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A numerical simulation study of co2 injection for enhancing hydrocarbon recovery and sequestration in liquid-rich shales

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Petroleum Science 2018年第1期15卷 103-115页

作者： Sumeer Kalra Wei Tian Xingru Wu Warwick Energy Group 900 W Wilshire BlvdOklahoma City OK 73116 USA University of Oklahoma 100 E Boyd St. Sec 1210 NormanOK 73019-1003 USA

Less than 10% of oil is usually recovered from liquid-rich shales and this leaves much room for improvement, while water injection into shale formation is virtually impossible because of the extremely low permeability of the formation matrix. Injecting carbon dioxide（co2） into oil shale formations can potentially improve oil recovery. Furthermore, the large surface area in organicrich shale could permanently store co2 without jeopardizing the formation integrity. This work is a mechanism study of evaluating the effectiveness of co2-enhanced oil shale recovery and shale formation co2 sequestration capacity using numerical simulation. Petrophysical and fluid properties similar to the Bakken Formation are used to set up the base model for simulation. Result shows that the co_2 injection could increase the oil recovery factor from7.4% to 53%. In addition, petrophysical characteristics such as in situ stress changes and presence of a natural fracture network in the shale formation are proven to have impacts on subsurface co2 flow. A response surface modeling approach was applied to investigate the interaction between parameters and generate a proxy model for optimizing oil recovery and co2 injectivity.

关键词： co2 EOR Tight formations Experimentaldesign Response surface modeling Recovery of shaleliquid co2 sequestration

co_2 sequestration from flue gas by direct aqueous mineral carbonation of wollastonite

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Science China(Technological Sciences) 2013年第9期56卷 2219-2227页

作者： YAN Heng ZHANG JunYing ZHAO YongChun ZHENG ChuGuang State Key Laboratory of coal combustion Huazhong University of Science and Technology

Emission of carbon dioxide is considered to be the main cause of the greenhouse effect. Mineral carbonation, an important part of the CCS technology, is an attractive option for long-term co2 sequestration. In this study, wollastonite was chosen as the feedstock and the feasibility of direct aqueous mineral carbonation in the simulated flue gas was investigated via a series of experimental studies carried in a stirred reactor. X-ray diffraction （XRD）, X-ray fluorescence spectroscopy （XRF）, ion chro- matography （IC） and thermal decomposition were used to determine the carbonation conversion. The influences of various factors, including reaction temperature, reaction pressure, solution composition, heat-treatment and particle size, were dis- cussed. concurrently, the effects of SO2 and NO presented in simulated flue gas were also investigated and a possible mecha- nism was used to explain the results. Experimental results show that reaction temperature, reaction pressure and particle size can effectively improve the carbonation reaction. Addition of 0.6 M NaHco3 was also proved to be beneficial to the reaction and heat-treatment is not needed for wollastonite to get a higher carbonation conversion. compared with carbonation in puri- fied co2 gas, co2 sequestration directly from simulated flue gas by mineral carbonation is suggested to have a certain degree of economic feasibility in the conditions of medium and low-pressure. A highest carbonation conversion of 35.9% is gained on the condition of T=150℃, P=40 bar and PS 〈30 μ in distilled water for 1 h.

关键词： co2 sequestration mineral carbonation wollastonite flue gas

Characteristics of co_2 sequestration in saline aquifers

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Petroleum Science 2010年第1期7卷 83-92页

作者： Yang Fang Bai Baojun Tang Dazhen Shari Dunn-Norman David Wronkiewicz School of Energy Resources China University of Geosciences Beijing 100083 China Department of Geological Sciences and Engineering Missouri University of Science and Technology Rolla MO 65401USA

Storage of co2 in saline aquifers is a viable option for reducing the amount of co2 released to the atmosphere. This paper provides an overall review of co2 sequestration in saline aquifers. First, the principles of co2 sequestration are presented, including co2 phase behavior, co2-water-rock interaction, and co2 trapping mechanisms. Then storage capacity and co2 injectivity are discussed as the main determinants of the storage potential of saline aquifers. Next, a site section process is addressed considering basin characteristics, reservoir characteristics, and economic and social concerns. Three main procedures are then presented to investigate the suitability of a site for co2 sequestration, including site screening, detailed site characterization, and pilot field-scale test. The methods for these procedures are also presented, such as traditional site characterization methods, laboratory experiments, and numerical simulation. Finally, some operational aspects of sequestration are discussed, including well type, injection rate, co2 purity, and injection strategy.

