International Conference and Expo on Oil and Gas November 16-18, 2015 Dubai, UAE

A.M Hassan is a Graduated Assistant in the department of Petroleum Engineering at King Fahd University of Petroleum & Minerals (KFUPM), Dhahran, Saudi Arabia. He earned his B.Sc. in Petroleum Engineering from University of Khartoum, Sudan in August 2011. Mr. Hassan is working at University of Khartoum and PetroEDGE Company, Sudan. He has authored and co-authored several articles on various topics of petroleum engineering.

Objectives/Scope: The role of pressure on reservoir performance and management has been introduced by conventional diffusivity equation. However, only accurate measure of pressure response can lead to better reservoir management. Introducing the memory-based diffusivity equation enables to better understanding of pressure response based on rheological characteristics of the formation rock and fluid. This is because of the complexity of rock structures and fluid rheologies which depend on formation history and types. Ultimately, this history provides the quantitative and qualitative measures of fossil fluids in the reservoir.rnrnMethods: The memory-based diffusivity equation has been solved using numerical methods. To account the non-local aspects of the rock and fluid memories, the fractional derivative is used as memory formalism. A heterogeneous reservoir with synthetic porosity and permeability values is used to investigate the effect of reservoir heterogeneity on the pressure distribution using memory-based diffusivity equation.rnrnResults & Conclusions: A comprehensive study on different reservoir parameters such as formation porosity and permeability are thoroughly investigated to capture the influence of reservoir heterogeneity on the pressure distribution. Results show that, the memory-based diffusivity equation can be used to model the flowing of fluid through heterogeneous reservoir. In addition, the reservoir heterogeneity has a significant effect on the pressure distribution and therefore controls the reservoir performance. The effects of reservoir heterogeneity increases with time around the wellbore and decreases toward the outer boundary.rnrnNovel/Additive Information: The finding of this research will support the using of memory concept on heterogeneous reservoirs to predict the reservoir performance and to improve the reservoir management.rn

Luiz Eduardo Melo Lima is Chemical Engineering from the Federal University of Sergipe (2003). Master in Space Engineering and Technology (Combustion and Propulsion) by the National Institute for Space Research (2007). Doctor in Mechanical Engineering (Thermal and Fluids) by the State University of Campinas (2011). He worked as a Visiting Professor-Researcher of the PRH20-ANP at the State University of North Fluminense Darcy Ribeiro, developing research in the Laboratory of Petroleum Engineering and Exploration (2011-2012). He is currently Adjunct Professor of Mechanical Engineering Course of Federal Technological University of Paraná (Ponta Grossa Campus), developing research in the Mechanical Academic Department.

Gas-liquid flows are encountered in many industrial applications such as in the oil industry, where a gas-oil mixture is transported through pipes from the well to the separation and processing facilities. The dispersed bubbles flow is one of the several gas-liquid flow patterns frequently found in this industrial application. Depending on the dispersed bubbles flow regime (viscous, distorted and turbulent), the flow characteristics change significantly, influencing the gas velocity and, therefore, changing the gas fraction along the pipe cross section. The goal of this study is to propose a solution procedure for flow regime identification and consequently, obtaining the main characteristics of the dispersed flow. The solution procedure was implemented in a computer code written in Fortran 95 programming language. For the results analysis, it was developed a computer code using Gnuplot application commands with the goal to generate a flow patterns map which allows viewing and verifying the occurrence of dispersed bubbles regimes. This analysis considered different work fluids as well as different pipe diameters. The analysis results showed that the solution procedure captures the dispersed flow characteristics with a good precision, despite of the differences encountered due to the variation of the fluids physical properties and the pipe diameter in the analyzed cases.

Mohd Hafiz Fazalul Rahiman completed his Ph.D. degree in electrical engineering and post-doctoral studies from Universiti Teknologi. In 2006, he joined Universiti Malaysia Perlis, Malaysia as teaching staff member and at present he holds senior lecturer position. His research interests include process tomography, sensors and instrumentations and embedded system.

In this paper, we carried out a tomographic investigation on a column using ultrasonic sensor. The ultrasonic tomography sensing array was constructed and clamped onto the exterior circumference of the column. The time-of-flight and arrival-time analysis was studied to obtain the signal information in real-time. The cross-section images were then reconstructed using image reconstruction algorithm. Some experiments were carried out using known static profiles and were compared with the actual profiles. The findings showed promising results where the sensing array could detect the void fractions.

Arian Velayati is a young researcher and engineer born in July 03, 1990. Velayati is a researcher of drilling fluids at Research Institute of Petroleum Industry in Tehran. He earned a BS degree from science and research university of Tehran and MS degree from Shahrood university of tech, both in petroleum engineering and as the top student. He was acknowledged as “Scientific elite” by the national elites foundation of Iran in the year 2014 as a result of his publications, GPA and researches. Velayati is also a lecturer and developer of drilling engineering softwares.

Gas migration through cement slurry is a worldwide challenge. Gas invasion could lead to financial damages and fatal incidents. Major oil companies devised specially designed approaches to face the problem of gas migration, many additives have been introduced and several techniques have been utilized. We have reported on the effect of thixotropic agents on reducing transition time, critical hydration time, modification of the gel strength profile and generally prevention of gas migration through cement slurries. The research was conducted based on a detailed checklist for cement slurry design optimization. Resulted paper was published in journal of natural gas science and engineering (Elsevier). The results of the research indicate advantages of thixotropic agent utilization in cement slurry composition and facing the problem of gas migration. As the final stage of the slurry optimization plan the results were verified using fluid migration analysis (FMA) test. According to the results, total gas migration flow rate of cement slurry optimized using the presented checklist was recorded as 0.23 ml/min. It was also observed that thixotropic agents improved gel strength profile, filtration control, waiting on cement time (WOC), critical hydration time and cement transition time significantly.

