generation; could open a new energy scenario, according to the climate models published by IPCC. Nowadays CCS market is mainly developed in USA and Canada, but still not much accounted in Europe. In Italy there aren't active CCS projects, even if potential areas have been already identified. Many CH4 storage sites are located in Northern America, while other are present in Europe and Italy, but the number of sites is limited despite the huge underground potentiality. In Italy the power generation from geothermal energy comes exclusively from Tuscany (Larderello-Travale and Mt. Amiata geothermal fields) despite the huge potentiality of other regions as Latium, Campania and Sicily (Central and South Italy). The energy deficit and the relevant CO2 emissions represent a common status for many Italian regions, especially for the Latium Region. This suggests that a

Geologic CO₂ Sequestration Potential of 42 California Power Plant Sites: A Status Report to WESTCARB

Energy Technology Data Exchange (ETDEWEB)

Myers, Katherine B.L. [Lawrence Livermore National Lab. (LLNL), Livermore, CA (United States); Wagoner, J. L. [Lawrence Livermore National Lab. (LLNL), Livermore, CA (United States)

2011-06-15

Forty-two California natural gas combined-cycle (NGCC) power plant sites were evaluated for geologic carbon dioxide (CO₂) sequestration potential. The following data were collected in order to gauge the sequestration potential of each power plant site: nearest potential CO₂ sink, proximity to oil or gas fi elds, subsurface geology, surface expression of nearby faults, and subsurface water. The data for each site were compiled into a one-page, standalone profi le to serve as a quick reference for future decision-makers. A subset of these data was compiled into a summary table for easy comparison of all 42 sites. Decision-makers will consider the geologic CO₂ sequestration potential of each power plant in concert with its CO₂ capture potential and will select the most suitable sites for a future carbon capture and storage project. Once the most promising sites are selected, Lawrence Livermore National Laboratory (LLNL) will conduct additional geologic research in order to construct a detailed 3D geologic model for those sites.

Clean coal technologies. The capture and geological storage of CO2 - Panorama 2008

International Nuclear Information System (INIS)

2008-01-01

There is no longer any doubt about the connection between carbon dioxide emissions of human origin and global warming. Nearly 40% of world CO 2 emissions are generated by the electricity production sector, in which the combustion of coal - developing at a roaring pace, especially in China - accounts for a good proportion of the total. At a time when the reduction of greenhouse gases has become an international priority, this growth is a problem. Unless CO 2 capture and storage technologies are implemented, it will be very difficult to contain global warming

A CO2-storage supply curve for North America and its implications for the deployment of carbon dioxide capture and storage systems

International Nuclear Information System (INIS)

Dooley, J.J.; Bachu, S.; Gupta, N.; Gale, J.

2005-01-01

This paper presented a highly disaggregated estimate of carbon dioxide (CO 2 )-storage capacity of more than 330 onshore geological reservoirs across the United States and Canada. The demand placed upon these reservoirs by thousands of existing large anthropogenic CO 2 point sources was also reviewed based on a newly developed methodology for estimating the effective storage capacities of deep saline formations, depleted oil and gas reservoirs, and deep unmineable coal seams. This analysis was based on matching the identified point sources with candidate storage reservoirs. By incorporating the updated source and reservoir data into the Battelle CO 2 -GIS, a series of pairwise costs for transporting CO 2 from sites of anthropogenic CO 2 sources was calculated along with the net cost of storing it in each of the candidate reservoirs within a specified distance of the point source. Results indicate a large and variably distributed North American storage capacity of at least 3,800 gigatonnes of CO 2 , with deep saline formations accounting for most of this capacity. A geospatial and techno-economic database of 2,082 anthropogenic CO 2 point sources in North America, each with annual emissions greater than 100,000 tonnes of CO 2 , was also refined. Sensitivities examined for the CO 2 -storage cost curve focused on high/low oil and gas prices; the maximum allowed distance between source and reservoir; and, the infrastructure costs associated with CO 2 -driven hydrocarbon recovery. 20 refs., 5 figs

Numerical simulation methods applied to injection and storage of CO{sub 2} in saline aquifers; Metodos de simulacion numerica aplicados a la inyeccion y almacenamiento de CO{sub 2} en formaciones salinas

Energy Technology Data Exchange (ETDEWEB)

Arjona Garcia-Borreguero, J.; Rodriguez Pons-Esparver, R.; Iglesias Lopez, A.

2015-07-01

One of the Climate Change mitigation proposals suggested by the IPCC (Intergovernmental Panel on Climate Change) in its Synthesis Report 2007 involves the launch of applications for capturing and storing carbon dioxide, existing three different geological structures suitable for gas storage: oil and gas depleted reservoirs, useless coal layers and deep saline structures. In case of deep saline structures, the main problem to prepare a study of CO{sub 2} storage is the difficulty of obtaining geological data for some selected structure with characteristics that could be suitable for injection and gas storage. According to this situation, the solution to analyze the feasibility of a storage project in a geological structure will need numerical simulation from a 3D terrain model. Numerical methods allow the simulation of the carbon dioxide filling in saline structures from a well, used to inject gas with a particular flow. This paper presents a methodology to address the modeling and simulation process of CO{sub 2} injection into deep saline aquifers. (Author)

Developing a Comprehensive Risk Assessment Framework for Geological Storage CO₂

Energy Technology Data Exchange (ETDEWEB)

Duncan, Ian [Univ. of Texas, Austin, TX (United States)

2014-08-31

The operational risks for CCS projects include: risks of capturing, compressing, transporting and injecting CO₂; risks of well blowouts; risk that CO₂ will leak into shallow aquifers and contaminate potable water; and risk that sequestered CO₂ will leak into the atmosphere. This report examines these risks by using information on the risks associated with analogue activities such as CO₂ based enhanced oil recovery (CO₂-EOR), natural gas storage and acid gas disposal. We have developed a new analysis of pipeline risk based on Bayesian statistical analysis. Bayesian theory probabilities may describe states of partial knowledge, even perhaps those related to non-repeatable events. The Bayesian approach enables both utilizing existing data and at the same time having the capability to adsorb new information thus to lower uncertainty in our understanding of complex systems. Incident rates for both natural gas and CO₂ pipelines have been widely used in papers and reports on risk of CO₂ pipelines as proxies for the individual risk created by such pipelines. Published risk studies of CO₂ pipelines suggest that the individual risk associated with CO2 pipelines is between 10^-3 and 10^-4, which reflects risk levels approaching those of mountain climbing, which many would find unacceptably high. This report concludes, based on a careful analysis of natural gas pipeline failures, suggests that the individual risk of CO₂ pipelines is likely in the range of 10-6 to 10-7, a risk range considered in the acceptable to negligible range in most countries. If, as is commonly thought, pipelines represent the highest risk component of CCS outside of the capture plant, then this conclusion suggests that most (if not all) previous quantitative- risk assessments of components of CCS may be orders of magnitude to high. The potential lethality of unexpected CO₂ releases

Intelligent monitoring system for real-time geologic CO2 storage, optimization and reservoir managemen

Science.gov (United States)

Dou, S.; Commer, M.; Ajo Franklin, J. B.; Freifeld, B. M.; Robertson, M.; Wood, T.; McDonald, S.

2017-12-01

Archer Daniels Midland Company's (ADM) world-scale agricultural processing and biofuels production complex located in Decatur, Illinois, is host to two industrial-scale carbon capture and storage projects. The first operation within the Illinois Basin-Decatur Project (IBDP) is a large-scale pilot that injected 1,000,000 metric tons of CO2 over a three year period (2011-2014) in order to validate the Illinois Basin's capacity to permanently store CO2. Injection for the second operation, the Illinois Industrial Carbon Capture and Storage Project (ICCS), started in April 2017, with the purpose of demonstrating the integration of carbon capture and storage (CCS) technology at an ethanol plant. The capacity to store over 1,000,000 metric tons of CO2 per year is anticipated. The latter project is accompanied by the development of an intelligent monitoring system (IMS) that will, among other tasks, perform hydrogeophysical joint analysis of pressure, temperature and seismic reflection data. Using a preliminary radial model assumption, we carry out synthetic joint inversion studies of these data combinations. We validate the history-matching process to be applied to field data once CO2-breakthrough at observation wells occurs. This process will aid the estimation of permeability and porosity for a reservoir model that best matches monitoring observations. The reservoir model will further be used for forecasting studies in order to evaluate different leakage scenarios and develop appropriate early-warning mechanisms. Both the inversion and forecasting studies aim at building an IMS that will use the seismic and pressure-temperature data feeds for providing continuous model calibration and reservoir status updates.

