Download or read book Experimental Study on Foamy Oil Flow by Using Different Heavy Oil Solvent Systems written by Xiang Zhou and published by . This book was released on 2015 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: Foamy oil flow that occurs in heavy oil reservoirs under solution gas drive in the primary production process, shows an anomalous production performance compared with that in conventional solution gas drive reservoirs [Maini, 2001]. Although several laboratory experimental studies have been carried out to research the mechanisms of foamy oil flow in physical models, and the production performance effects of pressure depletion rates on foamy oil flow have been studied, it remains difficult to understand the process clearly. Meanwhile, many oil samples used in previous studies were on heavy oil-methane systems or heavy oil-CO2 systems, rarely on heavy oil-propane systems. Therefore, it is of crucial importance to understand the solution gas drive mechanisms in heavy oil reservoirs with different hydrocarbon solvent gases (methane, propane, and mixture) under different constant pressure depletion rates, so as to guide a better cold heavy oil production. In this study, pressure depletion tests on foamy oil flow were conducted in two kinds of apparatus, namely the Pressure-Volume-Temperature (PVT) system and the sandpack system, to investigate the effects of the pressure depletion rate on different heavy oil-solvent systems in bulk phase and porous media, respectively. Pure methane, pure propane, and a mixture of methane and propane were recombined into a Manatokan dead heavy oil sample to generate live oil samples, respectively. For the heavy oil-pure solvent system, both the PVT tests using the Constant Component Expansion (CCE) approach under constant volume depletion rates and the sandpack tests under constant pressure depletion rates were conducted to examine the effects of different pressure operation schemes on improving foamy oil recovery efficiency. For the heavy oil-mixture system, only sandpack tests were developed under constant pressure depletion rates to study the mixture effects on foamy oil flow. For each heavy oil-solvent system, four different volume or pressure depletion rates were undertaken; in total, eight PVT tests and twelve sandpack tests were carried out in this study. The experimental results showed that for the PVT tests, the plots of pressure versus time elapses and volume changes versus pressure declines of the heavy oil-methane system were much smooth than those of the heavy oil-propane system, which means the volume increase rates of the oil mixture and bulk phase are synchronous in the heavy oil-methane system. However, in the heavy oil-propane system, the volume increase rate of the oil mixture was lower than that of the volume increase rate in the bulk phase. Due to the high solubility of propane in heavy oil, the nucleated bubbles were trapped in the heavy oil and it was difficult for them to evolve out; the propane was recombined into the live oil simultaneously with undergoing the dynamic process undergoing, resulting in appearance of fluctuations in the plots. For the sandpack tests, the trend of oil production recovery factor is different from former researches which indicated that the oil recovery factor has a proportional relationship with pressure depletion rates. In this study, the oil recovery factor plot has a non-linear relation with pressure depletion rates, and there are summits in the recovery plots for the three heavy oil-solvent systems. Finally, for the three heavy oil-solvent systems a brief chart, from which pressure depletion rates can be optimized for the foamy oil flow and Cyclic Solvent Injection (CSI) processes, was developed.

Download or read book Experimental Study of Foamy Oil Characteristics and Post CHOPS CSI Processes Based on CO2 C3H8 Mixture Solvent written by Chen Shen and published by . This book was released on 2020 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: As the demand of crude oil increases sharply nowadays, heavy oil, an unconventional liquid hydrocarbon representing more than 70% of the world's total oil, needs to be further produced in the coming decades. Although some laboratory experiments have been conducted to find out the mechanism of foamy oil during pressure depletion processes. There are still some difficulties in understanding the characteristics of foamy oil flow in Cold Heavy Oil Production (CHOP). Large amounts of heavy oil samples used in previous studies were mixed with methane, carbon dioxide and butane. Only several studies were conducted under heavy oil-mixture solvent systems. Therefore, it is of great significance to carry out some experiments to perceive the foamy oil flow characteristics with its influencing factors in heavy oil-mixture solvent (CO2-C3H8) systems so as to get better recovery factors in primary production. In this study, four pressure depletion tests were conducted in 1D sand pack model to find out factors affecting the duration of foamy oil flow and recovery factors were obtained as the result. Firstly, all the conditions were the same except for the decline rate (-1, -2, -6, -12 kPa/min). Secondly, the optimized depletion rate was applied into the next stage experiments which was used to understand the length effect on foamy oil flow characteristics. Once all the depletion tests had been completed, another four post-CHOPS CSI tests were conducted to find out whether gravity can take effect on the oil recovery factors. Results show that in CO2-C3H8 mixture solvent-heavy oil system, oil recovery factor increases as the depletion rate becomes larger. Furthermore, compared with pure solvent heavy oil system, mixture solvent shows better during depletion tests. Besides, results show that there is a positive correlation between oil recovery factor and gravity. Last but not least, results from the pressure depletion tests indicate that pressure gradient will become smaller at the end as the model length increases. In the oil field, pressure gradient remains a low level when it is far away from the well bore and that is one reason for low cumulative oil production.