Ivan A. Tiunov completed his bachelor’s degree program in Perm State University in 2013. In 2015 he was graduated as a Master of Chemistry Science at Gubkin Russian State University of Oil and Gas and then continued his education as a PhD student. He’s field of research is corrosion monitoring in oil and gas industry, nanotechnology, electrochemistry. Ivan Tiunov is an author of eight papers, two patents and eight conference’s abstracts

Control of pipeline corrosion is a significant problem for oil and gas industry in Russia, because equipment is operated under more and more harsh conditions, especially in regions such as Ural or Siberia. Disastrous destruction of pipelines can be prevented if the corrosion is detected early by non-destructive testing (NDT) methods. There are a lot of NDT methods available for corrosion monitoring, but all of them have some drawbacks. For example, they are not applicable for rough surfaces, their contrast ability is low and a size-selective contrasting of nano-sized corrosion defects is unavailable.rnDuring our work a modified penetrant method was developed. According to our method visual inspection is replaced by a mapping of nanocracks contrasted by the penetrant – photoluminescent metal nanoparticles. Nanoparticles fill cracks that are wider than the nanoparticles diameter. After that the nanoparticles can be detected by femtosecond laser-induced photoluminescence and second harmonic generation, thus enabling size-selective contrasting of surface defects.rnThis method allows selectively contrast nanocracks with a different width by using nanoparticles with different size. Furthermore, it is possible to distinguish deep cracks from shallow surface defects. Preliminary results suggest being applicable not only for pipelines, but other high-loaded materials such as outer skin of aircraft or spacecraft.

Dr. Anton P. Semenov is senior research fellow, Department of physical and colloid chemistry of Gubkin Russian State University of Oil and Gas. He holds a PhD (2009) from the Gubkin Russian State University of Oil and Gas in Chemical Engineering. His research interests are in the areas of clathrate hydrates, phase equilibria, kinetics and thermodynamics of hydrate formation.

The equilibrium conditions of methane hydrate in the presence of additive of ethylene carbonate (C3H4O3) in aqueous solutions were experimentally measured in this study. Three-phase equilibrium conditions Lw-V-H (liquid water solution-vapor-hydrate) were determined by the isochoric method. New experimental results are reported for pressures ranging from 4 to 22 MPa and for mass fraction of ethylene carbonate ranging from 0.05 to 0.24 (0.011 to 0.061 for mole fraction). The experimental results show that the addition of ethylene carbonate in the system shifts hydrate phase boundaries to higher pressure and lower temperature. With the concentration of 0.240 mass fraction of the ethylene carbonate additive in an aqueous system, the most significant decrease of the equilibrium temperature is about 3 K at a given pressure, in comparison to that of methane + water system without additive. The structure of hydrate with this additive was determined using the Clausius-Clapeyron equation. Obtained data suggest that at a pressure more than 8 MPa, apparently, there is a structure sII hydrate formation, while at lower pressures structure sI hydrate formation. The effect of ethylene carbonate on methane hydrate formation conditions was compared with that of cyclopentanone (C5H8O). Despite similarity of cycle dimensions and structure, these compounds behave in the opposite way. Cyclopentanone is a thermodynamic hydrate promoter [1] whereas ethylene carbonate acts as a thermodynamic inhibitor.

Saeed Abbasi obtained his B.S. degree in Chemical Engineering from Iranian University of Technology, Iran (IUT) in 2000 and his M.S. degree in Petroleum Engineering from Petroleum University of Technology (PUT) in 2003. Currently, he is project manager at EOR studies center of Research Institute of Petroleum Industry related to NIOC (National Iranian Oil Company) and his interested fields are formation damage especially by water injection process.

Mineral scale deposition in near wellbore regions of injection wells is one of the main challengeable issues during the water injection process which magnify the importance of robust model in predicting the amount of mineral scale deposition such as calcium sulfate. One of the main challenges of CaSO4 scale is in carbonated reservoirs in which sensitive behavior was observed in related to contribution of both calcium and sulfate ions in carbonated and sulfated scale reactions. This defect is mirror of wrong procedure and value in estimation of first kind/value of precipitant contributed in scale deposition reactions (ions competition) as well as inconsistent temperature/pressure dependent coefficients of prediction model.rnThe objective of this study is to develop a model that can accurately predict the formation and amount of CaSO4 scale as the dominant scale in multicomponent aqueous systems by three major tools; utilization the best temperature and pressure dependent thermodynamic interactive ion coefficients (MSE Model: Pitzer), developing our fine-tuned iterative mathematical solver and verification the results of model by accurate experimental data. rnThe results showed that at the optimum value of precipitant (10%) in scale deposition reactions and by defining the best temperature and pressure dependent coefficients, we can attain the best accuracy in prediction of CaSO4 scale deposited amount (less than 0.06 percentages as relative error compared to commercial software with 36 percentages overestimation and 22 percentages underestimation). rnThe output of this study is developed software leading to more accurate prediction the amount of promising scales in near wellbore regions or pipeline.