Boyun Guo is the director of the Center for Optimization of Petroleum Systems (COPS) of the Energy Institute of Louisiana (EIL) and professor in petroleum engineering at the University of Louisiana at Lafayette, USA. He received his PhD degree in petroleum engineering from the New Mexico Institute of Mining and Technology, U.S.A. in 1993. His research interest is diversified including development of unconventional energy resources. Dr. Guo has completed numerous research projects sponsored by the US federal and state governments, Nature Science Foundation of China, and the oil and gas industry worldwide. He has published over 130 technical papers in professional journals and conferences and 10 books by professional publishers. Dr. Guo is an editor for several professional journals. He has received a number of awards from the oil and gas industry for his outstanding research work and services.
Engineers have struggled to produce natural gas from marine hydrates through drilling wells in the past two decades. The producing process has not been successful due to technical complications associated with hydrate decomposition such as wellbore collapse and sand production. Industry consensus is that commercial-scale gas production remains years away due to unsolved technical and environmental issues. A new thermal method called Moving Riser Method (MRM) is proposed in this work for producing natural gas from subsea gas hydrates and its feasibility is investigated. An analytical feasibility study was conducted in this project focusing on 1) achievable temperature of injected water at the seabed hydrate reservoir, 2) achievable gas production rate under given hot water injection conditions, and 3) production system design for environmental safety. This study concludes that with today’s pipe insulation technology water temperature drops only a few degrees from sea surface level to the seafloor level in an insulated 800 m deep vertical pipe. The injected water at seafloor level will be hot enough to dissociate gas hydrate at a commercial rate with an affordable energy consumption rate. The energy production to consumption ratio (PCR) is greater than 4. It is possible to use a gas collector of reasonable size (e.g., 2m in diameter) to gather all dissociated gas from the hydrate reservoir. Result of this investigation shows that producing natural gas from gas hydrate reservoir at seabed with the MRM is technically viable, economically feasible, and environmentally safe.
Dandina N. Rao is the Emmett Wells Distinguished Professor in Petroleum Engineering Department at LSU; is a registered PE and has been involved in EOR research for over 3 decades. He has served as a member of the Editorial Review Board of the Journal of Canadian Petroleum Technology for more than 7 years and as technical editor of SPE journal for 5 years.
The petroleum reservoirs constitute one of the most complex systems in nature that involve multiple interfaces coexisting and interacting with one another at elevated pressures and temperatures. Each of the four phases in the reservoir (solid rock, crude oil, associated gas and the brine) comprise multiple components, adding to the complexity of interfacial interactions. Furthermore, in order to recover the hydrocarbon resource, we impose processes involving the injection of water, chemicals and gases on these reservoirs, wherein the role of the interfacial interactions on multiphase flow through porous reservoir rocks becomes important. The tension at the various interfaces separating these phases of matter is a unique property in that it can reveal to us a great deal of information about the phases in contact including the direction and extent of mass transfer of components, their proximity to equilibrium, the nature of fluids distribution relative to one another, the contact angle and the spreading and adhesion behavior of liquids on solid surfaces. In this presentation we will examine, with supporting experimental data and literature findings, the multitude of roles played by interfacial tension in establishing (1) the phase behavior characteristics of solubility, miscibility, and the associated mass transfer mechanisms in multicomponent fluid systems, (2) the nature of fluids distribution in gas-oil-water in porous reservoir rocks at elevated pressures and temperatures, and (3) the spreading and adhesion characteristics in rock-oil-water-gas systems through dynamic contact angle measurements.
Abdelaziz Khlaifat is the Head of Petroleum Engineering Department at Abu Dhabi Polytechnic and AD Poly SPE Students Chapter Advisor. Prior to joining AD Poly, Abdelaziz worked as a Research and Development Manager of Dhahran Research Center at Weatherford International (Geoscience Development). Erstwhile, he worked as a Senior Reservoir Engineer, specialized in an unconventional resources (tight and shale gas) at Weatherford Saudi Arabia. Before joining Saudi Arabia office, he worked as a senior reservoir engineer (modeling and simulation) in the reservoir engineering group of the Weatherford Well Engineering Center of Excellence in Dubai. He obtained his BSc degree in Petroleum Engineering (1990) from Moscow Institute of Oil and Gas, Moscow-Russia, Master of Chemical Engineering and PhD in Chemical/Reservoir Engineering from Illinois Institute of Technology, Chicago-USA in 1994 and 1998, respectively. Before joining Weatherford, he had held different positions in the academia. In 2009 he was promoted to a full professor of chemical engineering at Mutah University, Jordan.