Download or read book Modeling of Enhanced Heavy Oil Recovery Processes written by Zinqian Lu and published by . This book was released on 2021 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: Many heavy oil reservoirs are now developed by enhanced heavy oil recovery methods, such as solvent-based recovery techniques. The solvent-based recovery techniques have advantages in energy effectiveness, cost efficiency, and environmental benefits compared with other methods. In the application of solvent-based recovery techniques, many types of solvent are available, including methane (C1), propane (C3), carbon dioxide (CO2), and solvent mixture. Foamy oil flow is considered an essential mechanism and has been extensively studied. For each heavy oil-solution gas system, the flow behavior is unique, and a systematic study is necessary to understand the foamy oil mechanism better. Previously proposed simulation models did not history match the production data and pressure distribution simultaneously. This deficiency would increase the uncertainty of the simulation result and influence the subsequent evaluation or prediction of the enhanced heavy oil recovery process since the pressure incremental is not captured. This work provides an innovative methodology to characterize foamy oil flow and gas-oil two-phase flow in heavy oil-different solvent systems. For each heavy oil-solvent system, a reliable non-equilibrium simulation model is developed and validated with sand-pack model pressure depletion tests by capture the production data and pressure distribution. This work consists of a systematic simulation study using the same heavy oil sample with different types of solvent. Since the mobility ratio between the solvent and heavy oil in applying solvent-based recovery techniques is very high, the frontal instabilities are also widely observed at the two-phase interface. The instabilities grow and form the viscous fingering phenomenon. Due to the existence of viscous fingering, the breakthrough time is shortened significantly, which will impact the oil recovery and swept efficiency. Since the description and prediction of the two-phase frontal instabilities in the porous media is always a challenge, most current work is based on theoretical models and rarely validated with lab tests. In addition, previous modeling works of frontal instabilities were mainly conducted in the Hele-Shaw model or micromodel, not in the sand-pack model. Hence, previous conducted experimental works were not analyzed with the simulation study in the porous media. In this work, a simulation model is developed by adopting the Volume of Fluid (VOF) method coupled with the Level-Set (LS) method to capture and track the immiscible two-phase interface between oil and water. Then the simulation results of viscosity fingering are validated with lab tests in the porous media in terms of qualitative (frontal instability morphological characteristics) and quantitative (breakthrough time) aspects. The characterization of the frontal instabilities (viscosity fingering) is investigated under different displacing rates and viscosities. It is very challenging to describe and predict both the foamy oil flow and frontal instabilities at the same time during the enhanced heavy oil recovery process. Therefore, this research conducted simulation works and validated with lab tests for each process (foamy oil flow and viscosity fingering) separately. The conducted researches provide numerical simulation methods and reliable simulation models that could be applied to further studies on the history match and prediction of field application. Moreover, the conducted researches allow future research to consider both phenomena (foamy oil flow and viscosity fingering) that happened in the enhanced heavy oil processes by integrating the proposed simulation models in this work.

