祁東煤礦3.0Mta新井設(shè)計(jì)含5張CAD圖.zip,祁東,煤礦,3.0,Mta,設(shè)計(jì),CAD 英文原文 Simulation of CO2-geosequestration enhanced coal bed methane recovery with a deformation-flow coupled model WangZuo-tanga,b,c*,Wang Guo-xiongb,Rudolph V.b,Diniz da Costa J.C.b, Huang Pei-ming cand Xin Lina aSchool of Mining, State Key Lab. of Safety Mining, China University of Mining and Technology, Xuzhou 221116, CHINA bSchool of Chemical Engineering, The University of Queensland, Qld 4072, Australia cCollege of ZiJin Mining, Fuzhou University, Fuzhou 350108, China Abstract:Coal bed methane (CBM) recovery and CO2 sequestration into coal seams coupled with enhanced CBM recovery have been recognized as an economically effective and environmentally friendly technology to improve the utilization of coal reserves. However, implementation of CBM and CO2 enhanced CBM (CO2-ECBM) production involves complex deformation-flow interactions in the coal. These aspects and their fundamental understanding remain as major concerns for CBM/ECBM modeling. Increasing interest in CBM and potentially in CO2-ECBM technology requires accurate predictive modeling to minimize investment risks. This paper proposed a deformation-flow coupled model to address aspects of model improvement. This model was developed based on nonlinear elastic deformation mechanics and gas percolation theory and implemented using an established computer program named F-RFPA2D - 2D Flow-coupled Rock Failure Process Analysis code. The numerical simulations of this model were carried out according to a CO2 capture and sequestration (CCS) integrated underground coal gasification (UCG) process designed for Zhongliangshan coal mine in southwest China. The individual operations comprising (1) conventional CBM recovery andCO2 sequestration into coal and (2) the integrated operation of CBM recovery with CO2 enhancement were numerically investigated, respectively. The results show that CO2 sequestration into the coal bed promotes rapid transport of CBM towards the gas producer wells with a longer production period and can enhance coal bed methane recovery by up to 80% under the conditions of using this this study. Keywords:coal bed methane (CBM); CBM recovery;CO2sequestration;CO2enhanced CBM (CO2-ECBM);numerical simulation 1. Introduction Coal is one of the dominant and abundant energy sources in the world and will become even more importantwhen oil and gas sources become more expensive to produce. However, directly utilizing coal by conventional technologies is causing serious concerns resulting from the high emission of CO2 which is associated with climate change1 Many attempts have been made to reduce the CO2 emission from coal sourced energy by means of various new or alternative technologies. An effective possibility is to integrate CO2 capture and sequestration (CCS) with coal utilization processes[2-3]. However, CCS is expensive and its practical application would be advantageous if equal or additional benefits are available through CO2 sequestration. Coal bed methane (CBM) is associated with CO2 injection as an enhancement agent, i.e. CO2-ECBM recovery, may present an attractive option for CCS, providing an economical solution to reduce CO2 emission from coal utilization processe[4-5] Commonly, CBM production relies on pressure depletion in a coal reservo ir which provides the primary recovery. Because the methane is adsorbed on the coal even at low pressures, this only allows a limited amount of the gas in place to be produced and typically 30-70% of the gas resource is never recovered[6],CO2sequestration into coal seam can significantly improve this, permitting access to most of the remaining gas[6-9].The CO2 has a stronger affinity for the coal than methane and also a greater adsorption capacity, 2 to 10 times depending on coal rank at normal reservoir pressures[10]and displaces the methane which is then available for recovery. Thus CO2ECBM could recover the large majority of the methane-in-place, while also having the added benefit that a large volume of greenhouse gas is sequestered in the coal. There are many factors that affect the CBM and CO2-ECBM processes. One of the most important is the dynamic response of coal bed permeability to methane production and CO2 injection[11].This comes about because of the structural deformation of the coal, caused by coal matrix shrinkage or swelling as desorption or adsorption of gases occurs[12-13], and volumetric changes that occur as the system stresses respond to water drainage and gas injection/drainage[14]. The extent of deformation determines the dynamic permeability and hence the transport of gases, influencing both the rate and capacity of the coal bed reservoir to accommodate CO2 storage and provide methane production. In particular, the interaction of deformation and fluid flow in coal beds is one of the major