Day 1 :
Keynote Forum
Valery N. Khabashesku
Baker Hughes a GE Company, USA
Keynote: Petrochemicals-derived fluorescent nanoparticles for tracer applications
Time : 10:00-10:40
Biography:
Valery Khabashesku obtained his professorial Doctor of Science Degree and Doctoral CSc Degree from Zelinsky Institute of Organic Chemistry of the Russian Academy of Sciences in, and MSc Degree in Chemistry from Lomonosov Moscow State University, Moscow, Russia respectively. At present, he is a Senior Technical Advisor for Nanotechnology at Baker Hughes a GE Company, one of the world-leading oil field services companies He is also an Adjunct Professor in the Department of Materials Science and Nanoengineering at Rice University; has been a Faculty Member in the Chemistry Department at the same university; Faculty Member- Department of Chemical & Biomolecular Engineering at the University of Houston, USA respectively. He has authored more than 300 publications and has been serving as an editorial board member for the journals of nanotechnology and materials.
Abstract:
Statement of the Problem: Fluorescent nanoparticles are becoming high demand products in the oil industry for application as tracers for reservoir monitoring to understand the flow pattern between the wells during waterflood operations and optimize the oil production. The common tracers, based on organic dyes, are not stable in harsh downhole conditions and are difficult to incorporate. Fluorescent carbon-based nanoparticles ??? carbon quantum dots (CQD) have recently drawn much attention due to outstanding fluorescence properties and pending applications towards chemical sensing and bio imaging. In most cases, CQDs outperform the traditional semiconductor-based quantum dots. They are also inherently non-toxic and stable in high temperature and pH conditions and are resistant to photobleaching. Purpose: The purpose of this study is development of low cost and scalable methods for synthesis of fluorescent carbon-based nanoparticles from petrochemical precursors. Methodology & Theoretical Orientation: CQDs were synthesized using electrochemical redox reactions. Platinum mesh was used for anode and cathode electrodes, and 0.1M NaOH as an electrolyte in a two-compartment cell. For preparation of fluorescent coreshell nanoparticles colloidal synthesis was applied. Findings: Electrochemical carbonization of low molecular weight petrochemical precursors containing carbon, oxygen, and hydrogen resulted in both water-soluble and oil-soluble CQDs of 10-20 nm size. Addition of nitrogen, boron, silicon or sulfur sources to the reaction produced doped CQDs with the fluorescence bands either blue-(N, B or Si) or red-shifted (S) with respect to undoped particles. Synthesized particles were stable for 30 days in API brine at 80�C and have been recovered at 76% in a flow experiments run through Berea sandstone core. Conclusion & Significance: A facile method has been developed for synthesis of large quantities of fluorescent carbon nanoparticles which can be recovered even from low permeable cores. This can open new opportunities for in situ monitoring of reservoir communication and oil production. Recent Publications 1. Zuniga C et al. (2016) Long term high-temperature stability of functionalized graphene oxide nanoplatelets in Arab-D and API brine. ACS Appl. Mater. Interfaces. 8(3):1780-1785. 2. Li H et al. (2012) Carbon nanodots: synthesis, properties and applications. J. Mater. Chem. 22(46):24230-24253. 3. Deng J et al. (2015) Large scale preparation of graphene quantum dots from graphite oxide in pure water via one-step electrochemical tailoring. RSC Adv. 5(38):29704-29707.
Keynote Forum
Angel Gonzalez-Delgado
CEPSA, Spain
Keynote: Thermogarvimetric monitoring of visbreaking unit in oil refineries
Biography:
A. García Barneto and J. Ariza Carmona are experts on the field of thermal analysis applied to organic materials. They have developed their careers applying thermogravimetric analysis to optimize industrial processes. To this end, they have used autocatalytic models based on Prout-Tompkins equation to deconvolute thermogravimetric curves. In recent times they have applied this approach to the crude oil industry in CEPSA’s refineries. A. González Delgado is a plant manager in La- Rábida CEPSA refinery (Huelva-Spain), being responsible of fuel production.
Abstract:
Statement of the Problem: In order to improve the fuel oil production, engineers need new resources to control the cracking reaction in visbreaking plants. Given the crude oil variability and the chemical complexity of vacuum residue, the optimization of distillates production without compromising fueloil stability is a challenge. As an alternative (or complement) to current situation, thermogravimetric analysis (TGA) provides fast and valuable information about composition of streams entering and leaving visbreaker unit in oil refineries. Methodology & Theoretical Orientation: Over a period of 6 months, the visbreaking unit of La R�bida- CEPSA Refinery (Huelva, Spain) was monitored by analyzing samples of visbreaking feed (VF) and residue (VR) both chemically and thermally. Findings: Thermogravimetric curves can be deconvoluted, allowing thermal-based composition of visbreaking streams to be elucidated by using lumps: four for visbreaking feed and seven for visbreaking residue obtained after thermal cracking. In both cases, some lumps explains volatilization of light substances (viz. naphtha or gasoil) under 350 �C, and some lumps explains cracking of heavy molecules (viz. resins or asphaltenes) at higher temperatures. On this basis can be defined new indices, based on the thermal behavior of samples, that monitor the VF stability and facilitates adjustment of furnace temperature (cracking severity). Conclusion & Significance: Thermogravimetric analysis of visbreaking streams is an alternative to present chemical analysis in order to optimize thermal cracking. Reduces analysis time and provides valuable information to the process engineers in order to maximize middle distillates production and to produce stable fuel oil. Recent Publications 1. Barneto, A.G.; Ariza, J.; Barr�n, (2015) A. Thermogravimetric Monitoring of Crude Oil and its Cuts in an Oil Refinery, Energy and Fuels 29 (3): 2250???2260. 2. Barneto, A.G.; Ariza, J. (2016) Thermogravimetric description of visbreaker streams in an oil refinery. Thermochimica Acta 642:1???9. 3. Joshi, J.B, Pandit, A.B., Kataria, K.L., Kulkarni, R.P., Sawarkar, A.N., Tandon, D., Ram, Y., Kumar, M.M. (2008) Petroleum Residue Upgradation via Visbreaking: A Review, Ind. Eng. Chem. Res., 47: 8960???8988 4. J.G. Speight, Heavy and extra-heavy oil upgrading technologies. (2013) Elsevier. Waltham, MA, USA. 5. E. Alvarez, G. Marroqu�n, F. Trejo, G. Centeno, J. Ancheyta, J. D�az, Pyrolysis kinetics of atmospheric residue and its SARA fractions, (2011) Fuel 90: 3602???3607.