Potential impacts on groundwater resources of deep CO2 storage: natural analogues for assessing potential chemical effects

Science.gov (United States)

Lions, J.; Gale, I.; May, F.; Nygaard, E.; Ruetters, H.; Beaubien, S.; Sohrabi, M.; Hatzignatiou, D. G.; CO2GeoNet Members involved in the present study Team

2011-12-01

Carbon dioxide Capture and Storage (CCS) is considered as one of the promising options for reducing atmospheric emissions of CO2 related to human activities. One of the main concerns associated with the geological storage of CO2 is that the CO2 may leak from the intended storage formation, migrate to the near-surface environment and, eventually, escape from the ground. This is a concern because such leakage may affect aquifers overlying the storage site and containing freshwater that may be used for drinking, industry and agriculture. The IEA Greenhouse Gas R&D Programme (IEAGHG) recently commissioned the CO2GeoNet Association to undertake a review of published and unpublished literature on this topic with the aim of summarizing 'state of the art' knowledge and identifying knowledge gaps and research priorities in this field. Work carried out by various CO2GeoNet members was also used in this study. This study identifies possible areas of conflict by combining available datasets to map the global and regional superposition of deep saline formations (DSF) suitable for CO2 storage and overlying fresh groundwater resources. A scenario classification is developed for the various geological settings where conflict could occur. The study proposes two approaches to address the potential impact mechanisms of CO2 storage projects on the hydrodynamics and chemistry of shallow groundwater. The first classifies and synthesizes changes of water quality observed in natural/industrial analogues and in laboratory experiments. The second reviews hydrodynamic and geochemical models, including coupled multiphase flow and reactive transport. Various models are discussed in terms of their advantages and limitations, with conclusions on possible impacts on groundwater resources. Possible mitigation options to stop or control CO2 leakage are assessed. The effect of CO2 pressure in the host DSF and the potential effects on shallow aquifers are also examined. The study provides a review of

Geological characterization of CO{sub 2} storage sites: lessons from Sleipner, Northern North Sea

Energy Technology Data Exchange (ETDEWEB)

R.A. Chadwick; P. Zweigel; U. Gregersen; G.A. Kirby; S. Holloway; P.N. Johannessen [British Geological Survey, Keyworth (United Kingdom). Kingsley Dunham Centre

2003-07-01

The paper aims to draw some generic conclusions on reservoir characterization based on the Sleipner operation in the North Sea where CO{sub 2} is being injected into the Utsira Sand, a saline aquifer. Regional mapping and petrophysical characterization of the reservoir, based on 2D seismic and well data, enable gross storage potential to be evaluated. Site specific injection studies, however, require precision depth mapping based on 3D seismic data and detailed knowledge of reservoir stratigraphy. Stratigraphical and structural permeability barriers, difficult to detect prior to CO{sub 2} injection, can radically affect CO{sub 2} migration within the aquifer. 5 refs., 5 figs.

Gas geochemistry of natural analogues for the studies of geological CO2 sequestration

International Nuclear Information System (INIS)

Voltattorni, N.; Sciarra, A.; Caramanna, G.; Cinti, D.; Pizzino, L.; Quattrocchi, F.

2009-01-01

Geological sequestration of anthropogenic CO 2 appears to be a promising method for reducing the amount of greenhouse gases released to the atmosphere. Geochemical modelling of the storage capacity for CO 2 in saline aquifers, sandstones and/or carbonates should be based on natural analogues both in situ and in the laboratory. The main focus of this paper has been to study natural gas emissions representing extremely attractive surrogates for the study and prediction of the possible consequences of leakage from geological sequestration sites of anthropogenic CO 2 (i.e., the return to surface, potentially causing localised environmental problems). These include a comparison among three different Italian case histories: (i) the Solfatara crater (Phlegraean Fields caldera, southern Italy) is an ancient Roman spa. The area is characterised by intense and diffuse hydrothermal activity, testified by hot acidic mud pools, thermal springs and a large fumarolic field. Soil gas flux measurements show that the entire area discharges between 1200 and 1500 tons of CO 2 per day; (ii) the Panarea Island (Aeolian Islands, southern Italy) where a huge submarine volcanic-hydrothermal gas burst occurred in November, 2002. The submarine gas emissions chemically modified seawater causing a strong modification of the marine ecosystem. All of the collected gases are CO 2 -dominant (maximum value: 98.43 vol.%); (iii) the Tor Caldara area (Central Italy), located in a peripheral sector of the quiescent Alban Hills volcano, along the faults of the Ardea Basin transfer structure. The area is characterised by huge CO 2 degassing both from water and soil. Although the above mentioned areas do not represent a storage scenario, these sites do provide many opportunities to study near-surface processes and to test monitoring methodologies.

The European FP7 ULTimateCO2 project: A comprehensive approach to study the long term fate of CO2 geological storage sites

Science.gov (United States)

Audigane, P.; Brown, S.; Dimier, A.; Pearce, J.; Frykman, P.; Maurand, N.; Le Gallo, Y.; Spiers, C. J.; Cremer, H.; Rutters, H.; Yalamas, T.

2013-12-01

The European FP7 ULTimateCO2 project aims at significantly advance our knowledge of specific processes that could influence the long-term fate of geologically stored CO2: i) trapping mechanisms, ii) fluid-rock interactions and effects on mechanical integrity of fractured caprock and faulted systems and iii) leakage due to mechanical and chemical damage in the well vicinity, iv) brine displacement and fluid mixing at regional scale. A realistic framework is ensured through collaboration with two demonstration sites in deep saline sandstone formations: the onshore former NER300 West Lorraine candidate in France (ArcelorMittal GeoLorraine) and the offshore EEPR Don Valley (former Hatfield) site in UK operated by National Grid. Static earth models have been generated at reservoir and basin scale to evaluate both trapping mechanisms and fluid displacement at short (injection) and long (post injection) time scales. Geochemical trapping and reservoir behaviour is addressed through experimental approaches using sandstone core materials in batch reactive mode with CO2 and impurities at reservoir pressure and temperature conditions and through geochemical simulations. Collection of data has been generated from natural and industrial (oil industry) analogues on the fluid flow and mechanical properties, structure, and mineralogy of faults and fractures that could affect the long-term storage capacity of underground CO2 storage sites. Three inter-related lines of laboratory experiments investigate the long-term evolution of the mechanical properties and sealing integrity of fractured and faulted caprocks using Opalinus clay of Mont Terri Gallery (Switzerland) (OPA), an analogue for caprock well investigated in the past for nuclear waste disposal purpose: - Characterization of elastic parameters in intact samples by measuring strain during an axial experiment, - A recording of hydraulic fracture flow properties by loading and shearing samples in order to create a 'realistic

Application of simplified models to CO2 migration and immobilization in large-scale geological systems

KAUST Repository

Gasda, Sarah E.

2012-07-01

Long-term stabilization of injected carbon dioxide (CO 2) is an essential component of risk management for geological carbon sequestration operations. However, migration and trapping phenomena are inherently complex, involving processes that act over multiple spatial and temporal scales. One example involves centimeter-scale density instabilities in the dissolved CO 2 region leading to large-scale convective mixing that can be a significant driver for CO 2 dissolution. Another example is the potentially important effect of capillary forces, in addition to buoyancy and viscous forces, on the evolution of mobile CO 2. Local capillary effects lead to a capillary transition zone, or capillary fringe, where both fluids are present in the mobile state. This small-scale effect may have a significant impact on large-scale plume migration as well as long-term residual and dissolution trapping. Computational models that can capture both large and small-scale effects are essential to predict the role of these processes on the long-term storage security of CO 2 sequestration operations. Conventional modeling tools are unable to resolve sufficiently all of these relevant processes when modeling CO 2 migration in large-scale geological systems. Herein, we present a vertically-integrated approach to CO 2 modeling that employs upscaled representations of these subgrid processes. We apply the model to the Johansen formation, a prospective site for sequestration of Norwegian CO 2 emissions, and explore the sensitivity of CO 2 migration and trapping to subscale physics. Model results show the relative importance of different physical processes in large-scale simulations. The ability of models such as this to capture the relevant physical processes at large spatial and temporal scales is important for prediction and analysis of CO 2 storage sites. © 2012 Elsevier Ltd.

Brine/CO2 Interfacial Properties and Effects on CO2 Storage in Deep Saline Aquifers Propriétés interfaciales saumure/CO2 et effets sur le stockage du CO2 dans des aquifères salins profonds

Directory of Open Access Journals (Sweden)

Chalbaud C.

2010-05-01

Full Text Available It has been long recognized that interfacial interactions (interfacial tension, wettability, capillarity and interfacial mass transfer govern fluid distribution and behaviour in porous media. Therefore the interfacial interactions between CO2, brine and reservoir oil and/or gas have an important influence on the effectiveness of any CO2 storage operation. There is a lack of experimental data related to interfacial properties for all the geological storage options (oil & gas reservoirs, coalbeds, deep saline aquifers. In the case of deep saline aquifers, there is a gap in data and knowledge of brine-CO2 interfacial properties at storage conditions. More specifically, experimental interfacial tension values and experimental tests in porous media are necessary to better understand the wettability evolution as a function of thermodynamic conditions and it’s effects on fluid flow in the porous media. In this paper, a complete set of experimental values of brine-CO2 Interfaciale Tension (IFT at pressure, temperature and salt concentration conditions representative of those of a CO2 storage operation. A correlation is derived from experimental data published in a companion paper [Chalbaud C., Robin M., Lombard J.-M., Egermann P., Bertin H. (2009 Interfacial Tension Measurements and Wettability Evaluation for Geological CO2 Storage, Adv. Water Resour. 32, 1, 1-109] to model IFT values. This paper pays particular attention to coreflooding experiments showing that the CO2 partially wets the surface in a Intermediate-Wet (IW or Oil-Wet (OW limestone rock. This wetting behavior of CO2 is coherent with observations at the pore scale in glass micromodels and presents a negative impact on the storage capacity of a given site. Il est admis depuis longtemps que les propriétés interfaciales (tension interfaciale, mouillabilité, capillarité et transfert de masse régissent la distribution et le comportement des fluides au sein des milieux poreux. Par cons