unknowns in CBM and CO2-ECBM processes. Within China, development of unconventional natural gas from coal has become an important part of energy policy, because of its increasing demand for fuel and constrained energy supply. Many efforts have been made in the past decade to obtain clean energy from the countries’relatively rich coal reserver. A successful example is the commercial application of underground coal gasification (UCG), for which planning is now underway to integrate with CCS for CO2-ECBM recovery. This paper presents a preliminary study on the feasibility of such an integration technology based on a field project recently carried out in Zhongliangshan coal mine. 2. Background Zhongliangshan coal mine, close to Chongqing in southwest China, has a coal reserve exceeding 78 million tons (Mt), containing acoal bed gas reserves of more than 400 billion m3 The coal mine extends over 10 km along a south-west direction, tapping 10 coal seams with a total thickness of 9.4m. Currently there are two underground mining wells at the south and west ends, which have so far produced about 25 Mt coal. The mining operation also results in a substantial volume of coal mine methane (CMM), most of which is released to the atmosphere. To improve the safety of underground operations and provide some beneficial use of the CMM, Zhongliangshan coal mine has been using a degasification system that employs vertical wells to pre-drain and recover methane for internal power production and residential use. However drainage alone does not release all of the methane from these gas rich seams and is constrained to a maximum rate of 25 million m3 annually. Furthermore, additional gas can readily find a market. To meet the twin demand for more gas and maximize coal utilization, the mine initiated an ambitious CCS-integrated underground coal gasification (UCG) project in 2005. This project sought to develop an improved UCG process to produce hydrogen from coal syngas and use CO2-ECBM to boost coal bed methane production. According to the design, coal is gasified underground by injecting air atomized water to produce syngas that, after cleaning up, mainly consists of CO, CO2, H2 and CH4. The syngas, sweetened with some methane from CBM and CMM operations, are further reformed with steam in a catalytic shift conversion reactor to CO2 and H2, allowing CO2 capture for H2 production. This process separates the syngas into its constituents and the CO2 fraction can be then used for CO2-ECBM recovery, simultaneously sequestering the CO2 and gaining the associated environmental benefit. A field test on the underground coal gasification process (itself rather unusual in concept and execution) has been completed and controllable UCG operation and stable process gas production has been demonstrated. Design for the carbon capture process has been completed and construction is in progress. The next step is to consider the design for the CO2-ECBM systems, establish performance of CO2-ECBM production and validate CO2 sequestration. The initial part of this work is through numerical simulations for the CBM and CO2-ECBM recovery processes and sensitivities. 3. Model description Coal seam is typically a porous and fractured medium, containing coal bed gases, mainly methane. Stresses in the seam will re-distribute as the CBM is extracted or CO2 is injected, and hence the permeability varies. The result is a time and location dependent change in the gas pressure in the pores and fractures, with corresponding impact on the transportation and flow of fluid in the coal seam. This highly coupled process, involving fracture mechanics and fluid dynamics, needs to be addressed in CBM/ECBM reservoir simulation. The deformation of coal seam during gas extraction and injection can mathematically be described using a stress- stain model employing Biot's theory of consolidation. The model, using conventional coordinate notation, comprises three governing equations, i.e. for the stress balance in any deformable body, subject to the geometrical constraints and the constitutive relationships where f and p are body force and pore-fluid pressure; a and s denote stress and strain;＆andεν effective stress and volumetric strain, respectively; u represents strain displacement; a is coefficient of pore-fluid pressure; δ is Kronecher delta; and 2 and G are Lame coefficient and modulus of shear deformation, respectively. The pore-fluid pressure in this deformation model is dynamic and can be described with the modified Darcy law for the fluid flow in porous medium, giving where k depicts permeability and Sp is a pressure-depended coefficient which can be estimated from where ? and γm are porosity and density of coal, respectively; p0 is standard atmospheric pressure; and a and b denote Langmuir-style volumetric and pressure constants, respectively Stress-sensitive permeability is an unusual feature in CBM and ECBM processes which needs to be numerically simulated through a coupled analysis of the deformation and fluid transport. An empirical approach is employed here to relate permeability and stress where k0 is initial permeability and P is a coupling parameter that reflects the impact of stress on the permeability. Eq. (6) can be extended to two or three dimensions, in which cases σ' represents the principal component of the effective stress. 