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A New Technology for the Exploration of Shale Gas Reservoirs.

作者：Jing, W.;Huiqing, L.;Rongna, G.;Aihong, K.;Mi, Z. 刊名：Petroleum Science and Technology 出版日期：2011 卷号：Vol.29 期号：No.23 页码：2450-2459

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Abstract: Energy consumption in the world increases 5.6% every year, and alternative resources like shale gas, coal-bed methane (CBM), tar sand, and so on are strongly needed. Shale gas is an unconventional natural gas of enormous potential. Abundant shale gas resides in the form of adsorption gas. Desorption of shale gas is an important mechanism and power source of shale gas reservoir development. Based on the features of shale gas reservoirs, the adsorption/desorption mechanisms, and their influencing factors, high-temperature mixture gas flooding is proposed in this article. Combining the theories of surface chemistry, chemical thermodynamics, and physical chemistry, this article investigates the mechanisms of developing shale gas reservoirs by high-temperature mixture gas flooding, which are illustrated in the following aspects: (1) increasing temperature to accelerate desorption; (2) competitive adsorption, lowering partial pressure of CH4, and accelerating diffusion; (3) increasing moisture on the shale surface; (4) decreasing total organic content (TOC) and improving permeability; and (5) providing displacement energy.

题名：页岩气藏勘探新技术

摘要要点：研究通过高温混合气溢出开发页岩气藏的机理，包含（1）以提高温度来加速解吸，（2）竞争吸附，减低CH4局部压力,以及加速扩散，(3)增加页岩表面湿度，（4）减少总有机含量(TOC)，改善渗透性，（5）提供置换能量。

Process Design and Integration of Shale Gas to Methanol

作者：Victoria M. Ehlinger;Kerron J. Gabriel;Mohamed M. B. Noureldin;Mahmoud M. El-Halwagi 刊名：ACS Sustainable Chemistry & Engineering 出版日期：2014 卷号：Vol.2 期号：No.1 页码：30-37

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Abstract: The substantial discoveries of shale gas present many opportunities for the chemical, petrochemical, and fuel industries. As in conventional natural gas, shale gas contains primarily methane, but some formations contain significant amounts of higher molecular weight hydrocarbons and inorganic gases such as nitrogen and carbon dioxide. These differences present several technical challenges to incorporating shale gas with the current infrastructure designed to be used with natural gas. This paper is aimed at process synthesis, analysis, and integration of the production of methanol from shale gas. The composition of the shale gas feedstock is assumed to come from the Barnett Shale play located near Fort Worth, Texas, which is currently the most active shale gas play in the United States. Process simulation using ASPEN Plus along with published data were used to construct a base-case scenario. Key performance indicators were assessed. These include overall process targets for mass and energy and economic performance. A sensitivity analysis is carried out to assess the impact of the methanol selling price and shale gas price on the profitability of the process. Energy integration including process cogeneration was carried out to enhance the sustainability and profitability of the process. Finally, a techno-economic analysis was carried out to estimate the price differential for shale gas at the wellhead compared to pipeline quality natural gas.

题名：以页岩气制备甲醇工艺流程设计与整合

摘要要点：以页岩气制备甲醇工艺流程合成、分析与整合。

Impact of temperature on the isothermal adsorption/desorption of shale gas

作者：Wei GUO;Wei XIONG;Shusheng GAO;Zhiming HU;Honglin LIU;Rongze YU 刊名：Petroleum Exploration and Development 出版日期：2013 卷号：Vol.40期号：No.4 页码：514-519

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Abstract：Isothermal adsorption and desorption experiments under different temperatures were carried out with the Longmaxi Formation shale samples collected from southern Sichuan. The experimental results show that temperature affects the adsorption and desorption capacity of shale, the adsorption capacity of shale decreases with temperature increase. The adsorption curve and desorption curve of shale are not coincident and the thermodynamic reason for the hysteresis of the desorption curve is that the isosteric heat of the shale adsorption process is greater than that of the desorption process. The Langmuir model and desorption model can describe the isothermal adsorption and desorption processes very well, respectively. Isothermal adsorption and desorption curves under different temperatures can be predicted by isosteric heat curves which match the experimental results. Shale gas production is a process of gas desorption and the desorption characteristics directly impact the production of shale gas, so the desorption model should be taken into consideration in the shale gas production forecast and numerical simulation.