Download or read book Effects of Temperature and Heavy Oil Viscosity on Foamy Oil Flow in Porous Media written by Mingyi Wu and published by . This book was released on 2018 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: With vast potential reserves of heavy oil, the research on heavy oil has been the hottest topic over the decades. Foamy oil flow occurs in primary production of heavy oil reservoirs with unexpected high oil recovery factor. Studying on foamy oil mechanisms and flow behaviors helps enhancing oil recovery. Lots of experimental researches have been conducted to investigate on improving foamy oil flow efficiency. Pressure depletion rate has been proven to be one of the most significant parameters that affects foamy oil flow. However, the other factors that influence foamy oil such as reservoir temperature, oil viscosity, oil composition, etc. are not fully understood. Therefore, it is of great importance to study the influence of temperatures and oil viscosity on foamy oil flow. In this study, two types of experiment are carried out: (1) the sand-pack pressure depletion test under different temperatures; (2) sand-pack pressure depletion test with different viscous oils. In the first series of experiment, four different temperatures (20°C, 30°C, 40°C, 50°C) are selected to exam the production performance. In the second set of experiment, three heavy oil specimens with different oil viscosities are utilized under the same temperature condition (40°C). Initial gas oil ratio (GOR) is settled the same in all experiments. The experimental results of different temperatures indicate that foamy oil flow is weakened, and oil recovery factor declines with elevating temperatures. However, gas recovery factor increases when temperature rises. It is observed that the higher initial reservoir pressure does not certainly increase oil recovery factor during foamy oil flow. Given a favorable live oil viscosity, oil recovery can reach the optimized value. A new foamy oil behavior is discovered during the study, in which a second foamy oil flow appears during the late-time production. The experimental results of different viscosities showed that, there is an optimal live oil viscosity for foamy oil production because the results give a non-linear relationship between oil recovery factor and oil viscosity. The dead oil viscosity should also be considered when estimating oil recovery performance since oil viscosity is approaching to dead oil viscosity due to the relatively low reservoir GOR after gas is produced.

Download or read book Experimental and Mathematical Studies of Cyclic Solvent Injection To Enhance Heavy Oil Recovery written by Zhongwei Du and published by . This book was released on 2017 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: It has been suggested that Cyclic Solvent Injection (CSI) is a highly promising technique to recover heavy oil resources at which other recovery techniques are not economically or efficiently available. Therefore, it is necessary to conduct experimental and mathematical studies on the CSI for effective heavy oil recovery purposes. Experimental and data regression studies have been conducted to investigate the effects of the wormhole on the CSI. Nine tests were completed using three sand-pack physical models with different dimensions. Experimental results suggest that the oil production can be divided into two phases: solvent chamber rising phase and solvent chamber spreading phase. The average production rate in the solvent chamber rising phase is proportional to the wormhole length, while the average production rate in the solvent chamber spreading phase does not change much with the wormhole length. In addition, a relation of the oil production rate to the drainage height is obtained by regression analysis and verified with a different experiment. It is suggested that for a rectangular model, the oil production rate in the chamber rising phase is proportional to h1.1667. Experimental study of effects of pressure decline rate on the CSI has been performed. Twelve tests with ten decline rates through linear and non-linear pressure-drawdown methods were conducted. Results of optimizing the pressure decline rate indicated that the pressure decline rate plays a primary role in the CSI by affecting solvent chamber growth, foamy oil flow performance in Phase 1, and pressure drop force in Phase 2. Different driving mechanisms in different phases lead to different optimum pressure decline rates. Comparison of two pressure-drawdown methods suggests that the main difference between the non-linear pressure-drawdown method and linear pressuredrawdown method is that the former cannot provide a continuous driving force for diluted oil as well as the latter. The effect of the intermittent driving force is much more significant in Phase 2. Therefore, production performance of tests of pressure-drawdown linearly was generally better than that of tests of pressure-drawdown non-linearly. A linear material balance equation of CSI has been proposed to obtain the recovery factor of diluted oil. It is successfully used to obtain the recovery factor of diluted oil of each cycle for a well-designed CSI test in a rectangular physical model (80×40×20 cm3). The relation of the solution-gas oil ratio and the diluted oil formation volume factor with pressure under non-equilibrium state are obtained through linear regression based the material balance equation. They are successfully verified through experimental data of a CSI test in a cylindrical model. Results indicate that the efficiency of oil dilution increases from 4.75% to 10.70% before the Cycle 10. Then it slightly varies from 10% to 16.25% till the Cycle 25. It is dramatically decreased 10.11% in the last five cycles. For first three cycles, the diluted oil recovery factor is up to 40% due to extended production time. Then it almost keeps around 32% till the Cycle 25. Three mixture solvent with the decline rate of 12.5 kPa/min ,5 kPa/min and 1 kPa/min have been conducted. Knowledge of production performance of mixture solvent CSI tests is obtained through the comparison of mixture solvent tests with different decline rate and the comparison between mixture and pure solvent tests. Pure solvent tests had larger recovery factor and average oil production per cycle than mixture solvent tests. The asphaltene precipitation and production time significantly impacted the recovery factor of diluted oil in mixture solvent tests.