4. Numerical implementation The deformation-flow coupled model, described by Eqs. (1) to (6), are implemented and solved numerically to simulate CBM and CO2-ECBM recovery processes. The results reported here use well test conditions that will provide seam stress damage, highly accelerated well interactions and exaggerated permeability changes, although the geological conditions are generally appropriate to the in-situ environment. We apply the numerical code F- RFPA2D for a coal seam as illustrated in Fig.1. In the coal seam the rock roof and floor consist of sandstone and clay rock respectively, which aligns with the geologic structure of the Zhongliangshan coal mine. These are assumed to be hard and impermeable, so that the model in this simple case is well bounded. The coal seam between rock roof and floor is about 1m thick and initially saturated with CBM. The case study assumes two wellbores, one used as the exaction well for CBM recovery and the other as the injection well for CO2sequestration. The distance between the two wells is 100 m. The original overburden (vertical) stress, σν is assumed to be 10 MPa (mimicking the reservoir pressure) based on geological conditions at the Zhongliangshan coal mine. The gas pressure at the well bottom is 0.1 MPa (about 1 atm) for extraction and 15 MPa for CO2 sequestration. Other mechanical and fluid properties are listed in Table 1. The F- RFPA2D program, developed by Northeastern University, China incorporates 2D gas flow, gas pressure and the rock failure process analysis (i.e. permeability change). It has been successfully used for simulation of the progressive fracture and fragmentation of coal and gas outburst under mining conditions. The code uses a finite element method (FEM) for rock failure process analysis and has been extended to include a fluid flow module for CBMECBM. The program logic is shown in Fig.2. To use the F- RFPA2D code, the physical model described in Fig.1 was discredited into 100x200 meshes, forming 20 thousand elements. The mechanical strength and material properties in coal are assumed to be randomly distributed amongst these elements, giving a heterogeneity with a Weibull distribution where s ands0 denote the actual and mean values of variables such as Young's modulus, compressive strength andpermeability; m is a heterogeneity index which is a reflection of the shape of the distribution function or the degreeof material heterogeneity. Table 1. Mechanical and transport properties for simulation. 5 results and discussion Fig.3 show the typical pressure profiles around the wellbores simulated for a single well operation with gasextraction (Fig.3a) and injection (Fig.3b) at various periods, respectively. The gas drainage and injection quicklyestablish pressure gradients within -25m of surrounding the wellbores, providing driving forces for the CBMrecovery and CO2 sequestration. As expected, the radial gradation of pressure decreasing over the course of both gasextraction and CO2 injection. The active regions in which adsorption and desorption occur in coal seam expandaccordingly. As a result, the fluid flow through coal seam tends to be quite stable over the normal operating periodfor gas extraction and CO2 sequestration. A number of cases are examined. Fig.4a illustrates the isobars around the extraction well when this is operated inisolation i.e. no CO2 injection. Fig.4b shows the isobars around the injection well, if that is operated without anyCBM extraction. Both cases result in gas pressure changes in the coal seam. However, compared with CBMextraction in which the operation pressure is very low, CO2 sequestration into coal seam seems more significant informing uneven fluid flow in the coal bed due to a relatively high operation pressure. Therefore operation pressurecan significantly affect the distribution of gas pressure and hence the mechanical and transport behaviors in coalseam during CBM recovery and CO2 sequestration. On the other hand, mechanical strength and material propertiesin coal seam are heterogeneous as implied in current model. These heterogeneities also contribute to themisdistribution of gas pressure, leading to uneven fluid flow and other physical behaviors includingadsorption’desorption in coal. CO2 sequestration into coal seam is typically used as a measure to enhance CBM recovery. The CO2-ECBM recovery