3^rd International Conference and Expo on Oil and Gas July 13-14, 2017 Berlin, Germany

Biography:

Tatiana Morosuk is professor of the Technische Universität Berlin, Germany (since 2013). She studied refrigeration engineering in the Odessa State Academy of Refrigeration, Ukraine, and received her Diploma in 1990, Ph.D. in 1994 and Professorship in 2001. Her field of scientific activities is the application of exergy-based methods to the analysis and improvement the thermodynamic, economic, environmental performance of different power generation systems, refrigeration/cryogenic systems and chemical plants. Particular attention is given to systems associated with the liquefaction of natural gas and the regasification of LNG, smart energy supply and use in industrial parks, including innovative concepts of liquid air energy storage. She is the author or co-author of 7 books and more than 250 publications, and has 10 patents. She has over twenty years of experience and related teaching experience in the fields of refrigeration and over ten years in the field of applied thermodynamics, energy engineering, exergy-based methods.

Abstract:

Statement of the Problem: The overall chain “natural gas − LNG – natural gas” can be divided into four blocks: (a) Export terminal with associated technology for natural gas liquefaction (LNG production),
(b) LNG transport, (c) import terminal using a regasification process, and (d) distribution of the natural gas. Each of those four blocks is associated with energy-intensive processes. During the last two decades the total cost of LNG technology has decreased significantly due to improvements of the liquefaction process. However, the regasification system has not been considerably improved. It is known, that for the conventional regasification process (indirect heat transfer process, for example open rack vaporizers, submerged combustion vaporizers) about 1.5 % of the LNG energy is used. Findings: The integration of LNG regasification into heat utilization systems of an industrial process, LNG-based cogeneration for electricity generation, and LNG-based cogeneration for chemical products will bring benefits for the entire co-generation system (or industrial park) from thermodynamic, econonmic and environmental poits if view. Methodology: Exergy-based methods are applied for analysis, evaluation and improvement the thermodynamic, economic, environmental performance of actual and innovative systems for regasification of LNG. Conclusion & Significance: LNG will have in future a significantly larger contribution to the energy supply in the world than it had in the past. Thus, applying thermodynamically efficient, cost effective, and environmentally benign plants for the regasification of LNG is of particular importance for the use of LNG.

            Figure 1: Options for the regasification of LNG

Recent Publications

1. Morosuk T, Tsatsaronis G (2012) LNG – Based Cogeneration Systems: Evaluation Using Exergy-Based Analyses. Chapter 11 “Natural Gas - Extraction to End Use” (Ed. SB Gupta), InTech: 235-266.
2. Tsatsaronis G, Morosuk T (2015) Understanding the Formation of Costs and Environmental Impacts Using Exergy-Based Methods. Chapter 18 “Energy Security and Development. The Global Context and Indian Perspectives” (Eds. BS Reddy, S Ulgiati), Springer, New Delhi, India: 271-292.
3. Tesch S, Morosuk T, Tsatsaronis G (2016) Advanced exergy analysis applied to the process of regasification of LNG (liquefied natural gas) integrated into an air separation process, Energy – The International Journal 117: 550-561.
4. Morosuk T, Tsatsaronis G (2016) Comparison of novel concepts of cogeneration systems used to regasify Liquefied Natural Gas (LNG), Journal of Natural Gas Science and Engineering 34: 1434-1445.
5. Morosuk T (2016) Guest editor “Practice and innovations in the regasification of LNG, Energy – The International Journal 105.

Biography:

Jinsheng Wang is a Research Scientist of CanmetENERGY, Natural Resources Canada. His research interest spans several areas, including unconventional oil and gas, greenhouse gas control, clean energy processes, oil processing, etc. He has obtained his BSc from Beijing Institute of Chemical Technology, China, MSc from Institute of Aeronautical Materials, China and PhD from Kyoto University, Japan. He has been working in Natural Resources Canada since 2000. 