Download or read book Comprehensive Experimental Study on Foam Flooding for Enhancing Heavy Oil Recovery written by Jing Zhao and published by . This book was released on 2017 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: At present, thermal method, such as steam injection and in-situ combustion are the best for recovering heavy oil. However, some reservoirs in Canada and the United States with ultra thin oil formations saturated with lower viscous heavy oil (50~200 cp), chemical flooding is more attractive compared with conventional thermal methods. This study is aimed to explore the effectiveness and potential application of foam flooding for enhancing moderately viscous oil recovery. The effects of surfactant type and concentration on surfactant properties were examined in terms of bulk foam ability and foam stability by the Ross-miles method and Warning blender method. Foam stability in the presence of experiment heavy oil was determined on the basis of a mechanistic understanding of foam propagation in porous media, combined with "Pseudoemulsion-film model" theory. The effects of foam quality and flow rate on foam mobility were determined by performing a series of steady-state foam flow experiments in oil-free sandstone porous media. Oil displacement experiments were conducted to determine the effectiveness of immiscible foam as a tertiary recovery method in recovering heavy oil and to make a comprehensive evaluation of oil displacement efficiency of foam generated by different surfactants. Mobility Reduction Factor (MRF) in the presence or absence of oil were determined to reveal the destabilize effect of oil on foam stability in porous media and investigate the sensitive degree of different types of foam to oil. Results show anionic surfactants had the best comprehensive foaming ability, followed by nonionic, cationic surfactants. The optimum foaming concentration was found to be 1.0 wt%. To generate stabilized foam, BIO-TERGE AS-40, STEPANTEX VT-90, Triton X-100 were selected as representatives of anionic, nonionic, and cationic surfactants, respectively. Co-injection of CO2/foaming agent was manifested as a reasonable injection strategy, and the highest recovery factor (RF) was obtained at 80% foam quality with the flowrate of 2.5 cm3/min (at ambient condition). VT-90 foam, as a cationic surfactant, surprisingly presented the highest resistance to flow compared with foam generated by other two surfactants at the same foam quality and gas/liquid flow velocities. Results of this study showed that foam flooding can be used as an effective tertiary method for enhancing heavy oil recovery. One order decrease in MRFs of the three tested surfactants after interacting with water-flood residual oil proved that experiment heavy oil undoubtedly destabilizes foam texture. VT-90 foam, again exhibited extraordinary foam strength with oil despite its poor bulk foam ability. The ultimate oil recovery of as high as 73% of residual oil in place (ROIP) by VT-90 foam coincides with its lowest sensitive degree to heavy oil. It is speculated that, commercial microemulsions, such as STEPANTEX VT-90 solution, have the potential to recover more oil by emulsifying oil droplets in the Plateau borders and transporting them with bubbles.