Scientific basis to assess the potential for geological sequestration of CO{sub 2} in Switzerland

Energy Technology Data Exchange (ETDEWEB)

Diamond, L. W.; Chevalier, G. [Institut fuer Geologie, Universitaet Bern, Bern (Switzerland); Leu, W. [Geoform AG, Geologische Beratungen und Studien, Villeneuve (former Minusio) (Switzerland)

2010-07-01

Possibilities to sequester anthropogenic CO{sub 2} in deep geological formations are being investigated worldwide, but the potential within Switzerland has not yet been evaluated. This study presents a first-order appraisal based solely on geological criteria collated from the literature. The Swiss Molasse Basin (SMB) and the adjacent Folded Jura are the only realms of the country where CO{sub 2} could conceivably be stored in saline aquifers. Evaluation of geological criteria at the basin-wide scale shows that the SMB-Jura has moderate potential (score of 0.6 on a scale from 0 to 1) when compared to basins elsewhere. At the intrabasinal scale, inspection of the stratigraphy reveals four regional candidate aquifers that are sealed by suitable caprocks: top Basement plus basal Mesozoic sandstones, all sealed by the Anhydrite Group; Upper Muschelkalk sealed by the Gipskeuper; Hauptrogenstein sealed by the Effinger Member, and Upper Malm plus Lower Cretaceous sealed by the Lower Freshwater Molasse. Nine geological criteria are defined to evaluate the storage potential of these and other smaller-scale candidates. A numerical scoring and weighting scheme allows the criteria to be assessed simultaneously, permitting the storage potential to be depicted using the 0-1 scale in contoured maps. Approximately 5000 km{sup 2} of the central SMB exhibits potentials between 0.6 and 0.96. The Fribourg-Olten-Lucerne area is the most favoured owing to the presence of several sealed aquifers within the preferred 800-2500 m depth interval, and to its low seismicity, low geothermal gradient, low fault density, and long groundwater residence times. Smaller areas with good potential lie between Zurich and St. Gall. In contrast, western Switzerland, the Jura and the southern SMB have markedly poorer potential. Considering only the portions of the aquifers with potential above 0.6, the theoretical, effective storage capacity of the basin is estimated to be 2680 million tonnes of CO{sub 2

Environmental Assessment for Potential Impacts of Ocean CO2 Storage on Marine Biogeochemical Cycles

Science.gov (United States)

Yamada, N.; Tsurushima, N.; Suzumura, M.; Shibamoto, Y.; Harada, K.

2008-12-01

Ocean CO2 storage that actively utilizes the ocean potential to dissolve extremely large amounts of CO2 is a useful option with the intent of diminishing atmospheric CO2 concentration. CO2 storage into sub-seabed geological formations is also considered as the option which has been already put to practical reconnaissance in some projects. Direct release of CO2 in the ocean storage and potential CO2 leakage from geological formations into the bottom water can alter carbonate system as well as pH of seawater. It is essential to examine to what direction and extent chemistry change of seawater induced by CO2 can affect the marine environments. Previous studies have shown direct and acute effects by increasing CO2 concentrations on physiology of marine organisms. It is also a serious concern that chemistry change can affect the rates of chemical, biochemical and microbial processes in seawater resulting in significant influences on marine biogeochemical cycles of the bioelements including carbon, nutrients and trace metals. We, AIST, have conducted a series of basic researches to assess the potential impacts of ocean CO2 storage on marine biogeochemical processes including CaCO3 dissolution, and bacterial and enzymatic decomposition of organic matter. By laboratory experiments using a special high pressure apparatus, the improved empirical equation was obtained for CaCO3 dissolution rate in the high CO2 concentrations. Based on the experimentally obtained kinetics with a numerical simulation for a practical scenario of oceanic CO2 sequestration where 50 Mton CO2 per year is continuously injected to 1,000-2,500 m depth within 100 x 333 km area for 30 years, we could illustrate precise 3-D maps for the predicted distributions of the saturation depth of CaCO3, in situ Ω value and CaCO3 dissolution rate in the western North Pacific. The result showed no significant change in the bathypelagic CaCO3 flux due to chemistry change induced by ocean CO2 sequestration. Both

Next generation of CO2 enhanced water recovery with subsurface energy storage in China

Science.gov (United States)

Li, Qi; Kühn, Michael; Ma, Jianli; Niu, Zhiyong

2017-04-01

., Nakaten N., Kempka T., Kühn M. (2013) Analysis of an integrated carbon cycle for storage of renewables. Energy Procedia 40, 202-211. doi: 10.1016/j.egypro.2013.08.024. [3] Li Q, Wei Y-N, Liu G, Lin Q (2014) Combination of CO2 Geological Storage with Deep Saline Water Recovery in Western China: Insights from Numerical Analyses. Applied Energy 116:101-110. doi:10.1016/j.apenergy.2013.11.050 [4] Wei N, Li X, Fang Z, Bai B, Li Q, Liu S, Jia Y (2015) Regional Resource Distribution of Onshore Carbon Geological Utilization in China. Journal of CO2 Utilization 11:20-30. doi:10.1016/j.jcou.2014.12.005 [5] Li Q, Wei Y-N, Chen Z-A (2016) Water-CCUS Nexus: Challenges and Opportunities of China's Coal Chemical Industry. Clean Technologies and Environmental Policy 18 (3):775-786. doi:10.1007/s10098-015-1049-z

Subtask – CO₂ storage and enhanced bakken recovery research program

Energy Technology Data Exchange (ETDEWEB)

Sorensen, James [Univ. of North Dakota, Grand Forks, ND (United States); Hawthorne, Steven [Univ. of North Dakota, Grand Forks, ND (United States); Smith, Steven [Univ. of North Dakota, Grand Forks, ND (United States); Braunberger, Jason [Univ. of North Dakota, Grand Forks, ND (United States); Liu, Guoxiang [Univ. of North Dakota, Grand Forks, ND (United States); Klenner, Robert [Univ. of North Dakota, Grand Forks, ND (United States); Botnen, Lisa [Univ. of North Dakota, Grand Forks, ND (United States); Steadman, Edward [Univ. of North Dakota, Grand Forks, ND (United States); Harju, John [Univ. of North Dakota, Grand Forks, ND (United States); Doll, Thomas [Univ. of North Dakota, Grand Forks, ND (United States)

2014-05-31

Small improvements in productivity could increase technically recoverable oil in the Bakken Petroleum System by billions of barrels. The use of CO₂ for enhanced oil recovery (EOR) in tight oil reservoirs is a relatively new concept. The large-scale injection of CO₂ into the Bakken would also result in the geological storage of significant amounts of CO₂. The Energy & Environmental Research Center (EERC) has conducted laboratory and modeling activities to examine the potential for CO₂ storage and EOR in the Bakken. Specific activities included the characterization and subsequent modeling of North Dakota study areas as well as dynamic predictive simulations of possible CO₂ injection schemes to predict the potential CO₂ storage and EOR in those areas. Laboratory studies to evaluate the ability of CO₂ to remove hydrocarbons from Bakken rocks and determine minimum miscibility pressures for Bakken oil samples were conducted. Data from a CO₂ injection test conducted in the Elm Coulee area of Montana in 2009 were evaluated with an eye toward the possible application of knowledge gained to future injection tests in other areas. A first-order estimation of potential CO₂ storage capacity in the Bakken Formation in North Dakota was also conducted. Key findings of the program are as follows. The results of the research activities suggest that CO₂ may be effective in enhancing the productivity of oil from the Bakken and that the Bakken may hold the ability to geologically store between 120 Mt and 3.2 Gt of CO₂. However, there are no clear-cut answers regarding the most effective approach for using CO₂ to improve oil productivity or the storage capacity of the Bakken. The results underscore the notion that an unconventional resource will likely require unconventional methods of both assessment and implementation when it comes to the injection of CO

Numerical Study on CO2-Brine-Rock Interaction of Enhanced Geothermal Systems with CO2 as Heat Transmission Fluid

Directory of Open Access Journals (Sweden)

Wan Yuyu

2016-01-01

Full Text Available Enhanced Geothermal Systems (EGS with CO2 instead of water as heat transmission fluid is an attractive concept for both geothermal resources development and CO2 geological sequestration. Previous studies show that CO2 has lots of favorable properties as heat transmission fluid and also can offer geologic storage of CO2 as an ancillary benefit. However, after CO2 injection into geological formations, chemical reaction between brine and rock can change chemical characteristics of saline and properties of rock such as porosity and permeability. Is this advantage or disadvantage for EGS operating? To answer this question, we have performed chemically reactive transport modeling to investigate fluid-rock interactions and CO2 mineral carbonation of Enhanced Geothermal Systems (EGS site at Desert Peak (Nevada operated with CO2. The simulation results show that (1 injection CO2 can create a core zone fulfilled with CO2 as main working domain for EGS, and (2 CO2 storage can induced self-enhancing alteration of EGS.