题名：温度对页岩气等温吸附/解吸的影响

摘要要点：页岩气吸附能力随温度的增加而降低；以Langmuir模型和解吸模型分别阐述等温吸附和解吸过程；在不同温度下等温吸附和解吸曲线可通过等量吸附热曲线预测。

On a boundary layer problem related to the gas flow in shales

作者：G. I. Barenblatt;P. J. M. Monteiro;C. H. Rycroft 刊名：Journal of Engineering Mathematics 出版日期：2014 卷号：Vol.84 期号：No.1 页码：11-18

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Abstract: The development of gas deposits in shales has become a significant energy resource. Despite the already active exploitation of such deposits, a mathematical model for gas flow in shales does not exist. Such a model is crucial for optimizing the technology of gas recovery. In the present article, a boundary layer problem is formulated and investigated with respect to gas recovery from porous low-permeability inclusions in shales, which are the basic source of gas. Milton Van Dyke was a great master in the field of boundary layer problems. Dedicating this work to his memory, we want to express our belief that Van Dyke’s profound ideas and fundamental book Perturbation Methods in Fluid Mechanics (Parabolic Press, 1975) will live on—also in fields very far from the subjects for which they were originally invented.

题名：页岩气流的边界层问题

摘要要点：页岩气流数学模型至今还没有学者建立，而这模型是优化采气技术的关键。本文提出和研究边界层问题，以缅怀Milton Van Dyke在该领域的卓越贡献。

A numerical study of performance for tight gas and shale gas reservoir systems

作者：C.M. Freeman;G. Moridis;D. Ilk;T.A. Blasingame 刊名：Journal of Petroleum Science and Engineering 出版日期：2013 卷号：Vol.108 页码：22-39

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Abstract: Various analytical, semi-analytical, and empirical models have been proposed to characterize rate and pressure behavior as a function of time in tight gas and shale gas systems featuring horizontal wells with multiple hydraulic fractures. Despite a few analytical models, as well as a small number of published numerical studies, there is currently little consensus regarding the large-scale flow behavior over time in such systems, particularly regarding the dominant flow regimes and whether or not reservoir properties or volumes can be estimated from well performance data.

We constructed a fit-for-purpose numerical simulator which accounts for a variety of production features pertinent to these systems—specifically ultra-tight matrix permeability, hydraulically fractured horizontal wells with induced fractures of various configurations, multiple porosity and permeability fields, and desorption. These features cover the production mechanisms which are currently believed to be most relevant in tight gas and shale gas systems.

We employ the numerical simulator to examine various tight gas and shale gas systems and to identify and illustrate the various flow regimes which progressively occur over time. We perform this study at fine grid discretization on the order of 1 mm near fractures to accurately capture flow effects at all time periods. We visualize the flow regimes using specialized plots of rate and pressure functions, as well as maps of pressure and sorption distributions.

We use pressure maps to visualize the various flow regimes and their transitions in tight gas systems. In a typical tight gas system, we illustrate the initial linear flow into the hydraulic fractures (i.e., formation linear flow), transitioning to compound formation linear flow, and eventually transforming into elliptical flow. We explore variations of possible shale gas system models. Based on diffusive flow (with and without desorption), we show that due to the extremely low permeability of shale matrix (a few nanodarcies), the flow behavior is dominated by the extent of and configuration of the fractures.

This work expands our understanding of flow behavior in tight gas and shale gas systems, where such an understanding may ultimately be used to estimate reservoir properties and reserves in these types of reservoirs.

题名：密集气体和页岩气藏系统特性的数值研究

摘要要点：构建了描述页岩气系统物理特性的数值模型，利用该模型量化阐述演化流体；利用压力与吸附图可视化流体；显示流体状态受制于断裂程度。

Multiscale, Multiphysics Network Modeling of Shale Matrix Gas Flows ; Ayaz Mehmani;Maša Prodanović;Farzam Javadpour