Abstract:

For shale gas development, low recovery factor and greenhouse gas emissions are two important issues. The average recovery factor for shale gas is around 10%, resulting in a large footprint with only a small portion of the resource recovered. Meanwhile, emissions of methane, a potent greenhouse gas could undermine the global efforts of reducing greenhouse gas emissions into the atmosphere. Injection in shale gas fields of CO₂ captured from industrial emitters such as fossil-fuel power plants could increase the recovery of shale gas and achieve CO₂ storage in gas-depleted shale. This could obtain carbon credits and improve the economics for shale gas production. It may also turn gas-depleted shale into a sink of CO₂ and contribute to reduction of greenhouse gas emissions. In shale gas field, methane exists as free gas in void space and as adsorbed gas on organic matter. Injected CO₂ could push the free gas toward the production well and displace the adsorbed gas because CO₂ has a higher tendency to be adsorbed compared to methane. As a result CO₂ is trapped in gas-depleted shale to enable CO₂ storage. CO₂ could also drive out gas condensate that is trapped in the shale and impedes the gas flow. As part of our research on enhanced shale gas recovery with storage of CO₂, we have carried out sorption experiments for CO₂ and methane. The results with samples from a Canadian shale gas reservoir suggest that the shale could adsorb 10 times more CO₂ than methane. That is to say, with every cubic meter of methane produced, 10 cubic meters of CO₂ could be stored. We have also studied swelling of gas condensate by CO₂, which could mobilize the trapped condensate and facilitate the gas flow. Other interesting findings will also be presented.

Figure 2. Time dependence of the size of gas condensate drop.

Recent Publications 

1. Wang Z, Wang J, Lan C, He I, Ko V, Ryan, D., Wigston, A (2016) A study on the impact of SO2 on CO2 injectivity for CO2 storage in a Canadian saline aquifer. Applied Energy 184:329-336.
2. Wang J, Wang Z, Ryan D, Lan C (2015) A study of the effect of impurities on CO2 storage capacity in geological formations. International Journal of Greenhouse Gas Control 42: 132-137.
3. Ng S, Al-Sabawi M, Wang J, Ling H, Zheng Y. Wei Q, Ding F, Little E (2015) FCC coprocessing oil sands heavy gas oil and canola oil. 1. Yield structure. Fuel 156:163-176.
4. Wang J, Ryan D, Anthony EJ, Wigston A (2012) The effect of impurities in oxyfuel flue gas on CO2 storage capacity. International Journal of Greenhouse Gas Control 11: 158-162.
5. Wang J, Ryan D, Anthony EJ (2011) Reducing the greenhouse gas footprint of shale gas. Energy Policy 39: 8196-8199.

 

Biography:

Kashy Aminian, Professor of Petroleum & Natural Gas Engineering at West Virginia University, has 40 years of distinguished service in both industry and academia. He holds MS and PhD degrees both from University of Michigan. He has extensive research and teaching experience in the areas of unconventional natural gas resource development and reservoir engineering.

Abstract:

Unconventional shale reservoirs play an enormous role in hydrocarbon production in the United States. Among the shale gas producing plays, Marcellus shale has a growing contribution due to advances in horizontal drilling and hydraulic fracturing techniques. Even though the advances in these technologies have unlocked the gas contained in Marcellus shale, the quantification of the petrophysical properties remain challenging due to complex nature of the shale. Reliable values of the shale petrophysical properties including permeability and porosity are necessary for accurate estimation of the original gas-in-place, prediction of the production rates, and optimization of the hydraulic fracturing treatments. Unsteady state methods have been extensively used to estimate permeability of the shale samples because the shales typically have permeability values in Nano-Darcy range. However, the permeability values by determined by these techniques have been found often to have large margin of uncertainty which are attributed to the lack of consistent experimental protocols and the interpretations issues.

Figure 1. Schematic of PPAL

Recent Publications:

1. Elsaig, M., Aminian, K., Ameri, S. and M. Zamirian, 2016:  “Study Analyzes Marcellus Shale Petrophysics,” American Oil & Gas Reporter, November Issue, pp. 63-65.
2. Zamirian, M., Aminian, K. and S. Ameri, 2016: “Measuring Marcellus Shale Petrophysical Properties,” Paper SPE-180366, Proc. SPE Western Regional Conf., Alaska.
3. Zamirian, M., Aminian, K., Ameri, S., 2015. “Measurement of Key Shale Petrophysical Properties.” Paper SPE 174968 Proc. SPE ATCE, Houston, Texas.
4. Zamirian, M., Aminian, K., and Ameri, S., 2015. “Experimental Investigation of Geomechanical Impacts on Organic-Rich Shales Matrix-Fracture Characterization,” Paper SPE-1733028, Proc. SPE Eastern Regional Conference, Morgantown, WV.
5. Zamirian, M., Aminian, K., Ameri, S., 2014. “New Steady-State Technique for Measuring Shale Core Plug Permeability.” Paper SPE-171613, Proc. Unconventional Resources Conference, Calgary, Canada.