Gas geochemistry of natural analogues for the studies of geological CO{sub 2} sequestration

Energy Technology Data Exchange (ETDEWEB)

Voltattorni, N., E-mail: nunzia.voltattorni@ingv.it [Istituto Nazionale di Geofisica e Vulcanologia, Via di Vigna Murata no 605, 00143 Rome (Italy); Sciarra, A. [Istituto Nazionale di Geofisica e Vulcanologia, Via di Vigna Murata no 605, 00143 Rome (Italy); Caramanna, G. [Earth Science Dep., University ' La Sapienza' , Piazzale A. Moro no 5, 00185 Rome (Italy); Cinti, D.; Pizzino, L.; Quattrocchi, F. [Istituto Nazionale di Geofisica e Vulcanologia, Via di Vigna Murata no 605, 00143 Rome (Italy)

2009-07-15

Geological sequestration of anthropogenic CO{sub 2} appears to be a promising method for reducing the amount of greenhouse gases released to the atmosphere. Geochemical modelling of the storage capacity for CO{sub 2} in saline aquifers, sandstones and/or carbonates should be based on natural analogues both in situ and in the laboratory. The main focus of this paper has been to study natural gas emissions representing extremely attractive surrogates for the study and prediction of the possible consequences of leakage from geological sequestration sites of anthropogenic CO{sub 2} (i.e., the return to surface, potentially causing localised environmental problems). These include a comparison among three different Italian case histories: (i) the Solfatara crater (Phlegraean Fields caldera, southern Italy) is an ancient Roman spa. The area is characterised by intense and diffuse hydrothermal activity, testified by hot acidic mud pools, thermal springs and a large fumarolic field. Soil gas flux measurements show that the entire area discharges between 1200 and 1500 tons of CO{sub 2} per day; (ii) the Panarea Island (Aeolian Islands, southern Italy) where a huge submarine volcanic-hydrothermal gas burst occurred in November, 2002. The submarine gas emissions chemically modified seawater causing a strong modification of the marine ecosystem. All of the collected gases are CO{sub 2}-dominant (maximum value: 98.43 vol.%); (iii) the Tor Caldara area (Central Italy), located in a peripheral sector of the quiescent Alban Hills volcano, along the faults of the Ardea Basin transfer structure. The area is characterised by huge CO{sub 2} degassing both from water and soil. Although the above mentioned areas do not represent a storage scenario, these sites do provide many opportunities to study near-surface processes and to test monitoring methodologies.

Maximizing Storage Rate and Capacity and Insuring the Environmental Integrity of Carbon Dioxide Sequestration in Geological Reservoirs

Energy Technology Data Exchange (ETDEWEB)

L.A. Davis; A.L. Graham; H.W. Parker; J.R. Abbott; M.S. Ingber; A.A. Mammoli; L.A. Mondy; Quanxin Guo; Ahmed Abou-Sayed

2005-12-07

Maximizing Storage Rate and Capacity and Insuring the Environmental Integrity of Carbon Dioxide Sequestration in Geological Formations The U.S. and other countries may enter into an agreement that will require a significant reduction in CO2 emissions in the medium to long term. In order to achieve such goals without drastic reductions in fossil fuel usage, CO2 must be removed from the atmosphere and be stored in acceptable reservoirs. The research outlined in this proposal deals with developing a methodology to determine the suitability of a particular geologic formation for the long-term storage of CO2 and technologies for the economical transfer and storage of CO2 in these formations. A novel well-logging technique using nuclear-magnetic resonance (NMR) will be developed to characterize the geologic formation including the integrity and quality of the reservoir seal (cap rock). Well-logging using NMR does not require coring, and hence, can be performed much more quickly and efficiently. The key element in the economical transfer and storage of the CO2 is hydraulic fracturing the formation to achieve greater lateral spreads and higher throughputs of CO2. Transport, compression, and drilling represent the main costs in CO2 sequestration. The combination of well-logging and hydraulic fracturing has the potential of minimizing these costs. It is possible through hydraulic fracturing to reduce the number of injection wells by an order of magnitude. Many issues will be addressed as part of the proposed research to maximize the storage rate and capacity and insure the environmental integrity of CO2 sequestration in geological formations. First, correlations between formation properties and NMR relaxation times will be firmly established. A detailed experimental program will be conducted to determine these correlations. Second, improved hydraulic fracturing models will be developed which are suitable for CO2 sequestration as opposed to enhanced oil recovery (EOR

Towards a sustainable mining law: geothermal, CO2 capture and geological storage?

International Nuclear Information System (INIS)

Lanoy, Laurence

2013-01-01

The author comments how the French mining code has been able to adapt itself to the development of new techniques such as geothermal power, CO 2 capture and storage in a context of environmental concerns. She comments how the mining code evolved towards a new concept of soil use and valorisation in relationship with the development of these techniques, and how the mining code has thus become a new actor in the field of renewable energies. Its reform is briefly discussed

Soil gas (222Rn, CO2, 4He) behaviour over a natural CO2 accumulation, Montmiral area (Drome, France): geographical, geological and temporal relationships

International Nuclear Information System (INIS)

Gal, Frederick; Joublin, Franck; Haas, Hubert; Jean-prost, Veronique; Ruffier, Veronique

2011-01-01

The south east basin of France shelters deep CO 2 reservoirs often studied with the aim of better constraining geological CO 2 storage operations. Here we present new soil gas data, completing an existing dataset (CO 2 , 222 Rn, 4 He), together with mineralogical and physical characterisations of soil columns, in an attempt to better understand the spatial distribution of gas concentrations in the soils and to rule on the sealed character of the CO 2 reservoir at present time. Anomalous gas concentrations were found but did not appear to be clearly related to geological structures that may drain deep gases up to the surface, implying a dominant influence of near surface processes as indicated by carbon isotope ratios. Coarse grained, quartz-rich soils favoured the existence of high CO 2 concentrations. Fine grained clayey soils preferentially favoured the existence of 222 Rn but not CO 2 . Soil formations did not act as barriers preventing gas migrations in soils, either due to water content or due to mineralogical composition. No abundant leakage from the Montmiral reservoir can be highlighted by the measurements, even near the exploitation well. As good correlation between CO 2 and 222 Rn concentrations still exist, it is suggested that 222 Rn migration is also CO 2 dependent in non-leaking areas - diffusion dominated systems.

A consistent approach to CO{sub 2} storage capacity estimation for deep saline formations

Energy Technology Data Exchange (ETDEWEB)

Dose, T. [DEA Mineraloel AG, Hamburg (Germany)

2008-10-23

Whereas the methodology of assessing pore volume is well established, a consistent methodology for calculating the pore volume efficiency (PVE) needs to be applied, e.g., as proposed in this paper. (1) Numerical simulations show, that CO{sub 2} storage sites are not restricted to geologic traps like anticlines. Also synclines and flat structures provide feasible storage structures, as long as no shortcut to the surface like leaking faults or wells exist. (2) Among active forces induced by CO{sub 2} injection, differential injection pressure and static pressure increase may turn out to be critical. This can lead to overlap with capillary displacement pressure, fracturing pressure, and exceeding the fault friction limit. (3) If differential injection pressure turns out to be critical, this can be balanced technically. Fault slippage can be avoided by selecting appropriate sites. (4) For the CO{sub 2} storage system to stay in balance, it is required that the static pressure increase stays below the capillary displacement pressure. (5) With this limiting conditions, scenarios show PVEs of 0.1-0.65% for a hydraulic system, mostly dependant on caprock quality and total compressibility. (6) Likely several possible storage sites exist for a hydraulic system. It is almost sure that the sum of the local storage potential will exceed the storage potential of the hydraulic system. (7) Regional pressure effects of CO{sub 2} storage can be significant. Different storage sites injecting at high rates into the same hydraulic system will need large distances between them. (9) Due to likely interference of storage sites and other fluid operations within a hydraulic system, close cooperations between operators may become necessary. (orig.)

Functional response of a near-surface soil microbial community to a simulated underground CO2 storage leak.

Science.gov (United States)

Morales, Sergio E; Holben, William E

2013-01-01

Understanding the impacts of leaks from geologic carbon sequestration, also known as carbon capture and storage, is key to developing effective strategies for carbon dioxide (CO2) emissions management and mitigation of potential negative effects. Here, we provide the first report on the potential effects of leaks from carbon capture and storage sites on microbial functional groups in surface and near-surface soils. Using a simulated subsurface CO2 storage leak scenario, we demonstrate how CO2 flow upward through the soil column altered both the abundance (DNA) and activity (mRNA) of microbial functional groups mediating carbon and nitrogen transformations. These microbial responses were found to be seasonally dependent and correlated to shifts in atmospheric conditions. While both DNA and mRNA levels were affected by elevated CO2, they did not react equally, suggesting two separate mechanisms for soil microbial community response to high CO2 levels. The results did not always agree with previous studies on elevated atmospheric (rather than subsurface) CO2 using FACE (Free-Air CO2 Enrichment) systems, suggesting that microbial community response to CO2 seepage from the subsurface might differ from its response to atmospheric CO2 increases.

Your View or Mine: Spatially Quantifying CO2 Storage Risk from Various Stakeholder Perspectives

Science.gov (United States)

Bielicki, J. M.; Pollak, M.; Wilson, E.; Elliot, T. R.; Guo, B.; Nogues, J. P.; Peters, C. A.