Transport in Porous Media ; 0169-3913 ; 2013;99卷 ;2期 ;377页 ;共390页

Abstract: We present a pore network model to determine the permeability of shale gas matrix. Contrary to the conventional reservoirs, where permeability is only a function of topology and morphology of the pores, the permeability in shale depends on pressure as well. In addition to traditional viscous flow of Hagen–Poiseuille or Darcy type, we included slip flow and Knudsendiffusion in our network model to simulate gas flow in shale systems that contain pores on both micrometer and nanometer scales. This is the first network model in 3D that combines pores with nanometer and micrometer sizes with different flow physics mechanisms on both scales. Our results showed that estimated apparent permeability is significantly higher when the additional physical phenomena are considered, especially at lower pressures and in networks where nanopores dominate. We performed sensitivity analyses on three different network models with equal porosity; constant cross-section model (CCM), enlarged cross-section model (ECM) and shrunk length model (SLM). For the porous systems with variable pore sizes, the apparent permeability is highly dependent on the fraction of nanopores and the pores’ connectivity. The overall permeability in each model decreased as the fraction of nanopores increased

题名：页岩基质气流的多尺度多物理网络建模

摘要有点：以细孔网络模型来确定页岩气基质的渗透性。与传统气藏截然相反，页岩渗透性也取决于压力。本文网络模型中包含滑流和Knudsen扩散来模拟既含有微米级又含有纳米级的页岩体中的气流。这是首个3D网络模型，它把具有不同流体机理的纳米级和微米级细孔进行综合考虑。

Molecular simulation and experimental characterization of the nanoporous structures of coal and gas shale.

作者：Firouzi, Mahnaz;Rupp, Erik C.;Liu, Corey W.;Wilcox, Jennifer 刊名：International Journal of Coal Geology 出版日期：2014 卷号：Vol.121 页码：123-128

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Abstract: Characterization of coal and shale is required to obtain pore size distribution (PSD) in order to create realistic models to design efficient strategies for carbon capture and sequestration (CCS) at full scale. Proton nuclear magnetic resonance (NMR) cryoporometry and low-pressure gas adsorption isothermal experiments, conducted with N2 at 77 K over a P/P0 range of 10− 7 to 0.995, were carried out to determine the PSD and total pore volumes to provide insight into the development of realistic simulation models for the organic matter comprising coal and gas shale rock. The PSDs determined on the reference materials (SiliaFlash F60 and Vycor 7930) show a reasonable agreement between low-pressure gas adsorption and NMR cryoporometry showing complementarity of the two independent techniques. The PSDs of coal and shale samples were determined with low-pressure gas adsorption isothermal experiments, but were unable to be measured by NMR cryoporometry. This is likely due to a combined size and pore surface chemistry effect that prevents the water from condensing in the pores, such that when the sample is heated there is no distinction based upon melting or phase change. Molecular modeling is carried out to create the pore structure network in which the transport and adsorption predictions are based. The three-dimensional (3D) pore network, representative of porous carbon-based materials, has been generated atomistically using the Voronoi tessellation method. A comparison of the computed PSD using this method was made to the measured PSD using isothermal low-pressure gas adsorption isothermal experiments on coal and gas shale samples. Applications of this work will lead to the development of more realistic 3-D models from which enhanced understanding of gas adsorption and transport for enhanced methane recovery and CO2 storage applications can be developed.

题名：煤与气页岩纳米孔结构的分子模拟与试验特征

摘要有点：通过煤与页岩石的特征化来获得气孔分布(PSD)；以核磁共振成像试验确定PSD;通过低压气体吸附等温试验确定PSD；利用Voronoi镶嵌式布局方法创建3D气孔网络模型。

Sensitivity analysis of hydraulic fracture geometry in shale gas reservoirs ; W. Yu;Z. Luo;F. Javadpour;A. Varavei;K. Sepehrnoori

Journal of Petroleum Science and Engineering ; 0920-4105 ; 2014;113卷 ;1页 ;共7页

Abstract: The combination of horizontal drilling and multiple hydraulic fracturing has been widely used to stimulate shale gas reservoirs for economical gas production. Numerical simulation is a useful tool to optimize fracture half-length and spacing in a multistage fracturing design. We developed a methodology to use a commercial reservoir simulator to simulate production performance of shale gas reservoirs after fracturing. We verified our simulation method with the available field data from the Barnett Shale. In this work, we performed a sensitivity study of gas production for a shale gas well with different geometries of multiple transverse hydraulic fractures, in which fractures' half-lengths vary. Hydraulic fractures are divided into two outer and inner fracture groups. The simulation results revealed that the outer fractures contribute more to gas production when fracture spacing is small due to the effect of fracture interference. Also, we studied the effects of fracture half-length and fracture spacing on gas production. This work can provide some insights into characterization of hydraulic fracture geometry on the basis of production data in shale gas reservoirs.