- Reservoir Engineering | Field Development & Production Operations | Advances in Petroleum Engineering | Petroleum Distillation and Refining | Sustainable & Renewable Energy | Downstream Operations & Developments | Enhanced Oil Recovery and Refining | Petroleum Science and Technology
Location: olimpica 3+4
Chair
Valery N. Khabashesku
Baker Hughes a GE Company, USA
Co-Chair
Angel Gonzalez-Delgado
CEPSA, Spain
Session Introduction
Zhao Xin
Research Institute of Petroleum Exploration and Development, China
Title: Reasonale allocation for water producing gas well in tight gas reservoir
Biography:
Engineer, born in January 1984. Master degree, Graduated from China university of petroleum (Beijing) in 2010. Mainly engaged in natural gas development. Research on numerical simulation, gas reservoir engineering, and gas development plan.
Abstract:
The Western zone of Sulige gas field is tight reservoir which has a large area of aquifer, it???s very common that well products water, the average water-gas ratio of the zone is about 1m3/104m3, some wells are more than 3m3/104m3 so that wells don???t work virtually. Due to low single well gas production in tight reservoir, the production is always measured by the gas gathering station as a basic unit so most of wells have no gas and water production data and bring the very big difficult, this paper presents the method of determining the reasonable production system of gas well in the western block. The Western zone of Sulige gas field is tight reservoir which has a large area of aquifer, it???s very common that well products water, the average water-gas ratio of the zone is about 1m3/104m3, some wells are more than 3m3/104m3 so that wells don???t work virtually. Due to low single well gas production in tight reservoir, the production is always measured by the gas gathering station as a basic unit so most of wells have no gas and water production data and bring the very big difficult, this paper presents the method of determining the reasonable production system of gas well in the western block. Recent Publications 1. Architecture and quantitative assessment of channeled clastic deposits,Shihezi sandstone (Lower Permian), Ordos Basin, China[J], 2017, Journal of Natural Gas Geoscience.
Fu Ninghai
Research Institute of Petroleum Exploration and Development, China
Title: Fracturing geological model and fracturing optimization in tight gas reservoir
Biography:
Engineer, born in 1981. Master degree, Graduated from China university of petroleum (Beijing) in 2008. Mainly engaged in natural gas development for nine years. Research on gas reservoir engineering, numerical simulation and low permeability tight gas reservoir development and evaluation.
Abstract:
Tight sandstone reservoirs have strong heterogeneity, different distribution characteristics of effective sand bodies have different technical requirements for staged fracturing of horizontal wells. How to make full use of geological conditions and optimize the technological parameters, while controlling the investment cost and improving the fracturing effect, has become the key to further improve the development benefit of horizontal wells. Based on the geological and development characteristics of the research area in Eastern Sulige gas field, the study on the influence factors of horizontal well development effect is carried out. The main controlling factors including the size of the effective sand body, the stacking pattern of the reservoir and the fracturing technology are analyzed. According to the geology and production characteristics, combined with the differences of fracturing technology, the geological factors affecting the fracturing effect in the study area are refined into four elements: effective sand body, blocking zone, sand body and mudstone. On this basis, four fracturing geological models affecting the horizontal well reconstruction effect are summarized: massive thick layer type, multiple stacking type, local concentrated type and scattered isolated type. For the four types of geological models, the corresponding numerical simulation models are established, and the relevant parameters are optimized. The developing strategies are presented corresponding to the models. The massive thick layer type can only fracture the gas layer evenly, the multiple stacking type can fracture the gas layers mainly and fracture the sand bodies individually, the local concentrated type can fracture both gas layers and sand bodies, and determine the number of fracturing segments according to reservoir conditions, the scattered isolated type can fracture gas layer and isolated sand body, and the non-reservoir section can be fractured when reached a certain length. The study enhanced the combination of fracturing geology and fracturing technology, improved the pertinence of fracturing design of horizontal wells, and improved the fracturing effect. Recent Publications 1. The evaluation and recoverability analysis of low-quality reserves in Jingbian gas field[J], 2012, Acta Petrolei Sinica, EI.
Mohsen Fakhari
University of Leoben, Austria
Title: Evaluation of scaling phenomena in glass bead sand control system
Biography:
I have finished my Master in the university of Leoben (Austria), in the branch of Petroleum Production engineering. My master thesis was about production reduction because of gravel pack blockage by scaling. I am already working in the University of Leoben in the following topics; evaluation of invasion in gravel packing system, phase separation by ultrasonic, well cleaning by ultrasonic and new techniques.
Abstract:
Adherence and grow of scale is a known problem in oil industry that may happen in different areas and tools of oil and gas production and transportation equipment. Especially it can cause severe production drop by plugging sand control system. There are several methods in industry to solve the problem like, acid washing or chemical inhibitors. This paper presents the results of a laboratory study that demonstrates and quantifies the effectiveness of hiring glass beads, as a sand control system, on scaling phenomena. The physical properties of glass beads consist of uniformity and roundness, improving the permeability in sand control system, it can also have positive effects on fine invasion problem because of the uniformity of grains. In the second part of this experiment the coated glass beads with hydrophobic layer was postponing the scaling phenomena. Although the glass surface itself because of high smoothness makes it difficult for scale adherence, coating material will boost this potential. Activated surfaces by hydrophobic coating layer will reduce the contact between the surface and water and makes it difficult for crystal seeds to attach on them and grow. In this study, the glass beads were tested in a tube to create the pressure drop and measure the permeability. The scaling potential has been tested under the worst condition by temperature and existence of high amount of scaling components. Conductivity test and microscopic photos approve the inhibitor nature of glass beads when the results are compared with normal proppants used in the industry as sand control system.