2011-12-01

CO2 capture and storage involves injecting captured CO2 into geologic formations, such as deep saline aquifers. This injected CO2 is to be "stored" within the rock matrix for hundreds to thousands of years, but injected CO2, or the brine it displaces, may leak from the target reservoir. Such leakage could interfere with other subsurface activities-water production, energy production, energy storage, and waste disposal-or migrate to the surface. Each of these interferences will incur multiple costs to a variety of stakeholders. Even if injected or displaced fluids do not interfere with other subsurface activities or make their way to the surface, costs will be incurred to find and fix the leak. Consequently, the suitability of a site for CO2 storage must therefore include an assessment of the risk of leakage and interference with various other activities within a three-dimensional proximity of where CO2 is being injected. We present a spatial analysis of leakage and interference risk associated with injecting CO2 into a portion of the Mount Simon sandstone in the Michigan Basin. Risk is the probability of an outcome multiplied by the impact of that outcome (Ro=po*Io). An outcome is the result of the leakage (e.g., interference with oil production), and the impact is the cost associated with the outcome. Each outcome has costs that will vary by stakeholder. Our analysis presents CO2 storage risk for multiple outcomes in a spatially explicit manner that varies by stakeholder. We use the ELSA semi-analytical model for estimating CO2 and brine leakage from aquifers to determine plume and pressure front radii, and CO2 and brine leakage probabilities for the Mount Simon sandstone and multiple units above it. Results of ELSA simulations are incorporated into RISCS: the Risk Interference Subsurface CO2 Storage model. RISCS uses three-dimensional data on subsurface geology and the locations of wells and boreholes to spatially estimate risks associated with CO2 leakage from

An Assessment of Geological Carbon Storage Options in the Illinois Basin: Validation Phase

Energy Technology Data Exchange (ETDEWEB)

Finley, Robert

2012-12-01

The Midwest Geological Sequestration Consortium (MGSC) assessed the options for geological carbon dioxide (CO{sub 2}) storage in the 155,400 km{sup 2} (60,000 mi{sup 2}) Illinois Basin, which underlies most of Illinois, western Indiana, and western Kentucky. The region has annual CO{sub 2} emissions of about 265 million metric tonnes (292 million tons), primarily from 122 coal-fired electric generation facilities, some of which burn almost 4.5 million tonnes (5 million tons) of coal per year (U.S. Department of Energy, 2010). Validation Phase (Phase II) field tests gathered pilot data to update the Characterization Phase (Phase I) assessment of options for capture, transportation, and storage of CO{sub 2} emissions in three geological sink types: coal seams, oil fields, and saline reservoirs. Four small-scale field tests were conducted to determine the properties of rock units that control injectivity of CO{sub 2}, assess the total storage resources, examine the security of the overlying rock units that act as seals for the reservoirs, and develop ways to control and measure the safety of injection and storage processes. The MGSC designed field test operational plans for pilot sites based on the site screening process, MVA program needs, the selection of equipment related to CO{sub 2} injection, and design of a data acquisition system. Reservoir modeling, computational simulations, and statistical methods assessed and interpreted data gathered from the field tests. Monitoring, Verification, and Accounting (MVA) programs were established to detect leakage of injected CO{sub 2} and ensure public safety. Public outreach and education remained an important part of the project; meetings and presentations informed public and private regional stakeholders of the results and findings. A miscible (liquid) CO{sub 2} flood pilot project was conducted in the Clore Formation sandstone (Mississippian System, Chesterian Series) at Mumford Hills Field in Posey County, southwestern

Mineral storage of CO2/H2S gas mixture injection in basaltic rocks

Science.gov (United States)

Clark, D. E.; Gunnarsson, I.; Aradottir, E. S.; Oelkers, E. H.; Sigfússon, B.; Snæbjörnsdottír, S. Ó.; Matter, J. M.; Stute, M.; Júlíusson, B. M.; Gíslason, S. R.

2017-12-01

Carbon capture and storage is one solution to reducing CO2 emissions in the atmosphere. The long-term geological storage of buoyant supercritical CO2 requires high integrity cap rock. Some of the risk associated with CO2 buoyancy can be overcome by dissolving CO2 into water during its injection, thus eliminating its buoyancy. This enables injection into fractured rocks, such as basaltic rocks along oceanic ridges and on continents. Basaltic rocks are rich in divalent cations, Ca2+, Mg2+ and Fe2+, which react with CO2 dissolved in water to form stable carbonate minerals. This possibility has been successfully tested as a part of the CarbFix CO2storage pilot project at the Hellisheiði geothermal power plant in Iceland, where they have shown mineralization occurs in less than two years [1, 2]. Reykjavik Energy and the CarbFix group has been injecting a mixture of CO2 and H2S at 750 m depth and 240-250°C since June 2014; by 1 January 2016, 6290 tons of CO2 and 3530 tons of H2S had been injected. Once in the geothermal reservoir, the heat exchange and sufficient dissolution of the host rock neutralizes the gas-charged water and saturates the formation water respecting carbonate and sulfur minerals. A thermally stable inert tracer was also mixed into the stream to monitor the subsurface transport and to assess the degree of subsurface carbonation and sulfide precipitation [3]. Water and gas samples have been continuously collected from three monitoring wells and geochemically analyzed. Based on the results, mineral saturation stages have been defined. These results and tracer mass balance calculations are used to evaluate the rate and magnitude of CO2 and H2S mineralization in the subsurface, with indications that mineralization of carbon and sulfur occurs within months. [1] Gunnsarsson, I., et al. (2017). Rapid and cost-effective capture and subsurface mineral storage of carbon and sulfur. Manuscript submitted for publication. [2] Matter, J., et al. (2016). Rapid

Monitoring CO2 penetration and storage in the brine-saturated low permeable sandstone by the geophysical exploration technologies

Science.gov (United States)

Honda, H.; Mitani, Y.; Kitamura, K.; Ikemi, H.; Imasato, M.

2017-12-01

Carbon dioxide (CO2) capture and storage (CCS) plays a vital role in reducing greenhouse gas emissions. In the northern part of Kyushu region of Japan, complex geological structure (Coalfield) is existed near the CO2 emission source and has 1.06 Gt of CO2 storage capacity. The geological survey shows that these layers are formed by low permeable sandstone. It is necessary to monitor the CO2 behavior and clear the mechanisms of CO2 penetration and storage in the low permeable sandstone. In this study, measurements of complex electrical impedance (Z) and elastic wave velocity (P-wave velocity: Vp) were conducted during the supercritical CO2 injection experiment into the brine-saturated low permeable sandstone. The experiment conditions were as follows; Confining pressure: 20 MPa, Initial pore pressure: 10 MPa, 40 °, CO2 injection rate: 0.01 to 0.5 mL/min. Z was measured in the center of the specimen and Vp were measured at three different heights of the specimen at constant intervals. In addition, we measured the longitudinal and lateral strain at the center of the specimen, the pore pressure and CO2 injection volume (CO2 saturation). During the CO2 injection, the change of Z and Vp were confirmed. In the drainage terms, Vp decreased drastically once CO2 reached the measurement cross section.Vp showed the little change even if the flow rate increased (CO2 saturation increased). On the other hand, before the CO2 front reached, Z decreased with CO2-dissolved brine. After that, Z showed continuously increased as the CO2 saturation increased. From the multi-parameter (Hydraulic and Rock-physics parameters), we revealed the detail CO2 behavior in the specimen. In the brine-saturated low permeable sandstone, the slow penetration of CO2 was observed. However, once CO2 has passed, the penetration of CO2 became easy in even for brine-remainded low permeable sandstone. We conclude low permeable sandstone has not only structural storage capacity but also residual tapping

3rd Sino-German Conference “Underground Storage of CO2 and Energy”

CERN Document Server

Xie, Heping; Were, Patrick

2013-01-01

Anthropogenic greenhouse gas emissions, energy security and sustainability are three of the greatest contemporary global challenges today. This year the Sino-German Cooperation Group “Underground Storage of CO2 and Energy”, is meeting on the 21-23 May 2013 for the second time in Goslar, Germany, to convene its 3rd Sino-German conference on the theme “Clean Energy Systems in the Subsurface: Production, Storage and Conversion”.   This volume is a collection of diverse quality scientific works from different perspectives elucidating on the current developments in CO2 geologic sequestration research to reduce greenhouse emissions including measures to monitor surface leakage, groundwater quality and the integrity of caprock, while ensuring a sufficient supply of clean energy. The contributions herein have been structured into 6 major thematic research themes: Integrated Energy and Environmental Utilization of Geo-reservoirs: Law, Risk Management & Monitoring CO2 for Enhanced Gas and Oil Recovery, Coa...

Techno-Economic Assessment of Four CO2 Storage Sites

Directory of Open Access Journals (Sweden)

Gruson J.-F.