process was simulated in the current study and the typical result is shown in Fig.5. The result describes gas pressure distributions around wellbores on the 5th day under operation for CO2-ECBM recovery. It can be found that the injected CO2 significantly changed the pressure field around the CBM extraction wellbore while the operation maintained similar pressure distribution around the injection wellbore. The active region for CBMrecovery s apparently enlarged compared with CBM extraction without CO2 injection (refer to Fig.4a). In this case an increasing percolation flow from injection wellbore towards CBM extraction wellbore is formed, allowing the increasing CBM extraction. Meanwhile the relatively high CO2 pressure not only prolongs the fluid flow towards the extraction wellbote, but also promotes the desorption of methane from coal because of the decreased partial pressure of methane in coal bed. Moreover CO2 has a stronger adsorption capacity than methane and the methane in coal will be partially replaced with the injected CO2. As a result of such a competitive sorption, CO2 injection efficiently enhances the CBM recovery. The feasibility of Co2-enhanced CBM recovery from the given coal seam can further be verified by investigating the percolation velocity of gas in coal seam towards extraction wellbore. For this purpose, the proposed model was employed to simulate the gas percolation through coal seam, associated with the operations of extraction wellbore with and without CO2injection. The typical results on the 5th day under the operations are shown as Fig.6. These results clearly indicate that injecting CO2 largely speeds motion of desorbed CBM towards to the extraction wellbore, which accordingly enlarges the percolation area. Under the given conditions in this study, the percolation velocity in the region close to the extraction wellbore for CO2-enhanced CBM recovery is about twice compared with the CBM recovery without CO2-enhanced operation. The numerical simulations also provide the CBM production of a single well under operations including andwithout CO2 injection. Fig.7 shows the results for CBM production with time. The results suggest that CBMrecovery reaches a stable production period after about 60 days. The accumulated CBM production increases from5000 Nm3without enhancement to 8500 Nm3 with CO2-ECBM assistance. In other words, CO2-ECBM recovery canincrease CBM production rate by 70-80% on average in the steady flow period, under the conditions assumed inthis study. 6. Conclusions Coal bed methane (CBM) and/or CO2-ECBM recovery processes accompanied with internal deformation andmethane transportation in coal simultaneously both play an important role in improving CBM production. The deformation-flow interaction in coal is one of the major concerns in modeling CBM recovery and CO2sequestrationin coal, and has not been fully understood yet. A deformation-flow coupled model is proposed in the current study toaddress this issue. This model is developed based on nonlinear elastic deformation mechanics and gas percolationtheory and implemented using an established 2D Flowing-coupled Rock Failure Process Analysis F-RFPA2D code. The numerical simulations with the model are carried out according to a designed CO2 capture and sequestration (CCS) integrated underground coal gasification (UCG) process. The individual operations of the conventional CBMrecovery and CO2 sequestration in coal and the integrated operation of CBM recovery with CO2 enhancement are numerically investigated, respectively. The results suggest that CO2 sequestration in coal bed can promote the transportation of coal bed methane towards gas extracting wellbore with a longer production period and can enhance coal bed methane recovery up to 80% under the given conditions in this study. Acknowledgements The authors wish to acknowledge financial support from the Australian Research Council (ARC) and by the Cultivation Fund of the Key Scientific and Technical Innovation Project, Ministry of Education of China (No.02019), and NSFC of China-Australia Cooperation Project (No.407112365, 40730422). 參考文獻(xiàn) [1] J. Gale, Overview of CO2emission sources, potential, transport and geographical distribution of storage possibilities. the IPCC Workshopon Carbon Dioxide Capture and Storage, Regina, Canada, Energy Research Centre of the Netherlands, Petten.2002. [2] IEA, Prospects for CO2capture and storage, International Energy Agency (IEA), Paris, France, 2004. [3] M. Mazzotti and R. Pini, Enhanced coal bed methane recovery. J. of Supercritical Fluids 47 (2009) 619-627. [4] F. Van Bergen and J. Gale, Worldwide selection of early opportunities for CO2-enhanced oil recovery and CO2-enhanced coal bedmethane production. Energy, 29 (2004) 1611-1621. [5] C. M. White and D. H. 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