关键词： co2 sequestration saline aquifer site selection screening criteria geological storage storage capacity

The Development of Stylolites in Carbonate Formation: Implication for co_2 sequestration

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Acta Geologica Sinica(English Edition) 2014年第1期88卷 238-247页

作者： ZHOU Xuejun ZENG Zhengwen Department of GeoSciences Virginia Polytechnic Institute and State University Department of Geology and Geological Engineering University of North Dakota

The impact of co2 sequestration on the host formation is an issue occurring over geologic time. Laboratory tests can provide important results to investigate this matter but have limitations due to a relatively short timeline. Based on literature review and core sample observation, naturally occurred geological phenomena, stylolites are studied in this paper for understanding co2 sequestration in deep carbonate formations. Stylolites are distinctive and pervasive structures in carbonates that are related to water-assisted pressure solution. Pressure solution involving stylolitization is thought to be the main mechanism of compaction and cementation for many carbonates. In parallel, co2 sequestration in carbonate formation involves extensive chemical reactions among water, co2 and rock matrix, favoring chemical compaction as a consequence. An analogue between stylolites and co2 sequestration induced formation heterogeneity exists in the sense of chemical compaction, as both pressure solution in stylolites and co2 enriched solution in co2 sequestration in carbonate formations may all introduce abnormal porous regions. The shear and/or tension fractures associated with stylolites zones may develop vertically or sub-vertically; all these give us alert for long-term safety of co2 sequestration. Thus a study of stylolites will help to understand the co2 sequestration in deep carbonate formation in the long run.

关键词： Stylolites co2 sequestration compaction non-cataclastic behavior long-term safety

Lattice Boltzmann Simulation of co_2 Transport in Kerogen Nanopores——An Evaluation of co_2 sequestration in Organic-Rich Shales

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Journal of Earth Science 2017年第5期28卷 926-932页

作者： Sherifa Cudjoe Reza Barati Department of Chemical & Petroleum Engineering University of Kansas

Organic-rich shale resources remain an important source of hydrocarbons considering their substantial contribution to crude oil and natural gas production around the world. Moreover, as part of mitigating the greenhouse gas effects due to the emissions of carbon dioxide （co2） gas, organic-rich shales are considered a possible alternate geologic storage. This is due to the adsorptive properties of organic ke- rogen and clay minerals within the shale matrix. Therefore, this research looks at evaluating the seques- tration potential of carbon dioxide （co2） gas in kerogen nanopores with the use of the lattice Boltzmann method under varying experimental pressures and different pore sizes. Gas flow in micro/nano pores differ in hydrodynamics due to the dominant pore wall effects, as the mean free path （λ） of the gas molecules become comparable to the characteristic length （H） of the pores. In so doing, the traditional computational methods break down beyond the continuum region, and the lattice Boltzmann method （LBM） is employed. The lattice Boltzmann method is a mesoscopic numerical method for fluid system, where a unit of gas particles is assigned a discrete distribution function （/）. The particles stream along de- fined lattice links and collide locally at the lattice sites to conserve mass and momentum. The effects of gas-wall collisions （Knudsen layer effects） is incorporated into the LBM through an effective-relaxation- time model, and the discontinuous velocity at the pore walls is resolved with a slip boundary condition. Above all, the time lag （slip effect） created by co2 gas molecules due to adsorption and desorption over a time period, and the surface diffusion as a result of the adsorption-gradient are captured by an adsorption isotherm and included in our LBM. Implementing the Langmuir adsorption isotherm at the pore walls for both co2 gas revealed the underlying flow mechanism for co2 gas in a typical kerogen nano-pore is dominated by the slip flow regime. I

关键词： kerogen nanopores lattice Boltzmann method co2 sequestration slip flow Lang- muir isotherm.

Adsorption and desorption on coals for co_2 sequestration

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Mining Science and Technology 2009年第1期19卷 8-13页

作者： WANG Zuo-tang FU Zhen-kun ZHANG Bang-an WANG Guo-xiong RUDOLPH Victor HUO Li-wen State Key Laboratory of coal Resources and Mine Safety China University of Mining ＆ Technology Xuzhou Jiangsu 221008 China School of Mines China University of Mining ＆ Technology Xuzhou Jiangsu 221116 China college of Zijin Mining Fuzhou University Fuzhou Fujian 350108 China Chongqing Zhongliangshan coal-Electricity-Gas co. Ltd. Chongqing 400052 China School of Engineering University of Queensland Qld 4072 Australia Beijing Zhelong Mining Science and Technology co. Ltd. Beijing 100036 China

Adsorption and desorption of carbon dioxide, methane and other gases on coals has been investigated experimentally using representative Zhongliangshan coals. Gas adsorption is one of the major concerns for both co2 sequestration and methane recovery processes. The experiments were carried out using both single and multi-component mixtures at 25 ℃ and 30 ℃ with the highest pressure of 12 MPa. The coal was under moisture equilibrated conditions. This provides experimental data from which a predictive assessment of co2 sequestration and/or methane recovery can be conducted. The results show that for pure gasses the CH4 adsorption capacity is higher than the N2 adsorption capacity but lower than the co2 adsorption capacity. Injection of co2 or other gases into the coal significantly affects CH4 desorption. This allows the enhancement of CH4 recovery from the coals, thus supplying more clean energy while sequestering significant amounts of co2 thereby reducing the greenhouse effect from human beings.