2015-04-01

Full Text Available Carbon Capture and Storage (CCS should be a key technology in order to achieve a decline in the CO2 emissions intensity of the power sector and other intensive industry, but this potential deployment could be restricted by cost issues as the International Energy Agency (IEA in their last projections (World Energy Outlook 2013 has considered only around 1% of global fossil fuel-fired power plants could be equipped with CCS by 2035. The SiteChar project funded by 7th Framework Programme of European Commission gives the opportunity to evaluate the most influential parameters of techno-economic evaluations of four feasible European projects for CO2 geological storage located onshore and offshore and related to aquifer storage or oil and gas reservoirs, at different stages of characterization. Four potential CO2 storage sites have been assessed in terms of storage costs per tonne of CO2 permanently stored (equivalent cost based. They are located offshore UK, onshore Denmark, offshore Norway and offshore Italy. The four SiteChar techno-economic evaluations confirm it is not possible to derive any meaningful average cost for a CO2 storage site. The results demonstrate that the structure of costs for a project is heterogeneous and the storage cost is consequently site dependent. The strategy of the site development is fundamental, the technical choices such as the timing, rate and duration of injection are also important. The way monitoring is managed, using observation wells and logging has a strong impact on the estimated monitoring costs. Options to lower monitoring costs, such as permanent surveys, exist and should be further investigated. Table 1 below summarizes the cost range in Euro per tonne (Discount Rate (DR at 8% for the different sites, which illustrates the various orders of magnitude due to the specificities of each site. These figures have how to be considered with care. In particular the Italian and Norwegian sites present very specific

Optimizing geologic CO2 sequestration by injection in deep saline formations below oil reservoirs

International Nuclear Information System (INIS)

Han, Weon Shik; McPherson, Brian J.

2009-01-01

The purpose of this research is to present a best-case paradigm for geologic CO 2 storage: CO 2 injection and sequestration in saline formations below oil reservoirs. This includes the saline-only section below the oil-water contact (OWC) in oil reservoirs, a storage target neglected in many current storage capacity assessments. This also includes saline aquifers (high porosity and permeability formations) immediately below oil-bearing formations. While this is a very specific injection target, we contend that most, if not all, oil-bearing basins in the US contain a great volume of such strata, and represent a rather large CO 2 storage capacity option. We hypothesize that these are the best storage targets in those basins. The purpose of this research is to evaluate this hypothesis. We quantitatively compared CO 2 behavior in oil reservoirs and brine formations by examining the thermophysical properties of CO 2 , CO 2 -brine, and CO 2 -oil in various pressure, temperature, and salinity conditions. In addition, we compared the distribution of gravity number (N), which characterizes a tendency towards buoyancy-driven CO 2 migration, and mobility ratio (M), which characterizes the impeded CO 2 migration, in oil reservoirs and brine formations. Our research suggests competing advantages and disadvantages of CO 2 injection in oil reservoirs vs. brine formations: (1) CO 2 solubility in oil is significantly greater than in brine (over 30 times); (2) the tendency of buoyancy-driven CO 2 migration is smaller in oil reservoirs because density contrast between oil and CO 2 is smaller than it between brine and oil (the approximate density contrast between CO 2 and crude oil is ∼100 kg/m 3 and between CO 2 and brine is ∼350 kg/m 3 ); (3) the increased density of oil and brine due to the CO 2 dissolution is not significant (about 7-15 kg/m 3 ); (4) the viscosity reduction of oil due to CO 2 dissolution is significant (from 5790 to 98 mPa s). We compared these competing

Change in cap rock porosity triggered by pressure and temperature dependent CO2–water–rock interactions in CO2 storage systems

Directory of Open Access Journals (Sweden)

Christina Hemme

2017-03-01

Full Text Available Carbon capture and storage in deep geological formations is a method to reduce greenhouse gas emissions. Supercritical CO2 is injected into a reservoir and dissolves in the brine. Under the impact of pressure and temperature (P–T the aqueous species of the CO2-acidified brine diffuse through the cap rock where they trigger CO2–water–rock interactions. These geochemical reactions result in mineral dissolution and precipitation along the CO2 migration path and are responsible for a change in porosity and therefore for the sealing capacity of the cap rock. This study focuses on the diffusive mass transport of CO2 along a gradient of decreasing P–T conditions. The process is retraced with a one-dimensional hydrogeochemical reactive mass transport model. The semi-generic hydrogeochemical model is based on chemical equilibrium thermodynamics. Based on a broad variety of scenarios, including different initial mineralogical, chemical and physical parameters, the hydrogeochemical parameters that are most sensitive for safe long-term CO2 storage are identified. The results demonstrate that P–T conditions have the strongest effect on the change in porosity and the effect of both is stronger at high P–T conditions because the solubility of the mineral phases involved depends on P–T conditions. Furthermore, modeling results indicate that the change in porosity depends strongly on the initial mineralogical composition of the reservoir and cap rock as well as on the brine compositions. Nevertheless, a wide range of conditions for safe CO2 storage is identified.

Experimental simulation of the geological storage of CO2: particular study of the interfaces between well cement, cap-rock and reservoir rock

International Nuclear Information System (INIS)

Jobard, Emmanuel

2013-01-01

The geological storage of the CO 2 is envisaged to mitigate the anthropogenic greenhouse gas emissions in the short term. CO 2 is trapped from big emitters and is directly injected into a reservoir rock (mainly in deep salty aquifers, depleted hydrocarbon oil fields or unexploited charcoal lodes) located at more than 800 m deep. In the framework of the CO 2 storage, it is crucial to ensure the integrity of the solicited materials in order to guarantee the permanent confinement of the sequestrated fluids. Using experimental simulation the purpose of this work is to study the mechanisms which could be responsible for the system destabilization and could lead CO 2 leakage from the injection well. The experimental simulations are performed under pressure and temperature conditions of the geological storage (100 bar and from 80 to 100 deg. C). The first experimental model, called COTAGES (for 'Colonne Thermoregulee A Grains pour Gaz a Effet de Serre') allows studying the effects of the thermal destabilisation caused by the injection of a fluid at 25 deg. C in a hotter reservoir (submitted to the geothermal gradient). This device composed of an aqueous saline solution (4 g.L -1 of NaCl), crushed rock (Lavoux limestone or Callovo-Oxfordian argillite) and gas (N 2 or CO 2 ) allows demonstrating an important matter transfer from the cold area (30 deg. C) toward the hot area (100 deg. C). The observed dissolution/precipitation phenomena leading to changes of the petro-physical rocks properties occur in presence of N 2 or CO 2 but are significantly amplified by the presence of CO 2 . Concerning the experiments carried out with Lavoux limestone, the dissolution in the cold zone causes a raise of porosity of about 2% (initial porosity of 8%) due to the formation of about 500 pores/mm 2 with a size ranging between 10 and 100 μm 2 . The precipitation in the hot zone forms a micro-calcite fringe on the external part of the grains and fills the intergrain porosity

Preliminary Modelling of the Effect of Impurity in CO2 Streams on the Storage Capacity and the Plume Migration in Pohang Basin, Korea

Science.gov (United States)

Park, Yongchan; Choi, Byoungyoung; Shinn, Youngjae

2015-04-01

Captured CO2 streams contain various levels of impurities which vary depending on the combustion technology and CO2 sources such as a power plant and iron and steel production processes. Common impurities or contaminants are non-condensable gases like nitrogen, oxygen and hydrogen, and are also air pollutants like sulphur and nitrogen oxides. Specifically for geological storage, the non-condensable gases in CO2 streams are not favourable because they can decrease density of the injected CO2 stream and can affect buoyancy of the plume. However, separation of these impurities to obtain the CO2 purity higher than 99% would greatly increase the cost of capture. In 2010, the Korean Government announced a national framework to develop CCS, with the aim of developing two large scale integrated CCS projects by 2020. In order to achieve this goal, a small scale injection project into Pohang basin near shoreline has begun which is seeking the connection with a capture project, especially at a steel company. Any onshore sites that are suitable for the geological storage are not identified by this time so we turned to the shallow offshore Pohang basin where is close to a large-scale CO2 source. Currently, detailed site surveys are being undertaken and the collected data were used to establish a geological model of the basin. In this study, we performed preliminary modelling study on the effect of impurities on the geological storage using the geological model. Using a potential compositions of impurities in CO2 streams from the steel company, we firstly calculated density and viscosity of CO2 streams as a function of various pressure and temperature conditions with CMG-WINPROP and then investigated the effect of the non-condensable gases on storage capacity, injectivity and plume migrations with CMG-GEM. Further simulations to evaluate the areal and vertical sweep efficiencies by impurities were perform in a 2D vertical cross section as well as in a 3D simulation grid. Also

Probabilistic Assessment of Above Zone Pressure Predictions at a Geologic Carbon Storage Site

Energy Technology Data Exchange (ETDEWEB)

Namhata, Argha; Oladyshkin, Sergey; Dilmore, Robert M.; Zhang, Liwei; Nakles, David V.

2016-12-01

Carbon dioxide (CO2) storage into geological formations is regarded as an important mitigation strategy for anthropogenic CO2 emissions to the atmosphere. This study first simulates the leakage of CO2 and brine from a storage reservoir through the caprock. Then, we estimate the resulting pressure changes at the zone overlying the caprock also known as Above Zone Monitoring Interval (AZMI). A data-driven approach of arbitrary Polynomial Chaos (aPC) Expansion is then used to quantify the uncertainty in the above zone pressure prediction based on the uncertainties in different geologic parameters. Finally, a global sensitivity analysis is performed with Sobol indices based on the aPC technique to determine the relative importance of different parameters on pressure prediction. The results indicate that there can be uncertainty in pressure prediction locally around the leakage zones. The degree of such uncertainty in prediction depends on the quality of site specific information available for analysis. The scientific results from this study provide substantial insight that there is a need for site-specific data for efficient predictions of risks associated with storage activities. The presented approach can provide a basis of optimized pressure based monitoring network design at carbon storage sites.