题名：页岩气藏水力压裂形状灵敏度分析

摘要要点：开发出用商业气藏模拟器模拟裂变后页岩气藏生产特性的方法；用Barnett现场数据验证数值模型有效性；论述外内水力压裂干涉（干扰）对采气的影响。

Klinkenberg effect on predicting and measuring helium permeability in gas shales.

作者：Firouzi, Mahnaz;Alnoaimi, Khalid;Kovscek, Anthony;Wilcox, Jennifer 刊名：International Journal of Coal Geology 出版日期：2014 卷号：Vol.123 页码：62-68

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Abstract: To predict accurately gas-transport in shale systems, it is important to study the transport phenomena of a non-adsorptive gas such as helium to investigate gas “slippage”. Non-equilibrium molecular dynamics (NEMD) simulations have been carried out with an external driving force imposed on the 3-D carbon pore network generated atomistically using the Voronoi tessellation method, representative of the carbon-based kerogen porous structure of shale, to investigate helium transport and predict Klinkenberg parameters. Simulations are conducted to determine the effect of pressure on gas permeability in the pore network structure. In addition, pressure pulse decay experiments have been conducted to measure the helium permeability and Klinkenberg parameters of a shale core plug to establish a comparison between permeability measurements in the laboratory and the permeability predictions using NEMD simulations. The results indicate that the gas permeability, obtained from pulse-decay experiments, is approximately two orders of magnitude greater than that calculated by the MD simulation. The experimental permeability, however, is extracted from early-time pressure profiles that correspond to convective flow in shale macropores (> 50 nm). That is, pore diameters estimated from the measured permeability are greater than 50 nm.

题名：预测气页岩氦渗透性的滑脱效应

摘要有点：用Voronoi嵌入式布局方法产生的施加在3D碳孔网上的外驱力进行非平衡分子动力学模拟，以该模拟确定压力对气孔网构造中气体渗透性的影响。

Measurement of gas storage processes in shale and of the molecular diffusion coefficient in kerogen ; S. Reza Etminan;Farzam Javadpour;Brij B. Maini;Zhangxin Chen

International Journal of Coal Geology ; 0166-5162 ; 2014;123卷 ;10页 ;共19页

Abstract: Total gas storage capacity in many shale gas reservoirs arises from three sources: compressed gas in the micro- and nano-scale pores, adsorbed gas on the inner surfaces of pores in kerogen—the main constituent of organic materials in shale—and dissolved gas molecules in kerogen. The storage capacity of and transport processes for each of these three sources of gas are different, and accordingly, appropriate models and production strategies should be developed on the basis of actual physics. Of great relevance to field development and management is knowing the contribution of each source to daily production and ultimate gas recovery. A valuable body of literature has addressed the first two sources, but the last source has not been studied in detail. We developed a technique to measure the gas capacity from each of the above-mentioned three sources simultaneously, in a small piece of a shale sample, through batch pressure decay experiments. Temporal pressure decay is recorded using a quartz high-resolution pressure transducer for several days. The pressure-decline curve shows distinctive slope changes representing different storage processes. Pressure decline at the earliest time represents gas migration into the micro- and nano-pores. This is followed by a change in the slope of the pressure decline in an intermediate time, representing gas adsorption onto the inner surface of kerogen pores. At the later time, the slope of the pressure decline changes again, representing gas diffusion into kerogen. In the samples we tested, we found that dissolved gas in kerogen can contribute about 22% of the total gas-in-place. Assuming that gas molecules diffuse into the walls of the pores in kerogen, we used a Fickian diffusion model and a parameter-estimation technique to estimate the gas molecular diffusion coefficient in kerogen. We measured the diffusion coefficient of methane in amorphous kerogen as being on the order of 10− 20 m2/s.

题名：页岩储气过程与油岩分子扩散系数测量

摘要有点：提出测量页岩储气和油岩分子扩散系数新技术；油岩分子扩散系数低，但由于“大”表面面积，其质流高。