Nazanin Motevali
Concordia University, Canada
Title: Influence of centrifuging conditions for sustainable recovery of fuel from oily sludge
Biography:
Nazanin Motevali is a graduate student in the Department of Building, Civil and Environmental Engineering at Concordia University in Montreal, Canada. She did her bachelor’s in Chemical and Petrochemical Engineering. The focus of her graduate research is improvement of management of oily waste generated by petroleum industry. She has an experience working in chemical and environmental laboratories. An important number of tests and analysis were performed by authors in this project.
Abstract:
One of the most troubling wasted products in both upstream and downstream petroleum industry is oily sludge. Oil sludge is generated in huge amounts through refining, exploration, storage, pipeline and tanker transportation. Such sludge, containing considerable amounts of hydrocarbons, solids, heavy metals, water and some impurities, presents a stable emulsion, which is difficult to treat. An adequate treatment prevents environmental pollution, protect public health, installation, disrupt operation, and preserves an adequate tank capacity. On other hand, oil sludge still contains valuable fuel and water, hence in spite of difficulties, the recovery of resources from sludge is a sustainable generation of fuels and recycling water. Centrifuging is one of the available technologies which is able to break the sludge suspension into phases, while fuel can be recovered. Another separated fractions, such as water and solids, can be treated, reused or disposed in an efficient way. In order to optimize phase separation and help in fraction recovery, the centrifuging process should considered: reduction of viscosity, preserving an adequate rotation speed, in combination with additives (e.g. organic solvents, demulsifying agents, etc.) and direct heating. The objectives of this study is to improve the oil sludge phase separation and fuel recovery using centrifuging and various conditioning methods. The results showed that the centrifuging process was the most efficient when the pretreatment with such additives like ferric chloride, ferrous sulfate and surfactant Tween 80, were applied and supported by a high speed. Furthermore, the study also showed that centrifuging three-phases separation was more affective when combined with pre-heating, particularly at 55�C. Recent Publications 1. Hu G, Li J and Zeng G (2013) Recent development in the treatment of oily sludge from petroleum industry: a review. Journal of Hazardous Materials. 261C:470-490. 2. Islam B (2015) Petroleum sludge, its treatment and disposal: a review. Int. J. Chem. Sci. 13(4):1584-1602. 3. Wang Y et al. (2017) Analysis of oil content in drying petroleum sludge of tank bottom. International Journal of Hydrogen Energy. 42(29):18681-18684.
maurizio Granata
Business Development Executive EMIA at Hexagon PPM, Italy
Title: Digital project execution & management supporting E&P capital investments
Biography:
Highly motivated and results-oriented executive. Maurizio is a strong leader and trusted advisor; he brings to Customers an extensive background in both engineering and business. Maurizio’s knowledge has built through both a 30 years career in the plant design industry, his education (MSC) in chemical engineering, business management, and executive business administration (MBA), and his cooperation and experience with Information Sciences Dept. of Milan State University.
Abstract:
In the context of Digital Transformation, today???s technology is re-shaping the execution and management of capital projects, ensuring that even the most complex project will provide clients with expected financial returns. Being able to efficiently manage and execute a project requires an integrated approach towards project execution and management, benefiting the entire engineering, construction, and operations value chain of the organization. This can be achieved by improving productivity, traceability and profitability. During this session Attendees will see how Hexagon PPM???s Integrated suite of solutions help organisations to digitally transform the Project Execution and Management processes - from project portfolio management, project controls, contract management, materials supply chain, construction and completion. It looks like the future of technology, but it is available today.
Jingyu Jin
Xi’an Jiaotong University, China
Title: Insights into the complex interaction between hydrophilic nanoparticles and ionic surfactants at the liquid/air interface
Biography:
Jingyu Jin mainly focuses on the interfacial properties and response behaviors under radiation, thermal, or magnetic field of nanoparticle suspensions. He has clarified the effect of the interaction between hydrophilic nanoparticles and ionic surfactants on the surface tension of liquid/air interface. A novel liquid optical filter based on the magnetic nanofluids has been proposed by him and can be used in the hybrid solar photovoltaic/thermal (PV/T) system. He has also investigated the relaxation behaviors of ferrofluids under magnetic field. Moreover, a modified multi-sphere Brownian model has been developed by him for thermal conductivity prediction in low volume fraction nanofluids. His studies are expected to contribute to a better understanding of various physical properties of nanofluids and its application in the future.
Abstract:
Combinations of nanoparticle and surfactant have been widely employed in many industrial processes, i.e., boiling and condensation in heat transfer and hydraulic fracturing in shale oil and gas production, etc.. However, the underlying mechanism for various phenomena resulted from the addition of nanoparticles into the surfactant solutions is still unclear. For instance, there are contradictory conclusions from the literatures regarding the variations of surface tension upon the addition of nanoparticles into surfactant solutions. In this work, the dominating factors, determining if the surface activity of the surfactant solution will increase or conversely decrease when adding certain kinds of nanoparticle, have been investigated. Two typical hydrophilic nanoparticles, SiO2 and TiO2 with anionic or cationic surfactants, respectively, have been considered. It was found that the surface tension of ionic surfactant solution can be further reduced only if nanoparticles of same charge were added. For instance, a system containing 0.25 CMC SDS and 1 wt% SiO2 behaves similar to a 0.34 CMC SDS-only solution. Interestingly, the observed synergistic effect is found to be more significant if the surfactant concentration is much lower than its CMC for a given nanoparticle content. Moreover, the effect is perfectly reversible. If nanoparticles of opposite charge were added, however, the surface tension of surfactant solution will increase. Zeta potential measurement and centrifugal treatment have been employed to reveal the interplay between nanoparticle and surfactant and the adsorption behavior of their assemblies at the liquid/air interface. Based on the experimental outcomes, a possible physical mechanism was proposed. It was concluded that the electrostatic repulsion between surfactant molecules and nanoparticles should be of the dominant factor responsible for the observed reversible synergistic effect. Our study is expected to contribute to a better understanding of the interfacial phenomenon in nanoparticle-surfactant complex systems. Recent Publications 1. Jin J et al. (2018) Time-dependent scattering of incident light of various wavelengths in ferrofluids under external magnetic field. Journal of Magnetism & Magnetic Material. 447:124-133. Doi:10.1016/j.jmmm.2017.09.066. 2. Jin J, Hatami M and Jing D (2018) Experimental investigation and prediction of the thermal conductivity of water-based oxide nanofluids with low volume fractions. Journal of Thermal Analysis and Calorimetry. Doi:10.1007/s1097. 3. Hatami M et al. (2018) Uniform magnetic field (UMF) effect on the heat transfer of a porous half-annulus enclosure filled by Cu-water nanofluid considering heat generation. Current Nanoscience. 14(3):187-198. Doi:10.2174/157341371466617 1222112425. 4. Jin J and Jing D (2017) A novel liquid optical filter based on magnetic electrolyte nanofluids for hybrid photovoltaic/ thermal solar collector application. Solar Energy. 155:51-61. Doi:10.1016/j.solener.2017.06.030. 5. Song D et al. (2016) Sedimentation of particles and aggregates in colloids considering both streaming and seepage. Journal of Physics D Applied Physics. 49(42):2715-2719. Doi:10.1615/TFEC2017.mnt.018015.
Mohamed Omran
British University of Egypt, Egypt
Title: Enhancing unconventional gas reservoirs characterization
Biography:
Mohamed Omran pursued his Bachelor’s Degree in Petroleum Engineering and Gas Technology from the British University in Egypt (BUE), Egypt. He received a scholarship for his Master of Petroleum Engineering Degree program at Norwegian University of Science and Technology (NTNU) in August 2018. He has participated in SPE ADIPEC University Program in Abu Dhabi, UAE (November 8-11, 2016) as a Research Presenter, besides being a Poster Presenter at the 58th SPWLA Annual Symposium, Oklahoma City, USA (June 17- 21, 2017) and has been a Speaker at the 3rd World Congress on Petroleum Engineering and Natural Gas Recovery, Sydney, Australia. He has worked on two graduation projects: research project concerning establishing new empirical and developing existing correlations for enhancing more accurate unconventional gas reservoirs characterization and design project concerning development of a software for well test analysis of unconventional gas reservoirs
Abstract:
Unconventional reservoirs can add huge amounts of additional energy to our world resources bases like organic shale in terms of shale gas, shale oil, tight gas and coal-bed methane. These reservoirs can transform the world global energy market through advances in reservoir characterization, drilling, and completion technologies. Reservoir characterization and properties have great influences on the exploration and development processes, it is not through a single discipline that can provide a fulfill description of the reservoir characteristics especially for unconventional reservoirs. Moreover, unconventional sources can be defined by their difference of intrinsic of their geological sittings, origins, and tapping mechanisms, thus having different methodologies for exploration, production, and development methods. Therefore, it is very important to well express and identify the necessary parameters for unconventional characterization of these reservoirs for defining reservoir rock and fluid properties in terms of total organic carbon content, gas adsorption, level of maturity, original fluids in place, and etc. The results showed that Upper Safa formation can be considered as shale gas unconventional resource play that consists mainly of kaolinite clay and other mixed clay types. Geochemical pyrolysis analysis is used to confirm the presents of kerogen type III as a shale gas potential reservoir. Interpretation analysis has been used also to confirm the presence of hydrocarbon potential in shale reservoirs depend on the readings that indicating most of shale play. Moreover, brittleness ratio average value equals to 50% brittleness. Integration between results of TOC (Total Organic Carbon) from both of geochemical and petrophysical analysis methods within the same range. However, TOC results which are obtained within the ranges of very good petroleum potential according to Rock Eval pyrolysis from 2% to 4% TOC. Some petrophysical analysis methods for determination of TOC results are applicable to Upper Safa formation as Schmoker, Modified Schmoker, NMR, and Uranium TOC. Recent Publications 1. M A F Omran and Attia Attia (2018) New approach for unconventional reservoirs rock typing characterization: Egyptian unconventional gas reservoirs. Petro. Chem. Indus. Intern. 1(1):1-7.
Adedamola Alake
Lagos University, Nigeria
Title: Enhanced oil recovery in reservoir formation rocks using a locally sourced material alcohol (Palm Wine)
Biography:
Alake Adedamola has a Bsc in Petroleum Engineering from the University of Lagos, Lagos Nigeria. Currently working on an experimental research thesis in the production optimization in the enhanced oil recovery phase of the petroleum industry titled ‘’Enhanced oil recovery in reservoir formation rocks using a locally sourced material plamwine”. He has also co researched ‘’ Gas leak Detection Systems in Subsea pipelines [Oyedeji et al2016}. He is currently on his way to Conventry University in the Uk for a petroleum Engineering Masters Degree. He is a cofounder of INSTUCOM (Integrated student community) , a mobile and web application built for universities students, lecturers and respective industrial professionals. It’s a central hub for academic/professional networking systems to improve the crawling learning process and capability and expose the young undergraduates to their respective career fields through E mentoring in Nigeria and West Africa. He was the the secretary and Public relation officer of the society of Petroleum Engineers SPE (University chapter), currently an SPE member. Also an active member of shell idea 360 and cofounder of young innovative Engineers at his University. He has worked with Total Upstream Company in Nigeria at the Geosciences and Reservoir and Inspection Department.
Abstract:
The importance of the daily usage of hydrocarbons and ever-increasing demand of energy cannot be overemphasized within and outside the country at large, even at the world scale. Fossil fuel is invariably the major source of energy in the world, it accounts for the majority Worlds electricity and also used to power aircrafts, automobiles, gasoline diesel used in power Generation in gas turbines and so on. For all these excessive demands of power generation, it would require drastic increase in the amount of crude oil recovered from reservoirs in petroleum and Gas industry.These would invariably pose a problem to the engineers within, to exhaust all the means of hydrocarbon recovery to enhance the amount of hydrocarbons recovered from reservoirs. Upon these basis lies the need to seek other recovery mechanisms that would efficiently increase the recovery of hydrocarbons and would of course be economical and cost effective, which is the basis of every operations carried out in the Oil and Gas industry. Oil wells that primary and secondary recovery processes have failed to improve would definitely require enhanced oil recovery which leads to the topic at hand, recovery of hydrocarbons in reservoir formation rocks with the aid of a locally sourced material, palm wine. The aim of this study to distinctively analyze and inspect the effects of using a locally sourced material (palm wine) to enhance the recovery of hydrocarbons in completed wells . Experimental observations have shown that components of alcohol and water paired with variations in core Sample can increase recovery, for this mixture oil recovery increased with increase in the alcohol content of the mixtures. This could be explained by the reduction of interfacial tension between oil and water mixture. The positivity of the result could have been generated from the reduction of interfacial tension and partly as the increase in the viscosity of the displacing fluid. Little or less experimental works have been carried out on the usage of (palm wine) to enhance the recovery of hydrocarbons . Alcohol is known to reduce the interfacialtension between oil and water, this property can be relied upon to achieve the objective. Most reservoirs are known for their low efficiency natural recovery mechanism therefore retaining enormous amount of hydrocarbons after their natural energy has been depleted, such reservoirs are often the best candidates for the aid of additional recovery methods. The oil phase is connected throughout the entire porous media over some saturation interval. As trapping occurs ,part of the oil is no longer by hydraulically connected to the flooding phase. An experimental study by Moore and slobod (1956) reported the effect of changing viscous and capillary forces on the residual oil saturation water wet cores. Viscous forces were altered by adding tertiary butyl alcohol to fluids to reduce the interfacial tension, it was reported that alcohol decreases the interfacial forces that hold the residual oil in place, thereby mobilizing more of the residual oil. Due to Forces, the effectiveness of water flooding is limited. This emphasizes the need to consider other processes such as the use of alcohol (palm wine), water mixtures to resolve the limiting capillary effects lowering the interfacial tension ,thereby mobilizing the residual oil left after water flooding or what the case maybe. The mobility ratio is the ratio of the displacing fluid mobility to the displaced fluid mobility. Recent Publications 1. Alake A.S ,Kehinde A.J , Adeboye Y.O, Mapayieda.B.S (2016) �???? Experimental study ofenhanced oil recovery inreservoir formation rocks using a locally sourced material palmwine. 2. Oyedeji E.A ,Alake A.S ,Abuhulimen B.A(2016) �???? Gas leak Detection systems in pipelines.
Arije Al-Khafaji
University of Leeds, UK
Title: Estimation of crude oil/brine/carbonates interactions using macroscopic and microscopic apparatuses
Biography:
Arije Al Khafaji has a BSc and MSc in Petroleum Engineering from the University of Baghdad with more than nine years’ experience working in the Iraqi Ministry Of Oil, Directorate of Reservoirs and Oil Fields Development, mainly as a Reservoir Engineer. She has extensive knowledge in Reservoir Engineering and has performed a full reservoir study using reservoir simulation tools. Also, she is involved in projects of redevelopment studies of mature fields, field development planning and secondary recovery by water flooding. Currently, she is doing her PhD in Petroleum Engineering at the University of Leeds. She is specifically studying the effect of low salinity flooding of enhanced oil recovery.
Abstract:
Low salinity water flooding has received a strong interest and been an area of research lately. Previous laboratory core flooding tests have shown that injecting low salinity water can improve oil recovery in carbonate reservoirs through wettability alteration. However, consistent mechanistic clarification of the underlying mechanisms at the pore scale level has not emerged yet. The major focus of this work is to study the complex interactions of crude oil/brine/ carbonates system at a molecular scale and then to provide a fundamental understanding of the physiochemical mechanisms involved in practical wettability alteration due to salinity changes. Adhesion forces by means of the atomic force microscopy (AFM) apparatus, macroscopic contact angle and interfacial tension (IFT) were experimentally investigated. To reduce surface roughness, flat calcite crystal surfaces were used to mimic the carbonates, while ready chemically modified tips (ST-PNP-COOH) were utilized to model polar-oil droplets. Synthetic formation water, seawater and various proportions of diluted seawater were used as selected saline solutions. Adhesion force maps were acquired for the same scanned area upon exposure to different saline solutions, injected in a sequential manner, starting from super saline solution (200000 ppm) ending up with 50 diluted sea water (873 ppm). The results of microscopic measurements reveal that the overall average of adhesion forces between a polar-oil droplet and calcite surface is decreased by about 45%, as the salinity decreased upto two times dilution. A small change (3???5%) in the adhesion values has been observed with the further diluted versions of sweater. The microscopic AFM results are qualitatively consistent with the macroscopic contact angle measurements. Experiments with saline solutions containing different concentrations of SO42- and Mg2+ show that SO42- ion has more effect on the adhesion force values than Mg2+ ion and there is a critical concentration of sulphate, beyond which its effect will be revisable. Recent Publications 1. Pedersen N R, Hassenkam H, Ceccato M, Dalby K N, et al. (2016) Low salinity effect at pore scale: probing wettability changes in Middle East limestone. Energy & Fuels 30(5):3768???3775. 2. Nasralla R A, Bataweel M A and Nasr-El-Din H A (2013) Investigation of wettability alteration and oil-recovery improvement by low-salinity water in sandstone rock. Journal of Canadian Petroleum Technology 52(02):144-154. 3. Israelachvili J N (2011) Intermolecular and Surface Forces. Academic Press. 4. Fathi S J, Austad T and Strand S (2010) ''Smart water'' as a wettability modifier in chalk: the effect of salinity and ionic composition. Energy & Fuels 24(4):2514???2519. 5. Kumar K, Dao E K and Mohantly K K (2008) Atomic force microscopy study of wettability alteration by surfactants. Society of Petroleum Engineers 13(2):137???145.
Fanghzhou Nan
Institute of Geology and Geophysics, China
Title: 3D gravity anomaly separation method for the deep reservoir’s residual thickness: Application to the Sichuan basin
Biography:
Fangzhou Nan is a Research Assistant at the Institute of Geology and Geophysics, Chinese Academy of Sciences and he is mainly engaged in ocean bottom seismograph data processing and integrated geophysical research.
Abstract:
The Sichuan Basin has the largest number of proven gas reserves, gas fields found and the cumulative output in China. The oil and gas reservoirs are deeply buried and the stratum structure is complex, so the structures of the basement and deep reservoirs cannot be clearly described only by seismic method. Based on the super position effect of gravity potential field, the residual gravity anomaly of the target layer can be separated by forward method, thus the depth of the target interface can be calculated through Parker method and then the residual thickness of the target layer can be obtained. As the depth of Cambrian bottom interface has been controlled by the high resolution seismic reflection method, the key issue of the Cambrian reservoir???s residual thickness to get the depth of Cambrian top interface, which means the gravity effect of the Cambrian stratum should be obtained. As viewed from the stratigraphic density statistics of the Sichuan Basin and its adjacent area, it is observed that there are five main density interfaces in this region, i.e., Cretaceous???Jurassic (????=0.12 g/cm3), Mid-Late Triassic (????=0.15 g/cm3) and Cambrian???Sinian (????=0.14 g/cm3), high-velocity bodies in homogeneous mantle (????=0.1 g/cm3) and Moho (????=0.6 g/cm3) (*???? represents the density difference). Their gravity responses are deducted from the Bouguer gravity anomaly. Then the gravity effect of the stratum of Cambrian was separated and the residual gravity anomaly of Cambrian top interface was calculated through 3rd wavelet analysis and the depth of top interface by Parker inversion. At last, the Cambrian reservoir???s residual thickness equals to the depth difference between the bottom and the top interface. Considering the prior information of 6 2D-seismic sections, Cambrian bottom interface was stretched 1.25 times and downward continuation of 3 km. Late-Sinian bottom interface was obtained, which can match the 2D seismic sections well and then its thickness was calculated. Recent Publications 1. Xu C, Liu Z W, Luo Z C, Wu Y H and Wang H H (2017) Moho topography of the Tibetan Plateau using multi-scale gravity analysis and its tectonic implications. Journal of Asian Earth Sciences 138:378???386. 2. Xing J, Hao T Y, Hu L T, et al., (2016) Characteristics of the Japan and IBM subduction zone: evidence from gravity and distribution of earthquake source. Chinese Journal Geophysics 59(1):116???140. 3. Guo L H, Meng X H, Chen Z X and Zheng Y M (2013) Preferential filtering for gravity anomaly separation. Computers and geosciences 51:247???254. 4. Hao T Y, Xu Y, Zhao B M, Zhang Y J and Peng L L (2009) Geophysical research on distribution features of magnetic basements in the South China Sea. Chinese Journal Geophysics 52(11):2763???2774.
- Advances in Petroleum Engineering |Unconventional Gas and Oil Resources |Health, Safety & Risk in an Organizational Context | Petroleum Science And Technology |Enhanced Oil Recovery And Refining
Location: olimpica 3+4
Chair
Xiaohui Wang
China University of Petroleum, China
Co-Chair
Ricardo Medronho
Federal University of Rio de Janeiro, Brazil
Session Introduction
Ashraf A. Alaqeeli
Sirte Oil Company, Libya
Title: Characterization and distribution of the Sarir Sandstone Reservoir in the Chadar Field, Concession 126, Sirte Basin, North Libya
Biography:
He is from Exploration Department, Sirte Oil Company for Production Manufacturing Oil & Gas, Libya.
Abstract:
The study concentrates on characterization and distribution of the Sarir Sandstone reservoir in the Chadar Field. It includes wireline logs analysis integrated with core analysis and analyzed well test data from four wells drilled in the Chadar Field; three wells explored by Mobil Oil Libya in May 1966 and one well by Sirte Oil Company for production, manufacturing of oil & gas in November 2014.The Chadar Field is part of Concession 126; it is located in eastern part of the Sirte Basin in the north central of Libya. The area of study is located in the westward of Messlah High between the south of Ajdabiya Trough and north of Sarir Trough (figure 1). The Chadar Field was first discovered in 1968 and A1-126 well was tested gas condensate flowed to surface from the Sarir Sandstone. The Sarir Sandstone Formation of Upper Jurassic to Lower Cretaceous represents the main hydrocarbon potential reservoir in the Chadar Field. The Sarir Sandstone is distributed widely in the subsurface of the study area and it is composed of a thick sandstone unit interbedded with shale.
Biography:
Behzad Rostami is an Associate Professor of Petroleum Engineering at the Institute of Petroleum Engineering (IPE) at University of Tehran. His research interests include gas injection-based methods for enhanced oil recovery, foam injection and carbonated water injection, CO2 sequestration in saline aquifers and depleted hydrocarbon reservoirs, gravity drainage and multi block interaction in fractured media. He authored more than 40 technical papers in international journals and also supervised more than 30 graduate students.
Abstract:
In wet water media, a continuous thin water film exists on the surface of pores and pore throats in the reservoir rock. As water saturation increases during water flooding, this film coalesces into a water layer, which isolates the residual oil behind the oil bank in the form of more massive ganglia. When the tertiary gas injection process is applied to such a system, direct contact between the oil and gas phases will be impossible due to the presence of the water barrier formed previously. This phenomenon is referred to as water blocking or the water shielding effect. In the current survey, the time required in rupturing the water film shielding the oil as a result of oil swelling caused by the diffusion of dissolved gas in the water phase and trapped oil behind it has been investigated in porous medium at high pressure and temperature. To study the active mechanisms, the experiments have been conducted with two different types of injectants: carbon dioxide and methane (with different solubility in water), under different miscibility conditions at equal reduced pressures. The results show that water film reduces the performance of oil recovery by limiting the interface of oil and gas phase. Under such a condition, the best scenario is the miscible gas injection because the gas can effectively swell the oil and rip the water shield. At miscible and near-miscible conditions, the time required for wiping out the water film increases as the injectant solubility in water decreases; however, there is a negligible difference at the immiscible regime. The trend of oil recovery curves after rupture of the water film shows that oil swelling is one of the main mechanisms involved in water-trapped oil recovery. These results suggest practical guidelines on the effect of water shielding phenomenon in the field of tertiary gas injection. Recent Publications 1. Mirazimi S, Rostami B, Ghazanfari M H and Khosravi M (2017) Water film rupture in blocked oil recovery by gas injection experimental and modeling study. Chemical Engineering Science 161:288???298. 2. Zeinabadi D, Rostami B and Khosravi M (2016) Effect of petro physical matrix properties on bypassed oil recovery from a matrix-fracture system during CO2 near-miscible injection: experimental investigation. International Journal of Multiphase Flow 85:123???131. 3. Kazemi K, Rostami B, Khosravi M and Zeinabadi D (2015) Effect of initial water saturation on bypassed oil recovery during CO2 injection at different miscibility conditions. Energy & Fuels. 29(7):4114???4121. 4. Khostavi M, Rostami B, Emadi M and Roayaie E (2015) Marangoni flow: an unknown mechanism of oil recovery during near-miscible CO2 injection. Journal of Petroleum Science and Engineering 125:263???268. 5. Fatollahi A and Rostami B (2014) Carbonated water injection: effects of silica nano-particles and operating pressure. The Canadian Journal of Chemical Engineering 93(11):1949???1956.
Haifa Tang
Research Institute of Petroleum Exploration and Development, China
Title: Horizontal well for enhanced recovery technology in tight gas based on reservoir structure research
Biography:
Haifa Tang has her expertise in oil and gas production in development geology. Horizontal well is the key technology to develop such tight gas field, and the practice has proven its advantage in improving single well production. But as a whole, whether the horizontal well enhance the recovery efficiency of gas field or not is still a controversy because of the vertical sparse distribution of profit plays. In solving such problem, he presents a new concept of concentration ratio of the vertical profile reserves. And on the basis of this concept, three sand body distribution models have been established. They are single thick block type, multi period vertical overlap pan connected type, and multi period dispersed partially connected type. Reservoir recovery of horizontal well under different sand body combination has been studied, and technical measures to improve the recovery rate of horizontal wells have been proposed.
Abstract:
Sulige gas field is the largest tight sandstone gas field in China with low porosity, low permeability, high reservoir heterogeneity, and low single well production, but has huge reserves and high production capacity. Horizontal well is the key technology to develop such tight gas field, and the practice has proven its advantage in improving single well production. But as a whole, whether the horizontal well enhance the recovery efficiency of gas field or not is still a controversy because of the vertical sparse distribution of profit plays. In solving such problem, this paper presents a new concept of concentration ratio of the vertical profile reserves. And on the basis of this concept, three sand body distribution models have been established. They are single thick block type, multi period vertical overlap panconnected type, and multi period dispersed partially connected type. Reservoir recovery of horizontal well under different sand body combination has been studied, and technical measures to improve the recovery rate of horizontal wells have been proposed. The results show that straight wells is not perfect due to the "blocking zone" present in compound sand body of the braided river sedimentary system. The horizontal well can overcome the influence of "blocking zone" to improve the producing degree of reserves within the layer. However, the layered sand body dispersed, horizontal well development will lead to the vertical bearing department of gas reserves is not sufficient, reducing interlayer recovery degree. For the reserves concentration greater than 60%, single period and multi period vertical overlap panconnected type, using horizontal well development can significantly improve the producing degree of reserves and recovery, whose I + II wells are more than 70% proportion. For the multi period disperse partially connected reservoirs with less than 60% concentration of reserves, the development of vertical well pattern and the optimization of the horizontal well location by desserts can improve the recovery by more than 10%. Recent Publications 1. Liu Qunming, Tang Haifa, Lv Zhikai, et al. Well deployment technique for composite subwater distributary channel sand body reservoir architecture of Edong tight gas[J]. Journal of China University of Mining & Technology, 2017,40(5): 1144-1151. 2. Liu Qunming, Tang Haifa, Ji Guang, et al. Characteristics of braided river sedimentary system zones in Sulige gasfield, Ordos Basin [J]. Natural Gas Geoscience, 2016,27(7): 1360-1366. 3. Guo Zhi, Jia Ailin, He Dongbo, Tang Haifa. Control factors on the formation of effective reservoirs in tight sands: Example from Guangan and Sulige Gasfileds[J]. Oil & Gas Geology, 2016,34(1): 78-82. 4. Tang Haifa, Jia Ailin, Peng Shimi, et al. Stochastic modeling of sedimentary microfacies-lithofacies in proluvial fasn reservoir[J]. Journal of China University and Development, 2010, 34(3): 12-17.
Zhikai LV
Research Institute of Petroleum Exploration and Development, China
Title: Production characteristics and productivity evaluation of horizontal wells in sulige tight gas reservoir
Biography:
Zhikai LV has her expertise in oil and gas production in evaluating gas well productivity. According to the one point method, his productivity chart was drawn. With horizontal wells test data, the chart can be used to estimate the absolute open flow rate of horizontal wells to obtain the reference index of reasonable gas production rate quickly and intuitively. Through the analysis of the actual production data of 63 wells which product 3 years, the relationship between the average daily production and absolute open flow rate was regressed. So the initial production rate equation is obtained to determine initial production. The results show that the productivity chart can be used to estimate the absolute open flow rate of horizontal wells to obtain the reference index of reasonable gas production rate quickly and intuitively for Sulige gas field and error range is within 10%.
Abstract:
Horizontal well technology is an effective means to develop tight sandstone gas reservoirs. While horizontal wells development have achieved excellent performance in Sulige gas field, there exists practical problems including difficulty in production characteristics and productivity evaluation. For this, the gas field geology and horizontal well production characteristics were studied firstly. Then, the new method (productivity chart) was established to evaluate the absolute open flow rate of gas well. The time of horizontal well flow to achieve stationary was determined and the well-controlled reserves of the early horizontal wells were calculated by rate transient analysis. Finally, the relationships of reasonable production rate, absolute open flow rate and well-controlled reserves were analyzed. Results showed that initial production of horizontal well is much higher after fracturing, which mainly reflects the gas capacity of well nearby high permeable fractures. However, the subsequent production and pressure are continuously decreased with the extension of production time and generally there is no obvious stable production period. It takes 100 to 600 days for horizontal wells to enter the boundary controlled flow period due to poor properties and strong heterogeneity of Sulige tight gas field. Horizontal well production decline is depleted, early decline is dramatic and late decline is gradually slow. The relationship of reasonable horizontal well production and absolute open flow rate is power function. Reasonable production proration is gradually decreases with the increase of absolute open flow. The relationship of reasonable horizontal well production and well-controlled reserves is linear relation. This result is consistent with the actual production of data, which is benefit for production proration determination of fractured horizontal wells and production capacity building of tight gas reservoirs. Recent Publications 1. Qunming LIU, Haifa TANG and Zhikai LV, et al. (2017) Well deployment technique for composite subwater distributary channel sand body reservoir architecture of Edong tight gas. Journal of China University of Mining & Technology; 855-876. 2. Bo LI, Ailin JIA, Dongbo HE and Zhikai LV, et al. (2015) Productivity evaluation of horizontal wells in Sulige tight gas reservoir with strong heterogeneity. Natural Gas Geoscience; 2325-2334. 3. Ailin Jia, Zhikai Lv. (2014) Dynamic Effect of Capillary Pressure in Tight Gas Reservoir. The Open Petroleum Engineering Journal: 71-79. 4. Zhikai Lv, et al. (2014) The Effect of Gas Slippage on Laboratory Results and Gas Well Production. Theory and practice of natural gas development Petroleum Industry Press: 200-206. 5. Zhikai LV, et al (2013). Factors Affecting the Productivity of a Multi-fractured Horizontal Well. Petroleum Science and Technology: 2325-2334.
Zunyi Xia
Peking University, China
Title: Micro-nano pore structure and connectivity investigation in continental shale Zhanhua Sag, China
Biography:
Zunyi Xia is currently a research associate in College of Engineering, Peking University. China. She earned her second MS degree from the University of Oklahoma, Oklahoma, US. She earned her Ph.D. from Peking University, Beijing, China. She has worked on shale reservoir characteristic since 2006. Her research interests include rock physics, unconventional reservoirs, and reservoir characterization.
Abstract:
Pore structure and connectivity controls the fluid flow in the porous media. Shale micro-nano pore structure and connectivity in the continental Es31 Formation in the Zhanhua Sag is evaluated with FIB-SEM, High resolution CT, CO2 adsorption, N2 adsorption, and merury-injection porosimetry methods. The present study shows that micropores, mesopores ,macropores and micro-cracks are developed in the shale. The structure of the pore are mainly parallel plate, groove, slit, and ink-bottle type pore. Macropores have a greater capacity of providing pore volume rather than micropores and mesopores. Micropores are dominant in surface area. There is a positive correlation between Micropores volume and TOC, Clay mineral content. There is a positive correlation between Mesopores and clay mineral content. Pore connectivity of the continental shale nano pores are mainly organic pore, which are developed better with higher maturity. Recent Publications 1. Lei Wang, Zhenzhen Dong, Xiang Li , Zunyi Xia. A multi-scale flow model for production performance analysis in shale gas reservoirs with fractal geometry. Scientific Reports revised submitted (2018). SCI IF=4.259. 2. Lei Wang, Xiaoxia Chen, Zunyi Xia. A Novel Semi-Analytical Model for Multi-branched Fractures in Naturally Fractured- Vuggy Reservoirs. Accepted. 2018. Scientific reports. 3. Lei Wang, Cheng Dai, Xiang Li, Zunyi Xia, Cai Wang. Pressure transient analysis for asymmetrically fractured wells in hydrocarbon reservoirs with dual-permeability behavior. Accepted. 2018. International Journal of Hydrogen Energy. 4. Zunyi Xia, Carl Sondergeld, Chander Rai. Rock Mechanics of Shale. The abstract is accepted by AAPG, 2008. 5. Late Jurassic and Early Cretaceous the Bivalve Buchia fauna of Himalaya Region, South Tibet, Xia, Zunyi, Bai, Zhiqiang (Acta Palaeontologica Sinica. 44(4), 2005). 6. Xia, Zunyi, Bai, Zhiqiang. Discussion on a CO2 geological sequestration by methanogens in the biogenic gas field in China. (Petroleum Exploration and Development, Vol. 31, No. 6, 2004).
Fawzi S. F. Hamad
Sirte Oil Company, Libya
Title: Waha Reservoir Characterization and distribution in the Ralah Field, Concession 6, Sirte Basin, Libya
Biography:
He is from Sirte Oil Company for Production Manufacturing Oil & Gas, Exploration Department, Libya
Abstract:
The Ralah Field is one of the concession 6 fields operated by Sirte Oil Company. It is located in the southern part of the Sirte Basin (Libya), approximately 200 km south of the Mediterranean Sea. Geographically it is located between latitude 28� 42' 12" and 28� 51' 40" North and longitude 19� 51' 58" and 19� 59' 57" East. The Upper Cretaceous Waha Formation is the main producer in the Ralah Field. The Waha reservoir ranges from zero thickness on the crests of the paleo-topographic highs to over 45 m on their flanks. The Ralah Field was discovered in June 1964 with the drilling of DD1-6 well through the Waha Formation and proved to be the most prolific reservoir in the area. Oil flowed on a drill stem test in the discovery well. 2D seismic surveys were done in the Ralah Field. In 2004 a 3D seismic survey of 340 km�, which covered all the Ralah field area was completed to evaluate remaining and upside potential. The seismic interpretation has acquired new drillable well locations. Seismic and well data of nineteen wells have been used in this project. Waha reservoir was evaluated, analyzed and interpreted. Seismic interpretation and coherence attribute analysis were performed for the fault trend identification; and Property models were constructed in terms of clay volume, porosity, permeability and hydrocarbon saturation. The study concluded to show that; all of the faults in the Ralah Field are normal extension with modest throws and trending in NW-SE direction; Waha Reservoir is divided into four main facies (Wackestone, Rudstone, Dolomite Cemented Sandstone and Bioclastic Sandstone). Some of these facies are considered to be a tight non-productive facies (tight zone), and others have good reservoir properties (PHIE=13-25% & K=1-30mD).