CO{sub 2} storage in saline aquifers; Stockage du CO{sub 2} dans les aquiferes salins

Energy Technology Data Exchange (ETDEWEB)

Bentham, M.; Kirby, G. [British Geological Survey (BGS), Kingsley Dunham Centre, Keyworth, Nottingham (United Kingdom)

2005-06-01

Saline aquifers represent a promising way for CO{sub 2} sequestration. Storage capacities of saline aquifers are very important around the world. The Sleipner site in the North Sea is currently the single case world-wide of CO{sub 2} storage in a saline aquifer. A general review is given on the specific risks for CO{sub 2} storage in saline aquifer. The regional distribution of CO{sub 2} storage potential is presented. Finally, the knowledge gaps and the future research in this field are defined. (authors)

Coupled Model for CO2 Leaks from Geological Storage: Geomechanics, Fluid Flow and Phase Transitions

Science.gov (United States)

Gor, G.; Prevost, J.

2013-12-01

Deep saline aquifers are considered as a promising option for long-term storage of carbon dioxide. However, risk of CO2 leakage from the aquifers through faults, natural or induced fractures or abandoned wells cannot be disregarded. Therefore, modeling of various leakage scenarios is crucial when selecting a site for CO2 sequestration and choosing proper operational conditions. Carbon dioxide is injected into wells at supercritical conditions (t > 31.04 C, P > 73.82 bar), and these conditions are maintained in the deep aquifers (at 1-2 km depth) due to hydrostatic pressure and geothermal gradient. However, if CO2 and brine start to migrate from the aquifer upward, both pressure and temperature will decrease, and at the depth of 500-750 m, the conditions for CO2 will become subcritical. At subcritical conditions, CO2 starts boiling and the character of the flow changes dramatically due to appearance of the third (vapor) phase and latent heat effects. When modeling CO2 leaks, one needs to couple the multiphase flow in porous media with geomechanics. These capabilities are provided by Dynaflow, a finite element analysis program [1]; Dynaflow has already showed to be efficient for modeling caprock failure causing CO2 leaks [2, 3]. Currently we have extended the capabilities of Dynaflow with the phase transition module, based on two-phase and three-phase isenthalpic flash calculations [4]. We have also developed and implemented an efficient method for solving heat and mass transport with the phase transition using our flash module. Therefore, we have developed a robust tool for modeling CO2 leaks. In the talk we will give a brief overview of our method and illustrate it with the results of simulations for characteristic test cases. References: [1] J.H. Prevost, DYNAFLOW: A Nonlinear Transient Finite Element Analysis Program. Department of Civil and Environmental Engineering, Princeton University, Princeton, NJ. http://www.princeton.edu/~dynaflow/ (last update 2013

Natural CO2 Analogs for Carbon Sequestration

Energy Technology Data Exchange (ETDEWEB)

Scott H. Stevens; B. Scott Tye

2005-07-31

The report summarizes research conducted at three naturally occurring geologic CO{sub 2} fields in the US. The fields are natural analogs useful for the design of engineered long-term storage of anthropogenic CO{sub 2} in geologic formations. Geologic, engineering, and operational databases were developed for McElmo Dome in Colorado; St. Johns Dome in Arizona and New Mexico; and Jackson Dome in Mississippi. The three study sites stored a total of 2.4 billion t (46 Tcf) of CO{sub 2} equivalent to 1.5 years of power plant emissions in the US and comparable in size with the largest proposed sequestration projects. The three CO{sub 2} fields offer a scientifically useful range of contrasting geologic settings (carbonate vs. sandstone reservoir; supercritical vs. free gas state; normally pressured vs. overpressured), as well as different stages of commercial development (mostly undeveloped to mature). The current study relied mainly on existing data provided by the CO{sub 2} field operator partners, augmented with new geochemical data. Additional study at these unique natural CO{sub 2} accumulations could further help guide the development of safe and cost-effective design and operation methods for engineered CO{sub 2} storage sites.

Increased N2O emission by inhibited plant growth in the CO2 leaked soil environment: Simulation of CO2 leakage from carbon capture and storage (CCS) site.

Science.gov (United States)

Kim, You Jin; He, Wenmei; Ko, Daegeun; Chung, Haegeun; Yoo, Gayoung

2017-12-31

Atmospheric carbon dioxide (CO 2 ) concentrations is continuing to increase due to anthropogenic activity, and geological CO 2 storage via carbon capture and storage (CCS) technology can be an effective way to mitigate global warming due to CO 2 emission. However, the possibility of CO 2 leakage from reservoirs and pipelines exists, and such leakage could negatively affect organisms in the soil environment. Therefore, to determine the impacts of geological CO 2 leakage on plant and soil processes, we conducted a greenhouse study in which plants and soils were exposed to high levels of soil CO 2 . Cabbage, which has been reported to be vulnerable to high soil CO 2 , was grown under BI (no injection), NI (99.99% N 2 injection), and CI (99.99% CO 2 injection). Mean soil CO 2 concentration for CI was 66.8-76.9% and the mean O 2 concentrations in NI and CI were 6.6-12.7%, which could be observed in the CO 2 leaked soil from the pipelines connected to the CCS sites. The soil N 2 O emission was increased by 286% in the CI, where NO 3 - -N concentration was 160% higher compared to that in the control. This indicates that higher N 2 O emission from CO 2 leakage could be due to enhanced nitrification process. Higher NO 3 - -N content in soil was related to inhibited plant metabolism. In the CI treatment, chlorophyll content decreased and chlorosis appeared after 8th day of injection. Due to the inhibited root growth, leaf water and nitrogen contents were consistently lowered by 15% under CI treatment. Our results imply that N 2 O emission could be increased by the secondary effects of CO 2 leakage on plant metabolism. Hence, monitoring the environmental changes in rhizosphere would be very useful for impact assessment of CCS technology. Copyright © 2017 Elsevier B.V. All rights reserved.

Geochemical modelling of worst-case leakage scenarios at potential CO2-storage sites - CO2 and saline water contamination of drinking water aquifers

Science.gov (United States)

Szabó, Zsuzsanna; Edit Gál, Nóra; Kun, Éva; Szőcs, Teodóra; Falus, György

2017-04-01

Carbon Capture and Storage is a transitional technology to reduce greenhouse gas emissions and to mitigate climate change. Following the implementation and enforcement of the 2009/31/EC Directive in the Hungarian legislation, the Geological and Geophysical Institute of Hungary is required to evaluate the potential CO2 geological storage structures of the country. Basic assessment of these saline water formations has been already performed and the present goal is to extend the studies to the whole of the storage complex and consider the protection of fresh water aquifers of the neighbouring area even in unlikely scenarios when CO2 injection has a much more regional effect than planned. In this work, worst-case scenarios are modelled to understand the effects of CO2 or saline water leaks into drinking water aquifers. The dissolution of CO2 may significantly change the pH of fresh water which induces mineral dissolution and precipitation in the aquifer and therefore, changes in solution composition and even rock porosity. Mobilization of heavy metals may also be of concern. Brine migration from CO2 reservoir and replacement of fresh water in the shallower aquifer may happen due to pressure increase as a consequence of CO2 injection. The saline water causes changes in solution composition which may also induce mineral reactions. The modelling of the above scenarios has happened at several methodological levels such as equilibrium batch, kinetic batch and kinetic reactive transport simulations. All of these have been performed by PHREEQC using the PHREEQC.DAT thermodynamic database. Kinetic models use equations and kinetic rate parameters from the USGS report of Palandri and Kharaka (2004). Reactive transport modelling also considers estimated fluid flow and dispersivity of the studied formation. Further input parameters are the rock and the original ground water compositions of the aquifers and a range of gas-phase CO2 or brine replacement ratios. Worst-case scenarios

Impact of CO_2 on the Evolution of Microbial Communities Exposed to Carbon Storage Conditions, Enhanced Oil Recovery, and CO_2 Leakage

International Nuclear Information System (INIS)

Gulliver, Djuna M.; Gregory, Kelvin B.; Lowry, Gregory V.

2016-01-01

Geologic carbon storage (GCS) is a crucial part of a proposed mitigation strategy to reduce the anthropogenic carbon dioxide (CO_2) emissions to the atmosphere. During this process, CO_2 is injected as super critical carbon dioxide (SC-CO_2) in confined deep subsurface storage units, such as saline aquifers and depleted oil reservoirs. The deposition of vast amounts of CO_2 in subsurface geologic formations could unintentionally lead to CO_2 leakage into overlying freshwater aquifers. Introduction of CO_2 into these subsurface environments will greatly increase the CO_2 concentration and will create CO_2 concentration gradients that drive changes in the microbial communities present. While it is expected that altered microbial communities will impact the biogeochemistry of the subsurface, there is no information available on how CO_2 gradients will impact these communities. The overarching goal of this project is to understand how CO_2 exposure will impact subsurface microbial communities at temperatures and pressures that are relevant to GCS and CO_2 leakage scenarios. To meet this goal, unfiltered, aqueous samples from a deep saline aquifer, a depleted oil reservoir, and a fresh water aquifer were exposed to varied concentrations of CO_2 at reservoir pressure and temperature. The microbial ecology of the samples was examined using molecular, DNA-based techniques. The results from these studies were also compared across the sites to determine any existing trends. Results reveal that increasing CO_2 leads to decreased DNA concentrations regardless of the site, suggesting that microbial processes will be significantly hindered or absent nearest the CO_2 injection/leakage plume where CO_2 concentrations are highest. At CO_2 exposures expected downgradient from the CO_2 plume, selected microorganisms emerged as dominant in the CO_2 exposed conditions. Results suggest that the altered microbial community was site specific and highly dependent on pH. The site

Some geomechanical aspects of geological CO2 sequestration

NARCIS (Netherlands)

Orlic, B.

