Qarun Petroleum Company

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Qarun Petroleum Company

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Salama H.,Badr El Din Petroleum Company BAPETCO | Darwish M.,Cairo University | Wahdan M.,Badr El Din Petroleum Company BAPETCO | El-Batal A.,Qarun Petroleum Company
Egyptian Journal of Petroleum | Year: 2017

This study includes a new understanding of the depositional model of Abu Roash “C” Member deposited in Sitra Field in Abu Gharadig Basin during Turonian time, and illustrates the major affecting factors that control the behavior of this reservoir and consequently offer a great opportunity for Sitra field's future development activities through a new methodology to maximize the field's ultimate recovery. The Sitra development lease is located in north Western Desert and occupies the central western part of Abu Gharadig Basin and covers the southern extension of Badr El-din Petroleum Company (BAPETCO) leases with an area of 322.4 km2. Sitra Area is divided into several structural closures; the main producing one is the Sitra 8 block in which 39 wells were drilled since 1993. Various data from these wells were evaluated to construct the depositional facies models for the Abu Roash “C” reservoir. The log analyses have been integrated with the core descriptions, and ditch cutting data to interpret the depositional facies model that controlled the reservoir characteristics. In Sitra Area the Abu Roash “C” Member exhibits all of the characteristics of the Shallow Marine-Tidal dominated estuaries which are linked to the south with a fluvio-marine environment, the tide-dominated estuaries are represented in tidal channels and tidal flat facies, march deposits, and distributary mouth bars. The best reservoir rock in the Abu Roash “C” Member was deposited as distributary channel fill/Mouth bars that cut through the underlying strata. Two major parasequences were identified, the first lower one was developed during a shallowing upward sequence represented by shale/sand intercalations into which the main Abu Roash “C” reservoir sand bodies are included, and reached its end by the appearance of a laterally extended coal marker nearly one meter thick. This parasequence was deposited subsequently to a falling sea level phase which occurred after the deposition of Abu Roash “D” limestone. The succeeding parasequence (deepening upward) reached its maximum flooding surface (MFS) by the deposition of the widely extensive shale marker being rich in pelagic Pelecypod shells. The resultant stratigraphic units consist of: genetically related depositional cycles (3 cycles) and their components of facies sequences (5 facies types), each cycle has its own distribution, facies classification and reservoir characteristics. © 2016 Egyptian Petroleum Research Institute


Othman A.,Al - Azhar University of Egypt | Fathy M.,Al - Azhar University of Egypt | Ali A.S.,Qarun Petroleum Company
Egyptian Journal of Petroleum | Year: 2016

Wadi Rayan Field is located approximately 115 km from Southwest Cairo. The study area is a platform lying between Abu Gharadig and Beni suef basins. It was discovered in September, 1996 through drilling well WR-1x which has been drilled to a total depth of 7740 ft. in basement. Abu Rawash G member is Cenomanian in age and the only producing horizon in this area; it's composed of shale and sandstones intercalations with minor carbonate interbeds. The main producing interval in this member is ARG-5 which consists of sandstone, silt and shale. The thickness is varying along whole study area. It ranges from 1 to 100 ft. There are two intervals of producing sandstone which not only vary from one well to another but also not deposited in some wells. For these reasons, it is important to integrate all available geological and geophysical data to come up with a model for ARG reservoir. © 2015 The Authors


Akl A.,Qarun Petroleum Co. | Akl A.,Mansoura University | Elnakib A.,Mansoura University | Kishk S.,Mansoura University
Wireless Personal Communications | Year: 2017

Due to the increasing demand for wireless communications, spectral efficiency of transmission schemes has gained a great concern recently. Also, achieving secure wireless communications is of high importance. Recently, physical layer security has been intensively investigated as an extra layer of protection for wireless communications. Directional modulation (DM) has been proposed as a mean to implement physical layer security. Antenna subset modulation (ASM) is a low complexity single beam DM technique suitable for millimeter-wave communications. The small wavelengths nature of millimeter-wave band is exploited to equip a transmitter with a large antenna array, and by randomly choosing few elements of this array for transmitting a symbol, secure communication in a single direction is obtained. This paper provides a study for the performance of broadcasting multi-beams antenna subset modulation (MASM) in which it is desirable to broadcast data streams to different receivers. A statistical model has been driven, and the symbol error rate of MASM using QPSK and secrecy capacity are obtained. Simulation results show that ASM can be used efficiently for multidirectional broadcasting communication, while maintaining its inherent security. © 2017 Springer Science+Business Media, LLC


Attalla M.,South Valley University | Ahmed H.,Asuit University | Ahmed M.S.,Sohag University | El-Wafa A.A.,Qarun Petroleum Company
Applied Thermal Engineering | Year: 2017