Abdelaziz is actively involved in scientific research and development of novel methodologies and techniques in tight and shale gas reservoirs, shale gas resource development workflow and tight gas staged field experiments. He has authored/coauthored over 85 publications, including journal articles, book chapters and specialized conference proceedings in the areas of flow through porous media, hydrocarbon reservoir engineering, unconventional tight and shale gas, managed pressure drilling, non-aqueous phase Liquid transport, photocatalysis, two phase flow modeling and simulation, and Dead Sea related-research. He is an active member of the SPE, AIChE, JGA, JES, JEA, AHWA and SFERA.
With the increased global demands on oil and gas, operators strive to maximize production by conducting more advanced drilling operations, such as extended reach, horizontal and high-pressure/high-temperature (HP-HT) drilling and are expanding globally into drilling unconventional resources. Unconventional gas resources offer significant gas production growth potential in the coming years, currently accounting for more than 43% of the US gas production. Tight Gas Sands (TGS) represents approximately 70% of the unconventional production and significant reserves are yet to be developed.Hydraulic fracturing of the deviated wells was the method of choice, in the late 80’s, for developing tight gas reservoirs worldwide. In the 90’s horizontal drilling became common practice as new drilling technology developed and proved to be very successful in many tight gas fields. However, conventional drilling operations caused reservoir formation damage that prevented the identification the gas production potential and resulted in missing some of the gas reservoirs. Underbalanced drilling (UBD) technology was introduced in the 90’s to minimize and prevent drilling problems associated with total losses into tight reservoirs. As a result, significant productivity gains were observed and this became a key driver to apply UBD technology in tight gas reservoir drilling. This paper provides a technical overview of the state of the art UBD technology used to develop unconventional tight gas reservoirs.
Lorenzo Spadaro, received his education at the Universities of Messina, Reggio Calabria, Turin and Rome, obtaining Ph.D. and Sc.D. in Industrial Chemistry and Chemical Engineering. Since 2000 he’s been researcher of Italian National Research Council (CNR) and University Lecturer. His main research activities concern the “Design of Catalysts and Industrial Processes for Energetic and Environmental Applications”. He’s co -author of more than 200 technical-scientific documents, inventor of several international industrial patents and prototypes.
Concerns about the environment pollution and energy shortage have promoted academics to exploit fossil fuel alternatives, such as biomass . In particular, crude bio-oils derived from the pyrolysis of biomasses, can represent one of the most suitable and renewable energy sources for the bio-fuel production. However, crude bio-oil upgrading is required before utilization as transportation fuels. In fact, the high content of oxygenated molecules is responsible for several deleterious properties of these crudes as high viscosity, low volatility, corrosiveness, thermal instability and tendency to polymerize. Moreover, although ethers are one of the primary products of pyrolysis oil, the HDO of these molecules has not been fully investigated.On this address, this work is aimed at highlighting the feasibility of the bio-oil upgrading process under simulated industrial conditions. Namely, a systematic study in the HDO of MTBE as model compound has been carried out by using alumina supported NiMo based catalysts, timely activated with different procedures, shedding light on the correlations between structure and reactivity. Preliminary tests show an almost complete conversion of the MTBE, with the formation of methanol as main reaction product, while the presence of methane is due to the occurrence of cracking side reaction.
Essa Georges Lwisa has a Master’s degree in Petroleum Engineering, he works as a Core Analysis lab instructor at the Chemical & Petroleum Engineering dept. UAE University. He published 15 scientific papers in Enhanced Oil Recovery methods, and honored with IAAM Scientist Medal of year 2017 for notable research in the Advanced Material Science and Technology during award ceremony of International Association of Advanced Materials, Stockholm, Sweden.
The interfacial tension and contact angle are believed to have direct impact on wettability alteration of crude oil/water/rock systems. An important factor that controls the fluid distribution in a reservoir is formation wettability. Most carbonate reservoirs are preferentially oil wet and they do have a negative capillary pressure. These reservoirs exhibit reduced oil recovery compared to sandstones because of their fractured nature.This study has been conducted to find the optimum water salinity that may be used in water flooding in either the secondary or tertiary stages of a reservoir development depending upon interfacial tension between crude and brine, and contact angle measurements. Two crudes were taken from reservoirs in the UAE, Bu-Hassa (low acidity) and Thamama (high acidity), and five types of brine with different salt concentration were examined to find the relationship between the acidity numbers of the crude oil and the salinity of brine.