关键词： multi-component co2 sequestration greenhouse gas

Interactions between the Design and Operation of Shale Gas Networks, Including co_2 sequestration

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Engineering 2017年第2期3卷 244-256页

作者： Sharifzadeh Mahdi Xingzhi Wang Nilay Shah Cenrer for Process Systems Engineering Department of Chemical Engineering Imperial College London London SW7 2AZ UK

As the demand for energy continues to increase, shale gas, as an unconventional source of methane(CH_4), shows great potential for commercialization. However, due to the ultra-low permeability of shale gas reservoirs, special procedures such as horizontal drilling, hydraulic fracturing, periodic well shut-in, and carbon dioxide(co_2) injection may be required in order to boost gas production, maximize economic benefits, and ensure safe and environmentally sound operation. Although intensive research is devoted to this emerging technology, many researchers have studied shale gas design and operational decisions only in isolation. In fact, these decisions are highly interactive and should be considered simultaneously. Therefore, the research question addressed in this study includes interactions between design and operational decisions. In this paper, we first establish a full-physics model for a shale gas reservoir. Next, we conduct a sensitivity analysis of important design and operational decisions such as well length, well arrangement, number of fractures, fracture distance, co_2 injection rate, and shut-in scheduling in order to gain in-depth insights into the complex behavior of shale gas networks. The results suggest that the case with the highest shale gas production may not necessarily be the most profitable design; and that drilling, fracturing, and co_2 injection have great impacts on the economic viability of this technology. In particular, due to the high costs, enhanced gas recovery(EGR) using co_2 does not appear to be commercially competitive, unless tax abatements or subsidies are available for co_2 sequestration. It was also found that the interactions between design and operational decisions are significant and that these decisions should be optimized simultaneously.

关键词： Shale gas Hydraulic fracturing Scheduling Well shut-in co2 sequestration Simultaneous optimization

Influence of SO_2 in incineration flue gas on the sequestration of co_2 by municipal solid waste incinerator fly ash

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Journal of Environmental Sciences 2013年第4期25卷 735-740页

作者： Jianguo Jiang Sicong Tian Chang Zhang School of Environment Tsinghua University Key Laboratory for Solid Waste Management and Environment Safety Ministry of Education of China

The influence of co2 content and presence of SO2 on the sequestration of co2 by municipal solid waste incinerator （MSWI） fly ash was studied by investigating the carbonation reaction of MSWI fly ash with different combinations of simulated flue gas. The reaction between fly ash and 100% co2 was relatively fast; the uptake of co2 reached 87 g co2/kg ash, and the sequestered co2 could be entirely released at high temperatures. When co2 content was reduced to 12%, the reaction rate decreased; the uptake fell to 41 g co2/kg ash, and 70.7% of the sequestered co2 could be released. With 12% co2 in the presence of SO2, the reaction rate significantly decreased; the uptake was just 17 g co2/kg ash, and only 52.9% of the sequestered co2 could be released. SO2 in the simulated gas restricted the ability of fly ash to sequester co2 because it blocked the pores of the ash.

关键词： municipal solid waste incinerator fly ash SO2 accelerated carbonation co2 sequestration simulated incineration flue gas

Sorption of methane and co_2 for enhanced coalbed methane recovery and carbon dioxide sequestration

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Journal of Natural Gas Chemistry 2008年第1期17卷 29-38页

作者： Basanta Kumar Prusty Central Institute of Mining and Fuel Research Barwa RoadDhanbad-826 001India

sequestration of co2 in deep and unmineable coal seams is one of the attractive alternatives to reduce its atmospheric concentration. Injection of co2 in coal seams may help in enhancing the recovery of coalbed methane. An experimental study has been carried out using coal samples from three different coal seams, to evaluate the enhanced gas recovery and sequestration potential of these coals. The coals were first saturated with methane and then by depressurization some of the adsorbed methane was desorbed. After partial desorption, co2 was injected into the coals and subsequently they were depressurized again. Desorption of methane after the injections was studied, to investigate the ability of co2 to displace and enhance the recovery of methane from the coals. The coals exhibited varying behavior of adsorption of co2 and release of methane. For one coal, the release of methane was enhanced by injection of co2, suggesting preferential adsorption of co2 and desorption of methane. For the other two coals, co2 injection did not produce incremental methane initially, as there was initial resistance to methane release. However with continued co2 injection, most of the remaining methane was produced. The study suggested that preferential sorption behavior of coal and enhanced gas recovery pattern could not be generalized for all coals.

关键词： coal coalbed methane co2 injection enhanced coalbed methane co2 sequestration