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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.


Guichard A.,Schlumberger | Zhan L.,Schlumberger | Dilling L.,Schlumberger | Giaquinta A.,Qarun Petroleum Company | And 2 more authors.
North Africa Technical Conference and Exhibition 2010, NATC 2010 - Energy Management in a Challenging Economy | Year: 2010

In mature fields it can often be a challenge to obtain accurate well data and reliable formation parameters without imposing high cost and time constraints on development or production schedules. One common method to test non-naturally flowing wells is impulse testing, which makes use of differential pressures between the formation and a surge chamber or wellbore to perform a short flow period or surge test, followed by a relatively short shut-in period. Unfortunately, these tests frequently result in invalid or uninterpretable data as a result of several uncertainties and test constraints. An improved version of this common technique encompasses a three-fold approach to optimize the impulse test. A new numerical simulator designs the test to maximize depth of investigation without compromising the interpretable data. The coiled tubing-conveyed intelligent bottomhole assembly used to execute the impulse test may, in certain environments, reduce operating times in comparison to use of conventional tubing-conveyed solutions. The combination of the prejob design package and a functional bottomhole assembly enables consideration of the complexities that can result from impulse testing so that a valid data set is delivered. The interpretation is performed using traditional well test interpretation methodology and an analytical solution specifically designed for impulse testing. This solution considers the wellbore fluid density variation during the test while still maintaining the simplicity of the wellbore model; variable skin is described by an exponential function, thus improving on established analytical methods. A comparison of the results from both interpretation methods establishes the test validity in terms of flow capacity and skin. This paper describes the systematic approach, including its design, execution, and interpretation, and highlights advantages and limitations through the case study and field data of a well in the Wadi Rayan field of Qarun Petroleum Company. This technique offers a rigless testing method that can optimize test time while delivering valid, accurate results that aid in production forecasting, completion optimization, and planning of remedial intervention for non-naturally flowing wells. Copyright 2010, Society of Petroleum Engineers.


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.


Bosworth W.,Apache Egypt Companies | Khalil S.,Suez Canal University | Clare A.,Qarun Petroleum Company | Comisky J.,Apache Corporation | And 3 more authors.
Geological Society Special Publication | Year: 2014

The East Ras Budran Concession is located in the eastern rift shoulder of the Gulf of Suez. Syn- and pre-rift rocks are exposed in the north and east of the concession, and the Markha alluvial plain covers the SW. The Markha plain occupies the hanging wall of a large extensional fault which preserves most of the pre-rift stratigraphic sequence and >3500 m of syn-rift strata. Vertical wells drilled in 1999 indicated the presence of a >200 moil column in low-porosity naturally fractured limestone beds of the Eocene Darat and Thebes formations. Outcrop, borehole image and core data define NW, WNW, N, NE, and ENE steeply dipping fracture sets. Borehole breakouts and drilling-induced fractures show that the minimum horizontal stress is aligned NNE to NE, so the NW and WNW fractures should be open in the subsurface. Using this structural picture, a near-horizontal well of 300 m length was drilled into the Darat in a NE direction. During testing, the well flowed at a rate of 1900 barrels of oil per day with no water. Future development of the field includes drilling similarly oriented wells with longer horizontal sections. © The Geological Society of London 2014.


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.


Ali A.,Halliburton Co. | Amer M.,Halliburton Co. | Yassine R.,Halliburton Co. | Abdel-Khalek T.,Qarun Petroleum Company | Hamdy A.,Qarun Petroleum Company
SPE Middle East Oil and Gas Show and Conference, MEOS, Proceedings | Year: 2011

Hydraulic fracturing has been used for a long time in the Egyptian western-desert reservoirs and has proven to be very beneficial in increasing well productivity by approximately 25% over that of wells completed without hydraulic fracturing. However, production of water caused by fracture growth into the adjacent underlying (or overlying) water zones to the hydrocarbon zone is a major challenge. Excessive water production threatens the economics of a well by • Shortening its production life by trapping the hydrocarbon reserves • Increasing disposal and lifting costs that can reach up to an estimate of billions of dollars, partially attributed to water-disposal regulations • Boosting fines-migration problems • Increasing the rate of tubular corrosion and scale buildup These can be sufficient reasons to not consider fracturing in marginal fields. The conformance-while-fracturing (CWF) technique incorporates a relative permeability modifier (RPM) in the fracturing-fluids design. The RPM provides a reduction in effective permeability to water without significant changes to the relative permeability to oil. Applying the CWF technique resulted in water cut as low as 4%, even when the adjacent water zones were within 10 ft of the perforations. This technique provides a tremendous economic boost and has been found to be an effective solution for fields otherwise plagued with water production. Increased recoverable reserves are now being observed from these wells. This paper discusses the geological and reservoir parameters of the wells and zones of interest, the properties of the RPM, the CWF job-design considerations (and the associated challenges to the job design), its field applications, and post-fracturing results in comparison to offset wells fractured conventionally in the same reservoir and at the same level. It is envisaged that CWF techniques will prove to be beneficial to other operators facing similar production challenges. Copyright 2011, Society of Petroleum Engineers.

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