Download or read book Cold Production of Heavy Oil an Experimental Investigation of Foamy Oil Flow in Porous Media written by and published by . This book was released on 1998 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Foamy Oil Viscosity Measurement written by Di Pu and published by . This book was released on 2019 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: The rheological studies of gas-oil dispersion are essential for understanding the foamy oil flow behaviours related to high production rates in many heavy oil reservoirs. The viscosity of gas-oil dispersion is one of the critical parameters that influence the recovery in solution gas drive process. Only a few laboratory experimental studies have been carried out to investigate the effects of live oil viscosity and foam quality on the apparent viscosity of the foamy oil during the depressurization process. As for gas-in-oil dispersion, the continuous phase is the supersaturated live oil during the depressurization process. It is essential to quantify the in-situ foam quality to verify the viscosity models for the foamy oil viscosity calculation under pressure conditions. However, none of those previous experimental studies has directly measured the in-situ foam quality, to the best of our knowledge. Hopefully, this study developed a novel visualization-based experimental method to measure the in-situ foam quality under reservoir conditions in both CO2-heavy oil system and methane-heavy oil system. The foam quality under non-equilibrium conditions was first measured and analyzed by a real-time visualization chamber system. Besides, the viscosity models for the foamy oil viscosity calculation have been generated in both CO2-heavy oil system and methane-heavy oil system. The viscosity correlations developed in this study are capable of predicting the in-situ viscosity of gas-oil dispersion in the solution gas drive process on both laboratory and field scales.

Download or read book Processing of Heavy Crude Oils written by Ramasamy Marappa Gounder and published by . This book was released on 2019-12-18 with total page 274 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Cyclic Hot Solvent Injection Method to Enhance Heavy Oil Recovery Based on Experimental Study written by Kewei Zhang and published by . This book was released on 2018 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: In the solvent-based heavy oil recovery methods, the cyclic solvent injection (CSI) method has been acknowledged as an effective method with high oil production rate. Oil recovery in pure solvent CSI study is as high as over 70%. However, injection pressure in the pure solvent CSI is limited by the low dew point pressure of hydrocarbon at laboratory ambient temperature condition. In the mixture gas CSI method, although the solvent dew point pressure can be raised at the ambient temperature condition, recovery factor of this method is much lower than that of pure solvent CSI method. Therefore, it is necessary to explore an alternative CSI method which takes advantage of both pure gas-based and mixture gas-based CSI methods. As raising the pure solvent injection temperature can increase the solvent dew point pressure, the idea of hot solvent CSI is experimentally tested in this study. This new type of CSI method is named the cyclic hot solvent injection method (CHSI). In the CHSI laboratory study, hot solvent can reach high initial reservoir pressure. The experimental system consists of a sand-pack model unit, injection unit, production unit and data acquisition unit. Three major topics have been studied concerning CHSI: the comparison between CHSI and the replaceable method of CHSI (the mixture gas CSI method), the comparison between CHSI and the "N-Solv" (hot vapor solvent extraction) method, and temperature sensitivity analysis in CHSI. Experimental results show that, for the first topic, oil recovery of CHSI method is much higher than it is in mixture gas CSI method; for the second topic, oil production performance of CHSI is compared with that II in N-Solv; for the third topic, three solvent injection temperature levels are compared with each other in order to study solvent temperature effect on the oil production performance. Experimental results show that the CHSI method is an effective heavy oil extraction method, because this method is superior to mixture gas CSI method and N-Solv method regarding oil recovery. Oil recovery of CHSI is hardly influenced by solvent injection temperature. However, solvent injection temperature positively affects oil production rate during early CSI production period.

Download or read book Proceedings of the International Field Exploration and Development Conference 2020 written by Jia'en Lin and published by Springer Nature. This book was released on 2021-06-17 with total page 3487 pages. Available in PDF, EPUB and Kindle. Book excerpt: This book is a compilation of selected papers from the 10th International Field Exploration and Development Conference (IFEDC 2020). The proceedings focuses on Reservoir Surveillance and Management, Reservoir Evaluation and Dynamic Description, Reservoir Production Stimulation and EOR, Ultra-Tight Reservoir, Unconventional Oil and Gas Resources Technology, Oil and Gas Well Production Testing, Geomechanics. The conference not only provides a platform to exchanges experience, but also promotes the development of scientific research in oil & gas exploration and production. The main audience for the work includes reservoir engineer, geological engineer, enterprise managers senior engineers as well as professional students.