The present study investigated experimentally the cooling and heating performance of two identical counter flow vortex tubes arranged in-series (VTS) and parallel (VTP). The vortex tube used has general specifications of: aspect ratio AR = 1.6, hot tube length L = 112.5 mm, hot tube inner diameter D = 7.5 mm, cold end diameter dc = 5 mm, and generator of three nozzles, N = 3. Dry air is used as a working fluid with different inlet air pressures adjusted from 2 to 6 bars. The experimental results revealed that the maximum cold temperature difference occurred at the inlet air pressure of 6 bars and cold mass fraction of 0.4 for both VTS and VTP systems. The conducted results demonstrated that the values of COPref for VTS system were higher than the values of VTP system. However, the VTP yielded higher values of COPHP over the range of investigation. The VTS system improved the COPref by 22.5% and 31.5% compared with the VTP and the single vortex tube system (VTO), respectively. For the case of VTP system, the COPHP is enhanced by 18.2% and 27.3% than VTS and VTO, respectively. © 2017 Elsevier Ltd


Hassan S.S.,Schlumberger | Megawer A.K.,Qarun Petroleum Company | Zahran H.,Schlumberger | Emam M.,Schlumberger | And 2 more authors.
Society of Petroleum Engineers - SPE North Africa Technical Conference and Exhibition 2015, NATC 2015 | Year: 2015

The Western Desert accounts for approximately two thirds of Egypt's surface area. The region can be divided into a number of large scale structural provinces which developed along lines of weakness in the African basement, in response to lateral movements between Europe and Africa. Seismic evidence has revealed a subsurface comprising a series of low relief horsts and grabens. In places however, the structural history is more complex. The Yusif field located near the Qatara depression, is habituated and, therefore has poor seimic data. Three wells were drilled in the field, Yusif -1X, Yusif-3, and Yusif-4 respectively. The fourth well is planned for the most promising area between the three wells. Formation microimaging was performed in the three wells, and interpretation of the images helped to delineate the sand body propagation and geometry in the field and choose the most promising area for drilling the fourth well. The Lower Abu Roash "G" member usually appears as a fining upward profile from conventional openhole logs. Facies analysis was performed on the "G" member with manual sedimentary dip picking, which revealed the internal structures and directions that can't be observed from conventional logs. Correlation with existing openhole logs showed continuity in the vertical and lateral distribution of the sand body, and queries about the relation between the sand bodies in the three wells arose. The relationship between sand bodies can't be solved by conventional openhole logs correlation. Paleocurrent analysis was performed for the sand bodies in the three wells. The results showed that the main trend of the channel belt propagation is NE. Yusif-3 and Yusif-4 wells were drilled within the channel belt while Yusif-1X location was at the channel margin. Correlation is based on electrofacies, which was extracted from high-resolution formation microimaging in the three wells. It was found that the "G" member top is changed based on high-resolution electrofacies detection, and the fourth well was placed closer to Yusif-3 and Yusif-4 based on the recommendations on the channel activity propagation as identified in the formation microimaging. The sand body thickness in the fourth well was almost double the thickness that was found in the previous three wells. Copyright © 2015 Society of Petroleum Engineers.


Elmawgoud H.A.,Egyptian Petroleum Research Institute | Elshiekh T.M.,Egyptian Petroleum Research Institute | Khalil S.A.,Egyptian Petroleum Research Institute | Alsabagh A.M.,Egyptian Petroleum Research Institute | Tawfik M.,Qarun Petroleum Company
Egyptian Journal of Petroleum | Year: 2015

The scavenging of hydrogen sulfide is the preferred method for minimizing the corrosion and operational risks in oil production facilities. Hydrogen sulfide removal from multiphase produced fluids prior to phase separation and processing by injection of EPRI H2S scavenger solution (one of the chemical products of Egyptian Petroleum Research Institute) into the gas phase by using the considered chemical system corresponds to an existing oil well in Qarun Petroleum Company was modeled. Using a kinetic model the value of H2S in the three phases was determined along the flow path from well to separator tanks. The effect of variable parameters such as, gas flow rates, chemical injection doses, pipe diameter and length on mass transfer coefficient KGa, H2S outlet concentration and H2S scavenger efficiency has been studied. The modeling of the hydrogen sulfide concentration profiles for different conditions was performed. The results may be helpful in estimating injection rates of H2S scavengers for similar fields and conditions. © 2015


Attalla M.,South Valley University | Salem M.,Sohag University | Abo EL-Wafa A.,Qarun Petroleum Company
International Journal of Mechanical and Mechatronics Engineering | Year: 2014

An experimental study is carried out to investigate the effects of nozzle aspect ratio and hot tube length on the energy separation of a Ranque-Hilsch vortex tube (RHVT). The inlet pressures were adjusted from 200 kPa to 600 kPa with 100 kPa increments. A dry air is used as the working fluid. The conventional tangential nozzle (N = 6) was used. The inner diameter (D) of vortex tube used in the experiments was 7.5 mm. The ratio of the length of the vortex tube to its diameter (L/D) varied from 10 to 30. The experimental results reveal that the nozzle aspect has a great effect on energy separation. The results show that the maximum differences in temperature of hot and cold streams were obtained for the aspect ratio of 1.4. © August 2014 IJENS.


Nasser A.E.A.,Qarun Petroleum Company | Ghareeb M.,Lufkin Industries | Gawad A.A.,Qarun Petroleum Company
Society of Petroleum Engineers - North Africa Technical Conference and Exhibition 2012, NATC 2012: Managing Hydrocarbon Resources in a Changing Environment | Year: 2012

With continuous instability of oil prices it became necessary to reduce the cost of lifting the crude oil from the wells. This cost reduction is not feasible for each stage of the total oil production system; therefore the optimization of each component in the production system is a must. Production optimization meant to apply an optimum analysis and comprehensive investigation of well production system; including the artificial lift system that expected to increase the oil production and reduce the operating costs. The artificial lift systems are essentially in all Qarun Petroleum Company (QPC) fileds to transports reservoir fluid to the surface. Production optimization found to be an essential for the life cycle of each system in order to extend run life, decrease cost and increase the cumulative production per well. The applied artificial lift systems in QPC fields include Sucker Rod Pumps (SRP) and Electrical Submersible Pumps (ESP). The failures and problems related to ESP and the success resulted from the applications of the system optimization is encouraged us to be selected to be the subject of this paper. This paper will discuss in full details the successes results of using the Variable Speed Drive (VSD) with ESP. Statistical failure analysis has been conducted for the applications of ESP wells with and without VSD to evaluate their performance in order to optimize the applications. Copyright 2012, Society of Petroleum Engineers.


Abd El Hafeez T.H.,Al - Azhar University of Egypt | El Kadi H.H.,Al - Azhar University of Egypt | El Ghamry M.N.,Petro Sila Petroleum Company | Abd El Salam R.E.,Qarun Petroleum Company
Energy Exploration and Exploitation | Year: 2014

Using the available seismic data, this study aimed at the evaluation of the prospectivity and hydrocarbon potentialities to the deep formations structure of the Asala-Samra area. The Asala-Samra area is located in the Western Desert of Egypt, south of the Northeast Abu Gharadig Concession and west of Qarun oil field. The 3D-Seismic data covers about (56 km2) which called East Bahariya Area. The acquisition of high quality 3D seismic data integrated with the well data resulted in accurate delineation of the structure traps and the different elements of the petroleum system in the study area. The interpretation results of the high quality seismic data contributed to in the understanding of the tectonic history of the study area. Evidences for the presence of Jurassic-Early Cretaceous rifting, Late Cretaceous rifting, Late Cretaceous-Early Tertiary inversion, and Late Tertiary (Miocene) rifting tectonics were documented from the interpretation of the seismic data. The main productive reservoirs of the study area are Abo Roash "G" member and Upper part of Bahariya Formation. This research focused on the deeper formations and structures from Early Cretaceous and Late Jurassic which didn't test as HC trap yet and aims to add new undiscovered zones. Many seismic leads of Early Cretaceous and Late Jurassic were recognized from interpreted seismic data. Most of them are four way dip closure to avoid the side sealing problem. The source rocks are working in the eastern part of the Abu Gharadig Basin. The regional top seals for the different reservoirs in the study area were evaluated through isopach maps. A reservoir evaluation of the Alam Elbueib and Safa sands has been also attempted. © 2014 Energy Exploration & Exploitation.


AlMaraghi A.M.,Qarun Petroleum Co. | El-Banbi A.H.,Cairo University
Society of Petroleum Engineers - SPE North Africa Technical Conference and Exhibition 2015, NATC 2015 | Year: 2015

Pressure transient well test analysis is commonly used to help characterize oil and gas reservoirs. In a typical well test, interpretation of rate/pressure data usually yield information about permeability, skin factor, boundary conditions, and character of the reservoir. Some well tests, however, suffer from ambiguity and non-unique interpretation. The objective of this study is to apply the Artificial Neural Network (ANN) technology to identify the reservoir model. A multilayer neural network, with back propagation optimization algorithm, is used to identify the reservoir model. The required training and test datasets were generated by using the analytical solutions of commonly used reservoir models. Nine ANN networks were constructed with each one capable of differentiating among six boundary models. Most commonly found reservoir models of different inner, outer boundary and reservoir medium are included (e.g. vertical, fractured and horizontal wells; homogenous, dual porosity and radial composite reservoirs; and infinite, one sealing fault, two sealing faults, rectangle and circle boundaries). Each of the ANN of the nine networks has been constructed by one input layer, two hidden layers; and one output layer with six nodes characterizing the different reservoir boundary models. Different network structures and training intensity were tested during this work to arrive at optimum network design. The performance of the proposed ANN was tested against simulated noisy and smooth datasets. The results indicate that the proposed multilayer neural network can recognize the reservoir models with acceptable accuracy even with complex models. The comprehensive testing of different ANN designs showed that success rate increases significantly by distributing the commonly used reservoir models into nine networks. This ANN design can still yield good results even with some noise in the pressure data. After testing the ANN, they were then used in the interpretation of several field cases (including complex tests) and results are presented in the paper. Copyright © 2015 Society of Petroleum Engineers.

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