2008-01-01

Reservoir depletion and subsequent CO 2 injection into the depleted geological reservoir induce stress changes that may mechanically damage top seal and wells, or trigger existing faults, creating the leakage pathways for CO 2 escape from the reservoir. The role of geomechanics is to assess the

Some geomechanical aspects of geological CO2 sequestration

NARCIS (Netherlands)

Orlic, B.

2009-01-01

Reservoir depletion and subsequent CO2 injection into the depleted geological reservoir induce stress changes that may mechanically damage top seal and wells, or trigger existing faults, creating the leakage pathways for CO2 escape from the reservoir. The role of geomechanics is to assess the

Geometry-coupled reactive fluid transport at the fracture scale -Application to CO 2 geologic storage

KAUST Repository

Kim, Seunghee

2015-08-19

Water acidification follows CO2 injection and leads to reactive fluid transport through pores and rock fractures, with potential implications to reservoirs and wells in CO2 geologic storage and enhanced oil recovery. Kinetic rate laws for dissolution reactions in calcite and anorthite are combined with Navier-Stokes law and advection-diffusion transport to perform geometry-coupled numerical simulations in order to study the evolution of chemical reactions, species concentration and fracture morphology. Results are summarized as a function of two dimensionless parameters: the Damköhler number Da which is the ratio between advection and reaction times, and the transverse Peclet number Pe defined as the ratio between the time for diffusion across the fracture and the time for advection along the fracture. Reactant species are readily consumed near the inlet in a carbonate reservoir when the flow velocity is low (low transverse Peclet number and Da>10-1). At high flow velocities, diffusion fails to homogenize the concentration field across the fracture (high transverse Peclet number Pe>10-1). When the reaction rate is low as in anorthite reservoirs (Da<10-1) reactant species are more readily transported towards the outlet. At a given Peclet number, a lower Damköhler number causes the flow channel to experience a more uniform aperture enlargement along the length of the fracture. When the length-to-aperture ratio is sufficiently large, say l/d>30, the system response resembles the solution for 1-D reactive fluid transport. A decreased length-to-aperture ratio slows the diffusive transport of reactant species to the mineral fracture surface, and analyses of fracture networks must take into consideration both the length and slenderness of individual fractures in addition to Pe and Da numbers.

Geometry-coupled reactive fluid transport at the fracture scale -Application to CO 2 geologic storage

KAUST Repository

Kim, Seunghee; Santamarina, Carlos

2015-01-01

Water acidification follows CO2 injection and leads to reactive fluid transport through pores and rock fractures, with potential implications to reservoirs and wells in CO2 geologic storage and enhanced oil recovery. Kinetic rate laws for dissolution reactions in calcite and anorthite are combined with Navier-Stokes law and advection-diffusion transport to perform geometry-coupled numerical simulations in order to study the evolution of chemical reactions, species concentration and fracture morphology. Results are summarized as a function of two dimensionless parameters: the Damköhler number Da which is the ratio between advection and reaction times, and the transverse Peclet number Pe defined as the ratio between the time for diffusion across the fracture and the time for advection along the fracture. Reactant species are readily consumed near the inlet in a carbonate reservoir when the flow velocity is low (low transverse Peclet number and Da>10-1). At high flow velocities, diffusion fails to homogenize the concentration field across the fracture (high transverse Peclet number Pe>10-1). When the reaction rate is low as in anorthite reservoirs (Da<10-1) reactant species are more readily transported towards the outlet. At a given Peclet number, a lower Damköhler number causes the flow channel to experience a more uniform aperture enlargement along the length of the fracture. When the length-to-aperture ratio is sufficiently large, say l/d>30, the system response resembles the solution for 1-D reactive fluid transport. A decreased length-to-aperture ratio slows the diffusive transport of reactant species to the mineral fracture surface, and analyses of fracture networks must take into consideration both the length and slenderness of individual fractures in addition to Pe and Da numbers.

Modeling CO2 Storage in Fractured Reservoirs: Fracture-Matrix Interactions of Free-Phase and Dissolved CO2

Science.gov (United States)

Oldenburg, C. M.; Zhou, Q.; Birkholzer, J. T.

2017-12-01

The injection of supercritical CO2 (scCO2) in fractured reservoirs has been conducted at several storage sites. However, no site-specific dual-continuum modeling for fractured reservoirs has been reported and modeling studies have generally underestimated the fracture-matrix interactions. We developed a conceptual model for enhanced CO2 storage to take into account global scCO2 migration in the fracture continuum, local storage of scCO2 and dissolved CO2 (dsCO2) in the matrix continuum, and driving forces for scCO2 invasion and dsCO2 diffusion from fractures. High-resolution discrete fracture-matrix models were developed for a column of idealized matrix blocks bounded by vertical and horizontal fractures and for a km-scale fractured reservoir. The column-scale simulation results show that equilibrium storage efficiency strongly depends on matrix entry capillary pressure and matrix-matrix connectivity while the time scale to reach equilibrium is sensitive to fracture spacing and matrix flow properties. The reservoir-scale modeling results shows that the preferential migration of scCO2 through fractures is coupled with bulk storage in the rock matrix that in turn retards the fracture scCO2 plume. We also developed unified-form diffusive flux equations to account for dsCO2 storage in brine-filled matrix blocks and found solubility trapping is significant in fractured reservoirs with low-permeability matrix.

The Baltic Basin: structure, properties of reservoir rocks, and capacity for geological storage of CO2

Directory of Open Access Journals (Sweden)

Vaher, Rein

2009-12-01

Full Text Available Baltic countries are located in the limits of the Baltic sedimentary basin, a 700 km long and 500 km wide synclinal structure. The axis of the syneclise plunges to the southwest. In Poland the Precambrian basement occurs at a depth of 5 km. The Baltic Basin includes the Neoproterozoic Ediacaran (Vendian at the base and all Phanerozoic systems. Two aquifers, the lower Devonian and Cambrian reservoirs, meet the basic requirements for CO2 storage. The porosity and permeability of sandstone decrease with depth. The average porosity of Cambrian sandstone at depths of 80–800, 800–1800, and 1800–2300 m is 18.6, 14.2, and 5.5%, respectively. The average permeability is, respectively, 311, 251, and 12 mD. Devonian sandstone has an average porosity of 26% and permeability in the range of 0.5–2 D. Prospective Cambrian structural traps occur only in Latvia. The 16 largest ones have CO2 storage capacity in the range of 2–74 Mt, with total capacity exceeding 400 Mt. The structural trapping is not an option for Lithuania as the uplifts there are too small. Another option is utilization of CO2 for enhanced oil recovery (EOR. The estimated total EOR net volume of CO2 (part of CO2 remaining in the formation in Lithuania is 5.6 Mt. Solubility and mineral trapping are a long-term option. The calculated total solubility trapping capacity of the Cambrian reservoir is as high as 11 Gt of CO2 within the area of the supercritical state of carbon dioxide.

Storage Utsira. Analysis of potentials and costs of storage of CO{sub 2} in the Utsira formation. Country report - Denmark

Energy Technology Data Exchange (ETDEWEB)

Grohnheit, P.E.

2010-05-15

This report is the main deliverable for Denmark in the project 'Analysis of potentials and costs of storage of CO{sub 2} in the Utsira Aquifer in the North Sea'. The project is funded by energinet.dk within FENCO-ERA, which is an EU network for national R and D activities in 13 countries in the field of fossil energy conversion and CO{sub 2} capture and storage (CCS). The project aims to analyze potential and costs of storage of CO{sub 2} in the Utsira aquifer in the North Sea for five countries surrounding the North Sea. So far, there has been very little interest in CCS in Denmark. The technology is not a part of public policy, and the Government has not expressed any official standpoint on the use of CCS in Denmark. On the other hand, both the electricity industry and geologists from the Geological Survey of Denmark and Greenland (GEUS) have been active in international research on both capture and storage. A very significant additional constraint for CCS in Denmark is the planned development of wind power, which will further reduce the need for base-load thermal electricity generation. For the model analysis in the Storage Utsira project it means that the potential for CCS is becoming increasingly constrained. To model these constraints, it means that the Pan European TIMES model, which has a structure that is harmonised to meet the requirements for 30 European countries, must be calibrated in further details to give a proper representation of the constrained potential for Denmark. It is unlikely that Denmark will need the CO{sub 2} storage capacity in Utsira within the time horizon of the study. However, in co-operation with other countries around the North Sea, the Danish potential for carbon storage may contribute to the build-up of the long-distance CO{sub 2} transport infrastructure. (ln)