Download or read book Sustainable In Situ Heavy Oil and Bitumen Recovery written by Mohammadali Ahmadi and published by Elsevier. This book was released on 2023-03-24 with total page 512 pages. Available in PDF, EPUB and Kindle. Book excerpt: Sustainable In-Situ Heavy Oil and Bitumen Recovery: Techniques, Case Studies, and Environmental Considerations delivers a critical reference for today’s energy engineers who want to gain an accurate understanding of anticipated GHG emissions in heavy oil recovery. Structured to break down every method with introductions, case studies, technical limitations and summaries, this reference gives engineers a look at the latest hybrid approaches needed to tackle heavy oil recoveries while calculating carbon footprints. Starting from basic definitions and rounding out with future challenges, this book will help energy engineers collectively evolve heavy oil recovery with sustainability applications in mind. Explains environmental footprint considerations within each recovery method Includes the latest hybrid methods such as Hybrid of Air-CO2N2 and Cyclic Steam Stimulation (CSS) Bridges practical knowledge through case studies, summaries and remaining technical challenges

Download or read book Exploitation of Unconventional Oil and Gas Resources written by Kenneth Imo-Imo Israel Eshiet and published by . This book was released on 2019-07-10 with total page 152 pages. Available in PDF, EPUB and Kindle. Book excerpt: The stimulation of unconventional hydrocarbon reservoirs is proven to improve their productivity to an extent that has rendered them economically viable. Generally, the stimulation design is a complex process dependent on intertwining factors such as the history of the formation, rock and reservoir fluid type, lithology and structural layout of the formation, cost, time, etc. A holistic grasp of these can be daunting, especially for people without sufficient experience and/or expertise in the exploitation of unconventional hydrocarbon reserves. This book presents the key facets integral to producing unconventional resources, and how the different components, if pieced together, can be used to create an integrated stimulation design. Areas covered are as follows: • stimulation methods, • fracturing fluids, • mixing and behavior of reservoir fluids, • assessment of reservoir performance, • integration of surface drilling data, • estimation of geomechanical properties and hydrocarbon saturation, and • health and safety. Exploitation of Unconventional Oil and Gas Resources: Hydraulic Fracturing and Other Recovery and Assessment Techniques is an excellent introduction to the subject area of unconventional oil and gas reservoirs, but it also complements existing information in the same discipline. It is an essential text for higher education students and professionals in academia, research, and the industry.

Download or read book The Journal of Canadian Petroleum Technology written by and published by . This book was released on 2008 with total page 462 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Chemical Enhanced Oil Recovery written by Patrizio Raffa and published by Walter de Gruyter GmbH & Co KG. This book was released on 2019-07-22 with total page 277 pages. Available in PDF, EPUB and Kindle. Book excerpt: This book aims at presenting, describing, and summarizing the latest advances in polymer flooding regarding the chemical synthesis of the EOR agents and the numerical simulation of compositional models in porous media, including a description of the possible applications of nanotechnology acting as a booster of traditional chemical EOR processes. A large part of the world economy depends nowadays on non-renewable energy sources, most of them of fossil origin. Though the search for and the development of newer, greener, and more sustainable sources have been going on for the last decades, humanity is still fossil-fuel dependent. Primary and secondary oil recovery techniques merely produce up to a half of the Original Oil In Place. Enhanced Oil Recovery (EOR) processes are aimed at further increasing this value. Among these, chemical EOR techniques (including polymer flooding) present a great potential in low- and medium-viscosity oilfields. • Describes recent advances in chemical enhanced oil recovery. • Contains detailed description of polymer flooding and nanotechnology as promising boosting tools for EOR. • Includes both experimental and theoretical studies. About the Authors Patrizio Raffa is Assistant Professor at the University of Groningen. He focuses on design and synthesis of new polymeric materials optimized for industrial applications such as EOR, coatings and smart materials. He (co)authored about 40 articles in peer reviewed journals. Pablo Druetta works as lecturer at the University of Groningen (RUG) and as engineering consultant. He received his Ph.D. from RUG in 2018 and has been teaching at a graduate level for 15 years. His research focus lies on computational fluid dynamics (CFD).

Download or read book Experimental Study of Flow and Rheology of Water in crude Oil Emulsions written by Gnaly Marie Helene Kobea and published by . This book was released on 2019 with total page 92 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Theoretical and Experimental Study of Foam for Enhanced Oil Recovery and Acid Diversion written by Qiang Xu and published by . This book was released on 2003 with total page 208 pages. Available in PDF, EPUB and Kindle. Book excerpt: