Biography: will be update soon..
Abstract: The evaluation of unconventional reservoir in term of future exploration plan where the geochemical data are not unavailable making us different results from logging and Gas Data However this paper aim to define Potential zone through the estimation of total organic carbon (TOC) using ∆ log R Method and thermal maturity by mean of gas ration technique combined with gamma-ray data of Frasnian shale formation encountered in DAK-1 well drilled in Ahnet Basin from 1552m to 1728m. The results suggest that the frasnian shale have fair to good potential genration with TOC ranging from 2% to 4%, with mature organic matter who producing wet gas,The potential zone positioned in the lower frasnian over a thickness of 10m
Biography: Islam Zewain – Reservoir Engineer in GULF OF SUEZ PETROLEUM COMPANY with 5 years expeience, graduated in 2011 from the faculty of petroleum and mining engineering with very good as graduation grade.
Abstract: Morgan Field is one of biggest Egyptian oil fields, located in central part of GOS (Gulf of Suez). Morgan is a mature oil field discovered in 1965, production started in Apr 1967 from Kareem reservoir overlaid by Belayim reservoir, with peak rates reached 400 MBOPD in Aug 1970. Water flood started in Feb 1974.
The main Morgan field is subdivided into two big areas (North Morgan & South Morgan). Morgan field is elongate northwest-southeast trending faulted anticlines separated by a trough. The Morgan structure is one of the largest tilted fault block accumulations in the GOS. Full closure to the east is not achieved until the eastern boundary fault of the neighboring Badri field. Level of reservoir heterogeneity between the two reservoirs is high because of lateral and vertical facies variations. That is the main factor affecting production and water flood performance and consequently represents the biggest challenge to understand, evaluate and plan the depletion of the reservoirs.
The periodical engineering and geological reviews to the field through “the water flood conformance reviews” and “well by well reviews” recently resulted in many actions through which GUPCO could add around 5000 BOPD by drilling a new infilling well and 3 wells recompletion beside the regular add perforations and WSOs in other wells. The achieved recovery factors up to now are 52% in Kareem and 33% for Belayim which give indication of the good reservoir management.
Biography: Kamal is a reservoir engineer at APC holding B.Sc and M.Sc in PE. His career history included working as Teaching Assistant at the American Un. in Cairo (AUC), in addition to working as field engineer for two petroleum companies and working on projects from six countries. Kamal instructed around one hundred technical lectures in Malaysia, Dubai, Abu Dhabi and Egypt, including the British Un., and held Professional Certified Trainer (PCT) degree from the AUC. Kamal officially is a SPE-Certified Petroleum Engineer (SPEC) and his training history includes fifteen technical certifications from SPE-IPIMS. Kamal is interested in Unconventional Resources, EOR and Reservoir Simulation Uncertainty Analysis.
Abstract: History matching is a type of inverse problem in which observed reservoir behavior is used to estimate reservoir model variables that caused the behavior. Obtaining even a single history-matched reservoir model requires a substantial amount of effort, but the past decade has seen remarkable progress in the ability to generate reservoir simulation models that match large amounts of production data. The objective is to validate a reservoir model before it is used for prediction. In conventional way, people do history matching by manually adjusting uncertain parameters until an acceptable match is achieved. As a consequence, history matching becomes a delicate problem and consumes a lot of time. Furthermore, in several cases it is hard to obtain a match by manual process. In order to have a more efficient history matching process, many researchers conducted studies by involving a computer based program to obtain a match. The method is normally called (computer-) assisted history matching (AHM). One of the AHM methods involves the use of experimental design, proxy model and optimization algorithm. The basic concept of this method is to use proxy model which is generated from set of experiments to replace reservoir simulation in the optimization process. This method has practical application in the industry. However, without a proper understanding, using this method to solve a history matching problem would be as difficult as conventional way.
Biography: Eng. Khalaf Gad. I work as a senior reservoir engineer at Ganope Co. .I got Bachelor's degree In Petroleum Engineering at Al Azhar Univrsitey. I gained Pre- master in Petroleum Engineering at Cairo University GPA 3.2. Currently, I am finalizing my MSc thesis in Carbonate reservoir at Cairo University.
My research interest includes Reservoir Engineering and formation Evaluation.
Abstract: An accurate estimation of porosity and permeability are extremely essential for designing an ideal and efficient development program of an oil and gas field development. Numerous methods have been developed to determine the Porosity and Permeability including laboratory measurements and log derived models. Artificial neural network (ANN) provides an efficient technique that successfully addressed several engineering and geological challenges. In the present study ANN is applied to help in predicting porosity and permeability in carbonate reservoirs using back propagation neural network (BPNN) with high accuracy on well log data from numerous fields worldwide.
ANN has the ability to understand a highly non – linear relationship and to perform simulation studies in a rapid manner. The BPNN model of Porosity and permeability is developed using a set of well logging data as input layers and core porosity and core permeability as output layers. Porosity model is a [7-7-1] three-layer BPNN with a seven-neuron input layer (depth, gamma ray log data, formation density log data ,neutron log data , sonic log data, deep resistivity and diagenesis respectively) a seven-neuron hidden layer, and a one-neuron output layer. Permeability model is built in a similar manner to Porosity model ,but it involves eight – neuron input layer. The optimal learning rate and momentum constant used in the BPNN model are obtained from serial combinative experiments. The available data has assigned 80% for training and 20% for verification.
The results of the developed porosity and permeability models are well compared to core data in verification. Cross-plot of the actual Porosity versus ANN predicted Porosity exhibited a perfect match with a correlation coefficient equal to 0.9765. Cross-plot of the actual permeability versus ANN predicted Permeability exhibited a perfect match with a correlation coefficient equal to 0.981. Such data indicate that the developed models are successful in predicting the porosity and permeability for carbonate reservoirs.
Biography: Ms Da Costa did her bachelor thesis at PDVSA – Intevep, in Caracas, Venezuela. She studied at the Universidad Central de Venezuela.
Abstract: The Orinoco Oil Belt is the largest stock of heavy and extra heavy oil in the world, and its characterization is of vital importance in the oil industry. However, the working methodologies used to achieve this goal do not apply to actual reservoir conditions. For this reason, a working methodology that merges the Nuclear Magnetic Resonance (NMR) with the forced fluid displacement technique using a physical simulator for heavy and extra-heavy crude is implemented. This is done with the main objective of obtaining the relative permeability curves (Kr), wettability and other properties. However, when performance considerations are incorrect, so are the results. For example, the laboratory contracted by the Boyacá Block did not take into consideration these factors: temperature, injection rate and viscosity, among others; which are considered in the MDC (Intevep) methodology for dead crude in displacement tests. The foreign laboratory throws a condition of wet to the oil whereas for Intevep the tendency was wet to the water. For the recovery factor, in Intevep the values range from 69.9% the lowest to 89.8%, the highest, while in Boyacá oscillate between 18.2% and 21.2% at stopper scale. Due to these results, it is vital to faithfully recreating what happens in the heavy and extra heavy oil fields, with adequate tools and considerations, since from these results are proposed successful and low risk exploitation plans, which is, in the long run, the goal of all oil drilling and extraction in the world, and the Orinoco Oil Belt is no exception.
Biography: will update soon..
Abstract: Quantification of uncertainty in reservoir performance is an important part of proper economic evaluation. The uncertainty of a given reservoir`s performance (e.g. reserves at the economic limit) arises from the uncertainty in the information we have about the variables that control reservoir performance (e.g. permeability, oil/water contact, etc.) The problem is complex since the influence of the variables on the reservoir performance is often non-linear.
The objective of history match process is to improve the model in order to reproduce the production history while honouring the structural properties of the geological model. To that purpose, an objective function is defined that measures the mismatch between the simulation results and the production history. This function is minimized using an optimization algorithm, usually a gradient-based optimization algorithm, which is based on the computation of the gradients of the objective function with respect to the inversion parameters. Evaluation of the objective function needs reservoir simulations, which are very CPU time consuming.
This paper describes the application of the method of Experimental Design to this problem. It is to investigate and testing the effect of different Experimental Design Techniques method applied on ALWYN case, which is derived from a North Sea real field case. The objective was to run a sensitivity analysis and to quantify the impact of the major reservoir uncertainties on history matching.
The study was performed in the following steps:
- Identify the ranges of the important variables that influence the history matching.
- Select different Experimental Design to identify the values of the variables.
- Conduct the experiments-use reservoir simulation to select the most influential parameters effecting history matching.
- Compare the results for the different Experimental Design techniques-improving the history matching with reduction on the number of simulation runs.
This work has potential value in selecting the most influential reservoir parameters that can improve history matching. It can give a help to the reservoir engineers to select the most suitable Experimental Design technique needed
Biography: The works of Ajji and co-workers (Polytechnique de Montréal) Have proved the capability of PP to produce microporous membranes through the MEAUS process. Nevertheless, in some applications, it may be necessary the increase of the stiffness of the membrane, and this could be overcome by the addition of mineral fillers. In this sense, in the 90’s Nakamura and co-workers
Abstract: Microporous membranes are commonly used in separation processes such as battery separators and medical applications to control the permeation rate of chemical components. Due to the wide range of chemical structures, optimum physical properties, and low cost of polymers and polymer blends, these materials are known as the best candidates for the fabrication of microporous membranes.
The two main techniques to develop polymeric membranes are: solution casting and extrusion followed by stretching. High cost and solvent contamination are the main drawbacks of the solution technique. Techniques to make porous membranes from polymers without using any solvent were developed in the seventies of the last century for some applications, but most of the information on these processes remains proprietary to the companies’ and are not available to the scientific community. One of the techniques is MEAUS (melt extrusion annealing uniaxial strain). It is based on the stretching of a polymer film containing a row-nucleated lamellar structure. Then, three consecutive stages are carried out to obtain porous membranes: (1) creating a precursor film having a row-nucleated lamellar structure by mechanisms of shear and elongation-induced crystallization, (2) annealing the precursor film at temperatures near the melting point of the resin to remove imperfections in the crystalline phase and to increase lamellae thickness, and (3) stretching at low and high temperatures to create and enlarge pores, respectively. In fact, in this process the material variables as well as the applied processing conditions are key parameters that control the structure and the final properties of the fabricated microporous membranes. The material variables include molecular weight, molecular weight distribution, and chain structure of the polymer. These factors mainly influence the row-nucleated structure in the precursor films at the first step of the formation of microporous membranes.
Among a wide range of resins, polypropylene (PP) is a well-known semicrystalline polymer and, in comparison with polyethylene, has higher melting point, lower density, higher chemical resistance, and better mechanical properties, which make it useful for many industrial applications.
Biography: Dai Cheng is an reservior engineer in Exploration and Production Research Institute of SINOPEC. He holds Ph.D in energy engineer in Peking University. His research interests include numerical simulation, history matching and uncertainty quantification in reservoir engineering.
Abstract: Due to the low permeability of shale gas reservoirs, hydraulic fracture is always required to generate fracture network to enhance the recovery. The hydraulic fractured formations can be divided into two regions, e.g. stimulated reservoir volume (SRV) and unstimulated reservoir volume. Investigating the recovery patterns of gas stored in different region may assist us to make more reasonable productive strategies.
In this paper, we apply numerical simulation to quantify the gas production from each region. We proposed a new method called “component subdivision method”. This method can track the gas from different regions and assess their contribution to total production. Several cases based on Fuling Jiaoshiba Shale are proposed to study various features and hydraulic fracture parameters’ impact on the recovery patterns.
The results reveal that the factors including matrix permeability, the number of prime fractures, conductivity of prime fracture, permeability of secondary fracture network, the fracture space of secondary fracture network will influence the gas productions from different regions. When the matrix permeability is 100nD, contribution from free gas stored outside SRV is significant whereas it is insignificant when the matrix permeability is 10nD.
Dr. Amin Azhdarpour awarded his PhD (Petroleum Engineering) in 2015 from Universiti Teknologi Malaysia (UTM), Malaysia. He has been working as an academician and researcher since 2012 and as an Assistant Professor at the Department of Petroleum Engineering, Marvdasht Branch, Islamic Azad University, Marvdasht, Iran since 2015. He is currently the head of Petroleum Engineering department at the Faculty of Engineering.
Abstract: Production optimization and reservoir management in gas condensate reservoirs require an understanding of the reservoir behavior and characteristics. Therefore, reservoir parameters including permeability, porosity, initial reservoir pressure, wellbore storage coefficient, skin factor, and non-darcy flow coefficient are needed to be analyzed in this regard. Reservoir well testing is one of the methods that provide comprehensive analysis on abovementioned reservoir properties. In this paper, well testing data of one the south pars gas condensate reservoirs were analyzed using a software named Saphir and important reservoir properties such as permeability, wellbore storage coefficient, skin factor, initial pressure, reservoir type and boundaries were determined accordingly. The well testing results provided a knowledge to have a better understanding about reservoir performance.
Biography: Cai bo，Born in 1979，Doctor degree, major in Petroleum Engineering，China University of Geosciences(Beijing).Work at Research Institute of Petroleum Exp. and Dev. Langfang (RIPED-Langfang) in July 2005. Mainly engaged in design and field service of hydraulic fracturing treatment, particularly in tight oil and gas and other unconventional reservoir, published 43 technical papers, 11 papers were indexed by EI/SCI
Abstract: Proppant embedment leads a smaller fracture width, a smaller fracture conductivity and a smaller productivity. It is critical to keep a long-term stable high yield for a fractured oil and gas well. A large number of experimental studies have been made on the influence factors of proppant embedment and the affect of proppant embedment on the conductivity. However, the study on theory model of proppant embedment and the theoretical research on the affect of proppant embedment for the conductivity is still rare. This paper firstly summarizes the influence factors of proppant embedment and the affect of proppant embedment on the conductivity, secondly establishes the models of monolayer and multilayer proppant embedment and calculated sepatately conductivity of proppant fracture both embedment and not embedment stages. At last, according to the formula derived from the model, the effect of proppant embedment for propping fracture conductivity and productivity is analysized. The proppant embedment effects are quantified by the research on the models, so that indoor researchers and field workers can have a more intuitive understanding of the effects of proppant embedment for propping fracture conductivity and productivity.
Biography: Will be update soon...
Abstract: The main lithology in Mahu depression glutenite reservoir, with complex lithology (glutenite reservoir), burial depth (3750-3900m), medium porosity and low permeability (porosity 9.8%, 5.4mD thickness, permeability) and multi layer (3-5 layer thickness 3.4-23m, multi layer distribution, high pressure coefficient (1.6) ~ 1.8) etc.. The reservoir without natural productivity, fracturing are required to increase the single well production, but in the face of crack is difficult to find, the well depth transformation of high cost, difficult issues such as the use of multilayer, poor fracturing effect, in view of the above problems, on the formation of the technology system of low cost and high efficiency transformation of glutenite reservoir: in Glutenite Reservoir crack propagation law is difficult to find, to carry out the sand conglomerate complex fracture extension experiment on physical model, analysis of glutenite reservoir crack propagation characteristics, formation transformation ideas and countermeasures; the low permeability reservoir characteristics, research and development of a low concentration of fracturing fluid system, guar gum concentration decreased from 0.40% to 0.25%, 90 C, meet 170S-1, 120min shear fracturing fluid viscosity remains at more than 100mPa.s, reduce the cost of 39 yuan / square, while the residue content is only the past 10% guar gum; the multi layer reservoir reconstruction of vertical development Study on the technology of stratified fracturing and general fracturing. The results showed that: under the same geological conditions, the stratified fracturing can improve the vertical use degree, and improve the pertinence of each layer. The transformation of parameter optimization in different scale and reduced prepad proportion and different slickwater ratio, reasonable transformation parameters of formation; low cost and high efficiency to carry out research on the formation of completion tools, low cost and high efficiency tools; the formation of factory fracturing operation mode, the operation period reduced by 20%; the total of 47 wells 72 layers. The level of 2 wells in 48, the average single well oil production of 11.2 tons / day, super (design capacity of 9.5 tons / day), to achieve the purpose of lowering the efficiency, compact domestic similar low permeability reservoir reconstruction to provide technical guidance to the new.
Biography: Dhruvit Berawala was born in India in 1990 and moved to Stavanger, Norway in 2013. He received the M.Sc degree in Petroleum engineering from University of Stavanger in 2015. Passionate about mathematics, the move to be a Ph.D. research fellow on modelling and simulation of shale gas technology research project was a natural fit. Earlier, he has held Research Engineer positions at University of Stavanger and European Mud Company AS.
His main areas of research interest are modelling and simulation of fluid flow in porous media, enhanced oil recovery and geomechanical effects.
Abstract: Unconventional natural gas deposits are difficult to characterize overall, but in general are often lower in resource concentration and more dispersed over large areas. Moreover, gas is densely packed into the matrix through adsorption which account for large volume of gas reserves. The conventional reservoir modelling and production forecasting methods, which rely on fluid-flow processes dominated by viscous forces, have proved to be very pessimistic and inaccurate. We present a new approach to forecast shale gas production by detailed modeling of gas desorption, diffusion and non-linear flow mechanisms in combination with statistical representation of these processes. The representation of the model involves a cube as a porous media where free gas is present and a sphere (SiC: Sphere in Cube model) inside it where gas is adsorbed on to the kerogen or organic matter. Gas is considered to be densely packed into the sphere with many layers (onion-like structure) which desorbs to the nanopores and micro-fractures in the cube. The new available surface area on the sphere and change in concentration triggers the diffusion of gas from the kerogen. The sphere diameter allows to model gas storage, diffusion and desorption; the cube length takes into account the pathway for flow in nanopores and micro-fractures. Many of these representative but general cells of the reservoir are put together and linked to a well or well fractures. A numerical model has been derived which is then compiled on FORTRAN to develop a simulator for the production of shale gas by considering the spheres as a source term in each of the grid blocks. By applying SiC to field data, we demonstrate that the model provides an effective way to access gas production rates from shale formations. We also examine the effect of model input properties on gas production.
Biography: Over two decades of a diverse technical and supervisory experience in reservoir engineering in the oil industry, the Experience in conventional and advanced reservoir engineering and other petroleum related activities. Gained a good experience in many aspects, including:
Reservoir optimization and development fields. Team leading of Multidiscipline Integrated Reservoir studies, Simulation issues. Day to day reservoir management and monitoring Principal. Author and Co-author of some technical papers. Many years of multidiscipline team leadership, supervising junior and senior reservoir engineers.
Participation abroad (Italy) and completion of some 3D reservoir dynamic models.
Author and Co-author of many in-house and abroad of technical studies and reports .Taught under graduate courses in reservoir engineering, integrated reservoir Management as assistance university lecturer. Taught industry engineers and geoscientists (reservoir engineering Courses).
At present my employer is Mellitah Oil & Gas B.V. (ENI - AGIP) Libyan branch, Reservoir department, under title of Reservoir Engineering Superintend.
Abstract: Our major mature offshore Field is driving by mechanism of gas cap and strong aquifer; it is located in the Libyan sector of the Mediterranean Sea, producing since 1988. The reservoir formation is a fractured carbonate bearing a thick high oil rim with 25°API. Due to the existing primary gas cap and a strong aquifer, production is often affected early water and gas break-through. Coning phenomena were reduced by allocating extended reach and/or horizontal wells. One of the main challenges to reservoir management is the relative high water cut at which most of offshore wells become unstable or stop producing naturally.
Actually Natural flow of water cutting wells is highly dependent on gas oil ratio to be precis, oil wells with high water cut & low gas oil ratio GOR, will not resume production after shut-in cases.
Water flow into wellbore could be through fractures or/and water coning. These issues makes a sharp production decline is practical, so to improve the productivity and recoverable reserves of total field a production optimization and development strategy has been planned through a variety of projects, this plan included several actions and interventions for instance the slot recovery campaign, East Area Development, artificial lift (ESP Installation),gas utilization project ( GUP), Full field Optimization (Phase II) and acid gas injection. The key project is identified as Phase II, this project comprises one platform and one cluster of subsea wells, the development consists of expanding field development to the Western area including the Dolomitic member and the Northern flank not reachable from existing platform III, The exploitation area contains nearly 40% of OOIP and can be considered particularly challenging from a drilling and production approach.
On the same track and founded on the results derived from 3D reservoir simulation studies (2008 and 2016 ) this paper will be present and focus on the consequence of hydrocarbon reserves (oil) which Could be caused by postponed or delay of performing some projects that have been mentioned previously, it thought that the delay of the concerned activities brings to reduction of RR ( recoverable reserves ), it was observed that additional recoverable reserves from phase II and other scheduled activities are reduced compared the existing 3D reservoir simulation study to the previous one which was carried out in 2008. The paper is suppose to demonstrate the evidence of the different profiles of delaying effect on reserves performance; it will investigate/revise the motive of reduction in terms of oil reserves and the mechanism may abridged the Productivity through adverse relative permeability effects and hysterics effect associated with the preservation of invaded aqueous fluid. By other words water encroachment or invaded layers due to strong aquifer which may introduce an additional immiscible phase, or increase existing phase saturation within porous media which could cause adverse relative permeability effects , then it may has a significantly impact on the relative permeability of hydrocarbon phases.
Biography: Simulation Reservoir Engineer with more than 10 years of experience in numerical and analytical evaluation, implementation and monitoring of thermal recovery process like steamflooding, cyclic steam stimulation and solvent injection in Colombian Heavy Oil Reservoirs. Additional experience like professor of petroleum engineering basic program and research of thermal process. And studies on formulation and evaluation of projects.
Abstract: This paper shows the evolution of the cyclic steam stimulation (CSS) process in a Colombian heavy oil field. Some challenges have been faced like: low injectivity in the first cycles, presence of swelling clays, low continuity of sands, steam channeling, among others.
According to the oilfield complexity some strategies are currently being implemented after previous studies of numerical simulation and lab test evaluation: slug diesel to improve injectivity, reduced steam quality to increase steam injectivity, using clay inhibitor, reducing spacing according to opportunity index map, nitrogen injection and changes in completion design and drilling scheme, among others.
The set of lab test, numerical simulation and pilot test have resulted in the following: 1) Use of slug diesel before steam soaking clean the hole improving injectivity, allowing more steam volume. 2) Reduce steam quality in first cycles is useful to increase injectivity without significantly affecting SOR. 3) Using an index map opportunity help to identify areas with potential for infill wells. 4) Injecting nitrogen with steam improve production results due to the pressurization of sands. 5) Changes in drilling and completion scheme have reduced potential damage wells and reduce costs.
Key recommendations for implementing a CSS process in heavy oil reservoirs with low continuity of the producing sands, swelling clays and low NTG are presented in this article. The recommendations range from the first injection cycles to maturity of the process and the search for new production alternatives.
Biography: Waqas Ahmad received his PhD degree from Institute of Chemical sciences, University of Peshawar in 2013. He carried out a part of his PhD work at department of Chemical and Material Engineering, University of Alberta Canada. His area of research is desulfurization of petroleum products, conversion of waste polymers into liquid fuels, lube oil processing, and coal processing. He has around 20 publications in various international journals. He is currently working as Assistant Professor at Institute of Chemical sciences, University of Peshawar.
Abstract: Oxidative desulphurization of model and real oil samples was studied using air assisted H2O2-formic acid oxidation system in the presence of MoOx/ZSM-5 catalysts. The model oil used was Thiophene, DBT and 4,6-DMDBT dissolved in n-heptane with about 1275 ppm total sulfur content. The catalyst was prepared by wet impregnation method in the laboratory, and characterized by XRF, FT-IR, SEM and SSA analysis. In case of model oil, about 96% of desulfurization was attained in the presence of 2 wt % MoOx/ZSM-5 under atmospheric pressure, 60 oC temperature in 60 min reaction time, air flow rate of 100 ml/min and 1.5:1.75 ml concentration ratio of H2O2 and HCOOH. The reactivity order of model sulfur compounds was found to be as Thiophene < DBT < 4-MDBT. The ODS of commercial oil fractions including untreated naphtha, light gas oil, heavy gas oil and Athabasca bitumen was also studied under the optimal conditions, the % desulphurization yield attained in each fraction was to 81.6, 78.68, 64.86 and 60.27 respectively.
Biography: Mr. Ali Cherif Djendara got his Engineering degree in chemical process engineering from university of Mascara, Algeria, on 2011 and his master in environment engineering
in 2012. From 2013, he is preparing a PHD degree in Chimie Physique des colloides at university of Mascara, Algeria. His research interest includes, Extraction and characterization of heavy petroluem compounds and study of asphaltene flocculation and research of potential inhibitors.
Abstract: The main objective of this work is to investigate the link between chemical composition, chemical functionality and asphaltene stability. Solubility fractions derived from an Asphaltene extracted from a deposit of a Hassi Messaoud oil well have been analyzed using a variety of different analytical techniques. The studied fractions namely extracted asphaltene, purified asphaltene and 40% toluene/n-heptane and 40% Acetone/n-heptane soluble asphaltene were studied by IR and Near IR spectroscopy. It is noted that properties such as chemical composition and chemical functions differ slightly for all the fractions but differences exist in term of association behavior in solution when a flocculating agent is added. From titration experiments it is shown that the n-heptane/toluene soluble asphaltenes are more sensitive to n-heptane addition than n-heptane/Acetone soluble ones and precipitate more earlier.
Exploration & production
Biography: Eleven years experience in Oil and Gas Industry.
•Constructing 3D static model for reservoir simulation using PETREL.
•Design and conduct reservoir geological modeling work by conducting a systematic and an integrated reservoir study using sedimentology, facies, seismic information and petrophysical data in order to understand reservoir compartmentalization, distribution, reservoir heterogeneities, properties, quality and architecture to provide accurate input to reservoir simulation for optimizing the well placing and maximizing the recovery.
•Constructing different sensitivities of 3D static models; taking in consideration the uncertainty in structure, contact, petrophysical parameters and reservoir geometry.
Abstract: Identification of the types of the depositional environments that have control or influence on the distribution of petrophysical parameters is required to assess the potential utility of these parameters in the reservoir analysis.
The main factor controlling differences in petrophysical properties for these reservoirs is the type of sandstone facies. Shales cause a major reduction in the porosity and gas saturation of the reservoir sandstones especially in the Upper Bahariya reservoir which has dispersed and laminated shale and low resistivity net pay zone. The best reservoir characteristics belong to the Lower Bahariya, which has high effective porosity (PHIE), low shale content (Vsh), and high gas saturation (Sg). The poor reservoir characteristics belong to the Upper Bahariya. Core and production test are integrated with log data to mitigate the uncerinity in the petrophysical interpretation in the shaly sand intervals of Upper Bahariya reservoir.
Petrophysical characteristics, depositional environment, and hydrocarbon prospectivity of the Upper creatcouse Bahariya reservoir in the BED2 Field (Western Desert, Egypt) are described using data from wireline logs (gamma ray, density, neutron, sonic, resistivity, core and production test data) from 12 wells. Petrophysical characteristics of Upper Bahariya reservoir change significantly with variations of depositional facies and lithology. These units are interpreted to be complex of tidal sands with low net groos in Upper Bahariya and high ration of net gros in Lower Bahariya resevoir.
Updated GIIP based on the new petrophysical geological evaluation indicates for future gas development activities in BED2 filed, 50% of the existing gas volume add to the field, the new interpretd shaly sand intervals has been perforated and produced apromesd rate of gas therefor, perforation campaign is proposed (200 meter in 7 wells) candiates for the unconventional reservoir (shaly sand intervals) in addition to proposed slanted well targeting the unconventional reservoir intervals.
Abstract: Here, we show the contribution of the seismic anisotropy using the sonic scanner tool in the characterization of natural and hydraulic fractures of shale gas reservoirs. Data of a horizontal well drilled in the Lower Barnett shale gas reservoir located in the Ft Worth Basin (USA) are used. Results interpretation show that the sonic scanner tool can be sued for Natural fracture modeling, surface seismic data calibration and sweet spots localization.
Biography: Ernst Zaltsberg is co-ordinated and conducted the technical review of more than 40 applications and supporting documentation for the municipal and privately owned landfill sites in Ontario. He did Research work on earthquake prediction based on hydrogeological information and Compilation of a map of geodynamic conditions for Southern BC. He got Over 50 years' experience in the environmental field, both in North America and the former Soviet Union and extensive knowledge of the theory, principles, and practices of groundwater monitoring, assessment and forecasting techniques.
Abstract: Geodynamic processes could make the significant impact on urban agglomerations, highways, railroads, pipelines, oil and gas fields, mining operations, etc.
The regional deformation process in geological formations is the result of combined impacts of endogenic, exogenic and technogenic forces on the lithosphere stress field which manifests itself as a combination of short-living strain structures.
The high susceptibility of the lithosphere to all disturbances of the geodynamic balance allows defining them by means of applying theoretical principles and methodology of regional hydrogeoderformatics (HGD) (ссылки на публикации на англ.).This new discipline is based on the discovery of globally spread, short-lived pulsating changes in the hydrogeosphere, caused by its ability to respond to changes in the stress state of the lithosphere. The methodology developed allows defining the area of dangerous strain conditions, their magnitude and speed velocity of their development.
A strong geodynamic event occurring in any region on the Earth generates deformation changes within huge geological massifs far away from the source of the event. All such changes including fine ones could be identified by means of the HGD methodology.
Kinetics of deformation processes is investigated in details and direction of the deformation impulse movement is identified. The possibility of defining the permanently “pulsating’ zones dangerous for urban and industrial development is discussed.
Lateral geodynamic movements of geological massifs and their near surface manifestations are considered and discussed. Various specific hydrogeodeformatic precursors warning on potentially dangerous geodynamic development in the area are discussed.
Establishing of several strategically located HGD monitoring stations which could provide such warnings on the global scale is proposed.
High lithosphere susceptibility to all kinds of stresses, including man induced one, could create catastrophic changes in the fragile natural strain-stress balance within the huge geodynamic systems.
Biography: Will update soon..
Abstract: In this paper we intend to present a modeling of a powdered (sulfur / carbon) composite electrode in our tests on a novel technique for removing cationic lead from water by using a composite (sulfur / carbon) electrode,
It is known that sulfur is practically insoluble in water, and it confers a very important characteristic, which is the very rapid chemical adsorption of most heavy metals such as cationic lead, when the electrode incorporated in Carbon is negatively charged with a current, even of very low intensity.
Our first tests are devoted to the realization of this electrode and the optimization of the parameters that influences the flow of current through the incorporated electrode.
We intend to present a detailed diagram of this technique and the possibility of its realization by the contribution with a team specialized in automation.
Biography: MR.Ahmed Mohamed Hassanein Graduatedfrom Petroleum and Water
Program_Geology Department_Faculty of Science_Suez Canal University, after graduation he work in (Zpec Egypt ) (Zhongman Petroleum and Natural Gas Group)
As a geologist ,the 3d reservoir modeling was his graduation project he worked very hard in it he learned more and more about reservoir modeling in order produce a project such that , more important than project is the way he presented his work that way let any one related or not related to he filed to understand it.
Abstract: South Umbarka Area is found in a development lease to the north of the Khalda Concession. Bahariya Formation, the main target of this study, is one of the most important reservoirs in the Western Desert, in Shushan Basin. The Bahariya Formation is underlain and overlain by Kharita Formation and Abu Roash-G member. It consists mainly of sandstone, siltstone with shale and limestone streaks. A detailed 3D model of Bahariya Oil reservoir in South Umbarka Area has been constructed by integration of seismic, well log, and core data. The goal of this work is to develop a model with sufficient detail to represent vertical and lateral heterogeneity at the well, multi-well, and field scale, which could be used as a tool for reservoir management. Identifying and recovering hydrocarbons requires an accurate, high-resolution geological model of the reservoir structure and stratigraphy. The Bahariya reservoir has been divided into two zones (Upper and Lower Bahariya). The configuration of the studied area is controlled by northwest-southeast oriented large fault; this fault breaks the reservoirs into two major fault blocks (North and South Block). Well log analyses furnish the data necessary for quantitative evaluation of hydrocarbons in situ. The reservoir parameters of Upper and Lower Bahariya reservoirs are illustrated in the form of 3D models which include shale volume (Vsh), effective porosity (фe), hydrocarbon saturation (Sh), and Net/Gross thickness. Consequently, the integration between the study of geological structures and accurate petrophysical evaluation leads to successful development of the area.
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Abstract: This study concerns the danger related to the installation of renewable energies sites, more exactly wind farms. After showing the dangers which could alter a wind turbine, and defining the most commons accidents in the world, we noticed that the main cause of the incidents is the high speed of the wind.
In this context we have established a PYTHON program to warn against the accidents in any region, for each type of wind turbine.
This allows us to view the feasibility and choose the adequate wind turbine for the adequate site, in order to preserve the durability of the device by making it works in a steady performance and a complete safety .
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Abstract: Surfactant flooding aims at lowering the interfacial tensions between the oil and water phases to improve the displacement efficiency during oil recovery. However, surfactant losses due to adsorption on the reservoir rock impairs performance of the chemical flooding, consequently renders the process impractical economically. This article presents adsorption equilibrium and kinetics of Sodium Dodécyl Benzene (SDS), a non-ionic surfactant, onto Hassi Messaoud rock . The adsorption tests were conducted at a temperature range of 28–85◦C. A conductivity method was employed in this study to measure CMC parameter and surfactant concentration in the aqueous solutions. The equilibrium conditions for the crushed rock samples were obtained after about 2 days. According to the experimental results, the equilibrium data were well-fitted by the Freundlich isotherm for sandstone samples. Furthermore, the adsorption process is exothermic and obeys the second-order kinetic model. Such a systematic investigation is very helpful to select a proper surfactant for EOR application and reservoir stimulation in the petroleum industry.
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Abstract: Despite numerous studies on the reserves and availability of natural gas hydrates, the technology of transporting natural gas hydrates in large quantities to sea has not been put into practical use. Several natural gas hydrate transport technologies presented by the International Maritime Organization (IMO) are under preparation for commercialization. Among them, NGH tank container concept modularized transportation unit to prevent sintering effect during sea transportation. The natural gas hydrate can be vaporized in a certain part during the transportation. Unprocessed BOG increases the pressure inside the tank. Also, there is a risk of fire if you export the BOG out of the tank without proper handling. Therefore, in this study, we have studied the concept of technology to properly process BOG to modularize natural gas hydrate and to transport it to sea for long distance. The study is expected to contribute to the practical use of NGH tank container, which is a modular transport concept proposed to solve the sintering problem that occurs when transporting natural gas hydrate in the form of bulk cargo.
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Abstract: The marvel of sulfide stress splitting (SSC) can bring about calamitous disappointments of pressurized hardware and channeling, bringing about broad harm, wounds and conceivable fatalities. Sulfide stretch splitting was initially distinguished as a major issue in the oil business in the late 1950's with the improvement of more profound harsh supplies. The high quality materials required for these wells started to come up short thus of weak break that was later distinguished as SSC. Look into started on this marvel and a errand gathering was framed, which later got to be related with the National Association of Corrosion Engineers (NACE), now known as NACE International. The T-1B board of trustees of NACE distributed a prescribed work on tending to the metallic material necessities for insurance against SSC. This prescribed practice was later issued in 1975 as the Materials Requirement MR-0175, referred to today as "Metals for Sulfide Stress Cracking and Stress Corrosion Cracking Resistance in Sour Oilfield Situations". As of late, NACE International has issued the International Standard MR0175/ISO 15156 tending to different types of breaking related with the nearness of fluid hydrogen sulfide. This paper will focus on, and distinguish, the necessities for SSC to happen and give originators and administrators handy alternatives for the aversion of SSC in gear working in a watery H2S environment. While this paper will essentially
talk about SSC, some understanding will be given to address the worries of different types of splitting
Abstract: At an early stage of development of a reservoir, it is vital to obtain required data for a plan of protective production. Equilibrium of light hydrocarbons mixtures with water is an important property within the natural gas industry. Development of reliable model with low relative error is particularly challenging since this property range from quantifying its effects the vertical saturation distribution of natural gas in a reservoir to determining liquid droplet size for multiphase flow calculations. The solubility of methane and three groups of natural gasses in water was measured under (293.2 to 353.2) K and (0.1 to 30) MPa. The experimental results show that, with the increase of temperature and pressure, the solubility of natural gas in water goes through a minimum value under the experimental conditions. The solubility of natural gas in formation water was also influenced by a composition of the gas phase. For natural gas solubility in water a thermodynamic model based on the chemical potential of natural gas in the liquid phase and that in the vapor phase was developed through using Jarrahian–Heidaryan equation of state (J–H-EOS) .
Biography: Dr. Hossein Aamani did his PhD from university of Tehran, Iran. He has published several research articles about optimisation of flow rate for gas and crude oil in pipes. He also has many papers about oil recovery using biosurfactants. His research interest includes, Biosurfactants, Oil recovery and Cell biology research.
Abstract: Recently, nanoparticles have become an attractive agent for enhanced oil recovery (EOR). But much of the work on nanoparticles for oil recovery is still in the laboratory stage. Therefore for a better understanding of this technique, it is essential to carry out tests about EOR by nanoparticles. In addition, the word is now more environmentally aware, presenting the opportunity to use biosurfactants for EOR. In this paper, the synergistic effect of simultaneous biosurfactant and nanoparticle on the removal of oil in a glass micromodel was evaluated. In this study, an aqueous solution of emulsan biosurfactant with addition of SiO2 nanoparticle was used as a nanofluid. The emulsan biosurfactant was produced by Acinetobacter calcoaceticus PTCC1318. The production of emulsan was confirmed by FTIR and H NMR analysis. According to our results, the use of the mixture of biosurfactant and nanoparticle (nanofluid) permitted a 90% reduction of interfacial tension in comparison with biosurfactant solution. Oil displacement experiments in micromodel with kerosene showed around 20% and 10 % recovery of residual oil after water flooding when the nanofluid and emulsan were injected, respectively. These results are useful in extending the application of nanostructures in ex situ microbial enhanced oil recovery.
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Abstract: The study area belongs to the Northern part of Ghadames basin in which the main discovered reservoirs are enclosed in the Paleozoic series. This work is mainly based on the lithostratigraphic description, series correlation and depth maps elaboration of the encountered Formations of available drilled wells. The Ordovician deposits which composed by sandstones interceded by shaly layers, constitute the primary target as mentioned by numerous companies that have been worked in the area. Whereas, the sandstone and carbonate layers of Cambrian, Late Silurian, Late Carboniferous and Permian Formations, where they exist, constitute a potential secondary target. All the cited Paleozoic reservoirs are sourced by the radioactive hot shale layer at the base of the Early Silurian Tannezuft Formation. The established lithostratigraphic chart, based on the borehole data, reveals that these reservoirs are mostly affected by many unconformities resulting on the occurrence of several orogenic phases specified this region of Tunisia. These tectonic manifestations have played an important role in the structural and stratigraphical traps arrangement.
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Abstract: Sources of ionizing radiation have wide application in medicine, industry, research,
agriculture and education. These sources must be managed in conditions of safety and
security. If used incorrectly or in unsafe conditions, radioactive sources can cause death,
serious injuries and economic losses, as demonstrated by the experience in many areas
of the world.
In the oil industry, specifically the oil refining industry has wide application of ionizing
radiation sources in the following fields:
1. Study and control of catalysis.
2. Measure and control fluid flow.
3. Determination of residence times of liquids in closed systems.
4. Location of interfaces or separation zones of petroleum products circulating in the
5. Analytical determination of components such as sulfur.
6. Studies on corrosion protection.
7. Fire detection and gas.
In Cuba three oil refineries are installed in different parts of the country the case in this
work is the Cienfuegos refinery located in the south-central Cuba, specifically in the
northern margin lobe of the Bay of Cienfuegos region. Its purpose is oil refining and
product manufacturing, purchase, storage, processing, distribution and marketing of oil
and petroleum products within the Cuban territory and abroad.
In the Cienfuegos oil refinery various types of sources of ionizing radiation, linked to
the following practices are used:
1. Location of interfaces or separation zones fixed level nuclear gauges are used with
Cesium sources 137, Cs-137, for a total of eight sealed sources, which are used in
2. Fire detection and gas, ionic smoke detectors used with sources of americium-241,
Am-241, for a total of 450 sources,
3. Detection of analytical components, two sulfur analyzers with X-ray tubes.
The above practices have spent more than 8 years in use with very good results.
Radiation protection in the exercise of these was based on the demands and
requirements established by law and national legislation in line with the basic rules and
guidelines proposed by the IAEA internationally.
At the time elapsed they have not reported overdose of occupationally exposed workers,
or specialists and workers related to the exercise of practices, nor have reported
incidents or radiological events.
The results are based on training and training of occupationally exposed workers and
workers linked to practices in the documentation of each and study and exercise plan
radiological emergency linked to other key plans like plan emergency in case of fire and
disaster reduction plan.
Training continuity by simple elements such as lectures, conferences, videos, business
web, and internal magazines to the entity raise awareness and training of workers in
confronting possible events and the responsible use of the potential of the exercise of
One aspect of great interest achieved is the systematic analysis with the fire department
and rescue of the actions to take in the combined events of fire and explosion which is
involved the presence of some of the sources of ionizing radiation, or natural disasters
as the incidence of severe cyclones, with a strong probability of occurrences as
meteorological data from previous years.
Biography: Ryan Damara Pradhana (Ryan) graduated from Institut Teknologi Bandung major in Geology in 2010. He is a geologist work for Special Task Force for Upstream Oil and Gas Business Activities Republic of Indonesia or SKK Migas (Exploration Division). Ryan accomplished in helping oil companies exploring Indonesia for more than US$500M of investment since 2011 and also to make sure his country obtain investment from remaining firm commitment in PSC. Currently, Ryan is monitoring the realization of exploration commitment in Indonesia and helps giving the recommendation in fiscal term to optimize the oil and gas industry in Indonesia.
Abstract: The Southern Java Basin is a West-East trending fore arc basin lying on pre-tertiary mélange rock in the Offshore Southern Java, Indonesia. The exploration activities in this basin had been operated since 1970’s, however, no petroleum in commercial quantities was found.
Up to the present time, 6 wells had been drilled, more than 3,000 seismic line data and turned out gave disappointing result. Moreover, also only few studies that had been done in this area. C-1 was drilled in 2016 and showed a very good gas reading despite the recent study that concludes there is a poor quality of source rock. From this well also, the lack of maturity and organic content richness of source rock are the main reason why the exploration targets in this area are not interesting in terms of risk and economy. This study will discuss about the possibility of exploration success in this frontier basin.
In term of Petroleum System, Southern Java Basin is divided into Western Java Fore Arc Basin, which was developed as fore arc basin earlier than the eastern part, and Eastern Java Fore Arc Basin. In this study, each component in petroleum system such as source rocks, reservoir rocks, hydrocarbon maturation and migration, trapping mechanisms and seal rocks will be re-evaluated in both areas, particularly on source rock analysis based on the latest biostratigraphy, geochemical and burial history analysis.
This study aims to re-evaluate the petroleum system in Southern Java offshore and provide consideration to oil and gas exploration companies in calculating the petroleum system risk in this area. In summary, based on the data from drilling and seismic acquisitions in Southern Java Basin along with re-evaluation of the wells as mentioned above, the fore arc basin in Southern Java Indonesia are very high risk and frontier area and thus, require big and wild ideas to explore the area.
Biography: Will update soon..
Abstract: Water injection to aquifer is one of the most common methods of pressure maintenance in the oil reservoirs. This process may causes permeability reduction due to change in thermodynamic equilibrium of ions which exist in these waters (change in temperature, pressure, pH, ion capacity) and although incompatibility of injection water with respect to amount of ions and concentration of suspended particles.
In some reservoirs which oil production is carried out along with water, a huge volume of reservoir water is produced. Due to environmental issues and rapid pressure decline in reservoir, this water is to be returned back to reservoir. Understanding of effective parameters on permeability reduction as a result of organic and inorganic scales, and optimizing injection condition are the main objectives of this paper.
In this paper possibility of CaCO3 scale formation during mixing of two incompatible waters is investigated using OILscale Chem software and the effect of different parameters such as temperature, pressure, PH, and CO2 for wells number Sar-5 and Saa-6 of Sarvestan and Saadatabad oilfield is also investigated. Water produced from this field is selected as injection water and water from wells Sar-5 and Saa-6 is selected as formation water. The Water Analysis of injection and formation water is determined by experimental methods in laboratory.
Biography: My self Sagar Dadhich .I am pursuing my Btech from Pandit Deendayal Petroleum University,Gandhinagar,Gujrat, India. I am currently in 3 year.
Abstract: With oil becoming scarcer and more expensive, the economics of the industry may finally tip in favour of one of the most neglected areas of its business - the technology for cleaning up oil spills. Oil spills can be costly for companies and for the environment. The traditional method of clearing an oil spill, containing it with the use of booms, skimming, and centrifuges .However these containment methods have not been successful as nearly 60000 barrels of oil get released into water every day. These methods can be replaced with polyurethane foams that can sponge the oil directly out of the water. It is a super-absorbent polymer(oil-SAP) that exhibits high oil absorption capability (up to 50 times of its weight),fast kinetics, easy recovery from water surface, and no water absorption. This idea presents an approach to solve this problem by use of porous materials that not only absorb oileffectively but also provide a way to recover the spilled oil.
The experimental and theoretical study shows that with highly interconnected open porous structures, and pore sizes below 500 micrometres, it is possible to reach absorption capacities as high as 50 grams of oil per gram of polyurethane.
The oil sponge consists of a simple foam made of polyurethane or polyimide plastics and coated with “oil-loving” silane molecules with a sweet spot for capturing oil. An interconnected structure, which water can easily flow through, is key to creating a highly effective mechanical sponge for clearing oil spills.The silane molecules are used to induce the superhydrophobic transformation.
The presented approach will provide a facile and easily scalable solution for the design and construction of multifunctional absorbent material with low costs for practical applications(Oil Spills)
Biography: Arsyan Hilman Sasoni was born in Okayama, Japan, on April 16,1991. He grew up in the Indonesian city of Jakarta where he finished his Senior High School in Labschool Kebayoran in 2009. He received Bachelor of Science in Geology of the University of Padjadjaran in late 2013 and started his first career in Geoservices as a geologist support in 2014. Now, he is sponsored by LPDP (Indonesian Education Scholarships) to continue master degree of Oil and Gas Enterprise Management at University of Aberdeen
Abstract: Nowadays Indonesia adopts a new oil and gas petroleum fiscal system called Gross Split PSC. The objective is to implement a better system for the development of oil and gas project in Indonesia which will authorise the government to secure higher government take from the early phase of production and provides a more efficient of bureaucracy for the contractors. This individual project contrasts the new PSC scheme and the traditional PSC system using deterministic sensitivity analysis to determine the most optimum fiscal terms under the Gross Split PSC. The discussion includes the profitability index such as government share of gross revenue, project’s NPV, and IRR. Also, the work is carried out both from the perspective of contractor and government in an IPA case study field development in deep offshore. The outcome of the economic modelling analysis shows that Gross Split PSC will have the same IRR with Traditional PSC if the project accelerates for 1year, receives a 5% deductible effective tax rate, and gets additional progressive split from cumulative production.